EXHIBIT 99.3

Unaudited Interim Consolidated Financial Statements for the Third Quarter Ended
September 30, 2010


		2010	2009

Cash Flow From Operations
(dollars per common share – basic)
For the three months ended September 30
Cash flow from operations ⁽¹⁾		1.04	0.43

For the nine months ended September 30
Cash flow from operations ⁽¹⁾		2.89	1.55

Ratios
For the twelve months ended September 30
Return on capital employed (%) ⁽²⁾		7.9	3.7
Return on capital employed (%) ⁽³⁾		5.7	2.6

Net debt to cash flow from operations (times) ⁽⁴⁾		2.0	7.0

Interest coverage on long-term debt (times)
	Net earnings ⁽⁵⁾	6.0	1.9
	Cash flow from operations ⁽⁶⁾	9.7	5.9

As at September 30
Total debt to total debt plus shareholders' equity (%) ⁽⁷⁾		25	29

Common Share Information
As at September 30
Share price at end of trading
	Toronto Stock Exchange – Cdn$	33.50	37.40
	New York Stock Exchange – US$	32.55	34.56

Common share options outstanding (thousands)		70 763	73 784

For the nine months ended September 30
Average number outstanding, weighted monthly (thousands)		1 561 650	1 061 074

Refer to the Quarterly Operating Summary for a discussion of financial measures not prepared in accordance with Canadian generally accepted accounting principles (GAAP).


		Three months ended							Nine months ended				Twelve months ended
			Sept 30 2010	June 30 2010	Mar 31 2010	Dec 31 2009	Sept 30 2009			Sept 30 2010	Sept 30 2009			Dec 31 2009

OIL SANDS
Production ^(a)
Total production (excluding Syncrude)			306.6	295.5	202.3	278.9	305.3			268.6	294.8			290.6
	Firebag ^(k)		50.4	55.7	55.7	51.1	54.3			53.9	48.4			49.1
	MacKay River ^(k)		28.8	32.5	31.8	31.7	26.5	***		31.0	26.5	***		29.7	***
Syncrude			31.7	38.9	32.3	39.3	37.4	***		34.3	37.4	***		38.5	***
Sales ^(a) (excluding Syncrude)
Light sweet crude oil			84.5	99.0	61.0	100.8	89.6			81.6	99.2			99.6
Diesel			25.8	30.7	12.9	31.4	36.9			23.2	28.4			29.1
Light sour crude oil			165.8	143.1	80.5	142.4	146.8			130.1	133.5			135.7
Bitumen			21.2	37.4	42.3	13.0	14.3			33.6	11.3			11.8

Total sales			297.3	310.2	196.7	287.6	287.6			268.5	272.4			276.2

Average sales price ^(1), ^(b) (excluding Syncrude)
Light sweet crude oil*			75.49	77.55	80.84	77.71	71.99			77.63	63.68			67.26
Other (diesel, light sour crude oil and bitumen)*			66.39	68.53	69.53	72.93	67.51			67.95	61.01			64.18
Total*			68.97	71.41	73.03	74.61	68.91			70.89	61.98			65.29
Total			67.53	69.79	70.21	65.42	62.01			69.05	60.32			61.66

Syncrude average sales price ^(1), ^(b)			78.83	77.32	83.21	78.81	75.17			79.79	75.17			77.36

Cash operating costs and Total operating costs – Total operations (excluding Syncrude) ^(c)
Cash costs			32.95	32.70	46.50	35.10	30.65			36.20	30.30			31.50
Natural gas			0.60	2.55	5.40	3.40	1.55			2.50	2.05			2.40
Imported bitumen			0.05	0.65	2.95	0.20	0.05			1.00	0.05			0.05

Cash operating costs ⁽²⁾			33.60	35.90	54.85	38.70	32.25			39.70	32.40			33.95
Project start-up costs			0.75	0.55	0.55	0.50	0.45			0.60	0.45			0.45

Total cash operating costs ⁽³⁾			34.35	36.45	55.40	39.20	32.70			40.30	32.85			34.40
	Depreciation, depletion and amortization		9.00	15.35	12.65	10.00	7.60			12.25	7.35			8.00

Total operating costs ⁽⁴⁾			43.35	51.80	68.05	49.20	40.30			52.55	40.20			42.40

Cash operating costs and Total operating costs – Syncrude ^(c)****
Cash costs			39.20	28.75	39.60	29.65	29.50			35.40	29.50			29.60
Natural gas			2.75	2.85	4.50	3.45	2.10			3.30	2.10			2.90

Cash operating costs ⁽²⁾			41.95	31.60	44.10	33.10	31.60			38.70	31.60			32.50
Project start-up costs			—	—	—	—	—			—	—			—

Total cash operating costs ⁽³⁾			41.95	31.60	44.10	33.10	31.60			38.70	31.60			32.50
Depreciation, depletion and amortization			14.85	11.35	13.70	11.80	12.70			13.15	12.70			12.15

Total operating costs ⁽⁴⁾			56.80	42.95	57.80	44.90	44.30			51.85	44.30			44.65

Cash operating costs and Total operating costs – In situ bitumen production only ^(c)
Cash costs			17.15	13.65	12.30	14.25	13.25			14.30	14.70			14.55
Natural gas			5.25	5.05	7.05	6.05	4.30			5.80	5.55			5.70

Cash operating costs ⁽⁵⁾			22.40	18.70	19.35	20.30	17.55			20.10	20.25			20.25
Project start-up costs			2.50	1.45	0.95	1.35	0.65			1.60	1.30			1.35

Total cash operating costs ⁽⁶⁾			24.90	20.15	20.30	21.65	18.20			21.70	21.55			21.60
Depreciation, depletion and amortization			5.90	4.70	5.05	6.65	5.95			5.20	6.20			6.35

Total operating costs ⁽⁷⁾			30.80	24.85	25.35	28.30	24.15			26.90	27.75			27.95

Suncor Energy Inc.
050 2010 Third Quarter For more information about Suncor Energy, visit our website www.suncor.com


		Three months ended						Nine months ended			Twelve months ended
			Sept 30 2010	June 30 2010	Mar 31 2010	Dec 31 2009	Sept 30 2009		Sept 30 2010	Sept 30 2009		Dec 31 2009

NATURAL GAS
Gross production
Natural gas ^(d)
	Continuing operations		380	398	419	424	335		399	207		262
	Discontinued operations		120	138	230	250	182		162	97		135
Natural gas liquids and crude oil ^(a)
	Continuing operations		5.4	5.5	6.2	6.2	4.8		5.7	2.3		3.3
	Discontinued operations		2.2	2.8	7.8	8.8	5.9		4.3	3.4		4.8
Total gross production ^(f)
	Continuing operations		412	431	456	461	363		433	221		282
	Discontinued operations		134	155	277	303	218		188	117		164

Average sales price from continuing operations ⁽¹⁾
Natural gas ^(g)			3.66	3.42	5.34	3.92	2.70		4.24	3.43		3.63
Natural gas ^(g)*			3.66	3.42	5.34	3.91	2.68		4.24	3.41		3.62
Natural gas liquids and crude oil ^(b)			68.03	82.82	74.71	65.74	58.31		73.66	51.89		59.41


		Three months ended						Nine months ended			Twelve months ended
			Sept 30 2010	June 30 2010	Mar 31 2010	Dec 31 2009	Sept 30 2009***		Sept 30 2010	Sept 30 2009***		Dec 31 2009***

INTERNATIONAL AND OFFSHORE
East Coast Canada
Production ^(a)
Terra Nova			17.2	27.2	29.6	24.0	16.0		24.6	16.0		20.8
Hibernia			32.3	30.1	30.2	26.3	28.5		30.9	28.5		27.2
White Rose			16.8	13.3	14.8	13.3	5.1		14.9	5.1		10.0

Total production			66.3	70.6	74.6	63.6	49.6		70.4	49.6		58.0

Average sales price ^(1), ^(b)			78.78	76.88	78.69	77.71	75.22		78.11	75.22		76.86

International
Production ^(e)
North Sea
	Buzzard		58.6	49.3	58.6	59.9	29.4		55.5	29.4		47.8
	Production from discontinued operations		25.2	22.7	27.5	31.1	25.2		25.2	25.2		28.7

Total North Sea			83.8	72.0	86.1	91.0	54.6		80.7	54.6		76.5
Other International
	Libya		35.4	35.4	35.4	26.0	42.7		35.4	42.7		32.6
	Syria*****		16.5	12.8	—	—	—		9.9	—		—
	Production from discontinued operations		4.2	11.1	11.7	12.0	11.3		9.0	11.3		11.7

Total Other International			56.1	59.3	47.1	38.0	54.0		54.3	54.0		44.3

Total production			139.9	131.3	133.2	129.0	108.6		135.0	108.6		120.8

Average sales price from continuing operations ^{(1), (l)}
Buzzard			75.60	78.57	72.36	68.71	72.02		75.35	72.02		69.53
Other International			74.90	76.14	73.40	79.18	75.60		76.16	75.60		78.05

Total International and Offshore Production ^(e)			206.2	201.9	207.8	192.6	158.2		205.4	158.2		178.8

Suncor Energy Inc.
052 2010 Third Quarter For more information about Suncor Energy, visit our website www.suncor.com


				Three months ended						Nine months ended			Twelve months ended
					Sept 30 2010	June 30 2010	Mar 31 2010	Dec 31 2009	Sept 30 2009		Sept 30 2010	Sept 30 2009		Dec 31 2009

REFINING AND MARKETING
	Eastern North America
		Refined product sales ^(h)
			Transportation fuels
			Gasoline		22.5	22.5	21.0	23.0	18.3		22.0	11.7		14.6
			Distillate		11.7	12.5	12.3	13.9	10.3		12.2	7.0		8.8

			Total transportation fuel sales		34.2	35.0	33.3	36.9	28.6		34.2	18.7		23.4
			Petrochemicals		2.5	2.8	2.2	1.2	1.7		2.5	1.2		0.8
			Asphalt		3.7	3.0	1.8	2.0	2.4		2.8	1.3		1.5
			Other		6.0	6.0	4.3	1.9	3.0		5.4	1.6		2.0

		Total refined product sales			46.4	46.8	41.6	42.0	35.7		44.9	22.8		27.7

		Crude oil supply and refining
			Processed at refineries ^(h)		30.7	30.6	31.0	28.3	25.5		30.8	16.2		29.6
			Utilization of refining capacity ^(j)		90	90	91	83	94		90	90		87

	Western North America
		Refined product sales ^(h)
			Transportation fuels
			Gasoline		19.9	19.2	18.1	18.4	16.1		19.1	11.1		13.0
			Distillate		17.4	16.3	16.9	15.6	11.8		16.9	7.4		9.5

			Total transportation fuel sales		37.3	35.5	35.0	34.0	27.9		36.0	18.5		22.5
			Asphalt		1.5	1.5	1.2	0.9	1.7		1.4	1.4		1.3
			Other		3.7	5.2	4.4	6.0	4.6		4.5	2.5		3.4

		Total refined product sales			42.5	42.2	40.6	40.9	34.2		41.9	22.4		27.2

		Crude oil supply and refining
			Processed at refineries ^(h)		36.6	31.7	33.5	33.4	27.8		34.0	19.3		33.6
			Utilization of refining capacity ^(j)		101	87	92	96	100		94	101		97


			Three months ended											Nine months ended					Twelve months ended
				Sept 30 2010		June 30 2010		Mar 31 2010		Dec 31 2009		Sept 30 2009			Sept 30 2010		Sept 30 2009			Dec 31 2009

NETBACKS – Continuing Operations
Natural Gas ^(g)
		Average price realized ⁽⁸⁾		4.76		5.06		6.23		5.02		3.69			5.37		4.12			4.50
		Royalties		(0.50	)	(0.06	)	(0.91	)	(0.71	)	(0.18	)		(0.50	)	(0.10	)		(0.37	)
		Operating costs		(1.92	)	(2.10	)	(1.67	)	(1.88	)	(1.80	)		(1.90	)	(1.77	)		(1.80	)

		Operating netback		2.34		2.90		3.65		2.43		1.71			2.97		2.25			2.33
		Depreciation, depletion and amortization		(8.36	)	(4.88	)	(3.36	)	(2.84	)	(3.06	)		(5.64	)	(3.02	)		(2.95	)
		Administrative expenses and other		0.17		(0.48	)	0.40		(1.67	)	(2.34	)		0.21		(2.07	)		(1.91	)

		Earnings before income taxes		(5.85	)	(2.46	)	0.69		(2.08	)	(3.69	)		(2.46	)	(2.84	)		(2.53	)

International and Offshore
	East Coast Canada ^(b)
		Average price realized ⁽⁸⁾		81.06		78.99		80.79		79.69		77.85			80.28		77.85			79.07
		Royalties		(25.49	)	(28.45	)	(28.78	)	(25.26	)	(21.02	)		(27.63	)	(21.02	)		(23.82	)
		Operating costs		(9.08	)	(8.19	)	(8.48	)	(7.61	)	(12.99	)		(8.58	)	(12.99	)		(9.45	)

		Operating netback		46.49		42.35		43.53		46.82		43.84			44.07		43.84			45.80
		Depreciation, depletion and amortization		(26.44	)	(24.08	)	(23.38	)	(26.56	)	(17.48	)		(24.58	)	(17.48	)		(23.47	)
		Administrative expenses and other		(1.55	)	0.91		(0.13	)	(1.61	)	(0.89	)		(0.22	)	(0.89	)		(1.36	)

		Earnings before income taxes		18.50		19.18		20.02		18.65		25.47			19.27		25.47			20.97

	North Sea – Buzzard ^(b)
		Average price realized ⁽⁸⁾		77.43		80.35		74.19		70.38		75.49			77.17		75.49			71.64
		Operating costs		(4.73	)	(5.35	)	(4.92	)	(4.57	)	(6.29	)		(4.98	)	(6.29	)		(4.99	)

		Operating netback		72.70		75.00		69.27		65.81		69.20			72.19		69.20			66.65
		Depreciation, depletion and amortization		(23.19	)	(21.83	)	(22.76	)	(25.24	)	(18.54	)		(22.64	)	(18.54	)		(23.60	)
		Administrative expenses and other		(5.13	)	(3.72	)	(3.35	)	(2.20	)	(2.83	)		(4.09	)	(2.83	)		(2.36	)

		Earnings before income taxes		44.38		49.45		43.16		38.37		47.83			45.46		47.83			40.69

	Other International ^(l)
		Average price realized ⁽⁸⁾		75.24		76.61		73.92		79.97		76.02			76.60		76.02			78.19
		Royalties		(32.06	)	(36.99	)	(43.28	)	(32.12	)	(46.46	)		(37.91	)	(46.46	)		(39.88	)
		Operating costs		(5.06	)	(7.87	)	(3.81	)	(6.03	)	(2.21	)		(5.74	)	(2.21	)		(4.05	)

		Operating netback		38.12		31.75		26.83		41.82		27.35			32.95		27.35			34.26
		Depreciation, depletion and amortization		(4.97	)	(4.64	)	(4.29	)	(6.39	)	(1.54	)		(4.68	)	(1.54	)		(3.86	)
		Administrative expenses and other		(6.29	)	(5.09	)	(6.63	)	(11.46	)	(5.98	)		(5.95	)	(5.98	)		(8.60	)

		Earnings before income taxes		26.86		22.02		15.91		23.97		19.83			22.32		19.83			21.80

Suncor Energy Inc.
054 2010 Third Quarter For more information about Suncor Energy, visit our website www.suncor.com

Certain financial measures referred to in the Highlights and Quarterly Operating Summary are not prescribed by Canadian generally accepted accounting principles (GAAP). Suncor includes cash flow from operations, return on capital employed and cash and total operating costs per barrel data because investors may use this information to analyze operating performance, leverage and liquidity. The additional information should not be considered in isolation or as a substitute for measures of performance prepared in accordance with GAAP.


(1) Average sales price	–	This operating statistic is calculated before royalties (where applicable) and net of related transportation costs.
(2) Cash operating costs	–	Include cash costs that are defined as operating, selling and general expenses (excluding inventory changes), accretion expense and the cost of bitumen imported from third parties. Per barrel amounts are based on total production volumes. For a reconciliation of this non-GAAP financial measure see Management's Discussion and Analysis.
(3) Total cash operating costs	–	Include cash operating costs – Total operations as defined above and cash start-up costs. Per barrel amounts are based on total production volumes.
(4) Total operating costs	–	Include total cash operating costs – Total operations as defined above and non-cash operating costs. Per barrel amounts are based on total production volumes.
(5) Cash operating costs – In situ bitumen production	–	Include cash costs that are defined as operating, selling and general expenses (excluding inventory changes) and accretion expense. Per barrel amounts are based on in situ production volumes only.
(6) Total cash operating costs – In situ bitumen production	–	Include cash operating costs – In situ bitumen production as defined above and cash start-up operating costs. Per barrel amounts are based on in situ production volumes only.
(7) Total operating costs – In situ bitumen production	–	Include total cash operating costs – In situ bitumen production as defined above and non-cash operating costs. Per barrel amounts are based on in situ production volumes only.
(8) Average price realized	–	This operating statistic is calculated before transportation costs and royalties and excludes the impact of hedging activities.


		Three months ended September 30				Nine months ended September 30
($ millions)		2010		2009		2010		2009

Revenues
	Operating revenues	8 101		5 651		23 967		10 863
	Less: Royalties	(587	)	(440	)	(1 528	)	(586	)

	Operating revenues (net of royalties)	7 514		5 211		22 439		10 277
	Energy supply and trading activities	1 119		2 608		2 050		6 896
	Interest and other income	3		438		72		439

		8 636		8 257		24 561		17 612

Expenses
	Purchases of crude oil and products	3 494		2 284		10 922		4 502
	Operating, selling and general	1 882		1 668		5 520		4 188
	Energy supply and trading activities	1 164		2 572		1 999		6 857
	Transportation	165		122		471		246
	Depreciation, depletion and amortization (note 5)	1 070		523		2 939		1 103
	Accretion of asset retirement obligations	44		38		132		94
	Exploration	67		84		160		123
	Loss (gain) on disposal of assets	(105	)	(10	)	(133	)	12
	Project start-up costs	21		12		48		38
	Financing expenses (income) (note 7)	(142	)	(347	)	146		(416	)

		7 660		6 946		22 204		16 747

Earnings Before Income Taxes		976		1 311		2 357		865

Provisions for (Recovery of) Income Taxes(note 8)
	Current	275		445		705		649
	Future	92		(99	)	261		(514	)

		367		346		966		135

Net earnings from continuing operations		609		965		1 391		730
Net earnings (loss) from discontinued operations(note 4)		413		(36	)	827		(41	)

Net Earnings		1 022		929		2 218		689

Net Earnings from Continuing Operations per Common Share (dollars)
	Basic	0.39		0.72		0.89		0.68
	Diluted	0.39		0.71		0.88		0.67

Net Earnings per Common Share (dollars), (note 9)
	Basic	0.65		0.69		1.42		0.64
	Diluted	0.65		0.68		1.41		0.63

Cash dividends		0.10		0.10		0.30		0.20


			Three months ended September 30				Nine months ended September 30
($ millions)			2010		2009		2010		2009

Net earnings			1 022		929		2 218		689
Other comprehensive income (loss), net of tax
	Change in foreign currency translation adjustment		168		(186	)	(268	)	(250	)
		Reclassification to net earnings	44		—		44		—
	Gain on derivative contracts designated as cash flow hedges		—		1		—		1
		Reclassification to net earnings	(1	)	—		(1	)	2

Comprehensive Income			1 233		744		1 993		442

Suncor Energy Inc.
056 2010 Third Quarter For more information about Suncor Energy, visit our website www.suncor.com

($ millions)

September 30
2010

December 31
2009

Assets

Current assets

Cash and cash equivalents

598

505

Accounts receivable

4 051

3 703

Inventories

3 100

2 947

Income taxes receivable

718

587

Future income taxes

359

332

Assets of discontinued operations (note 4)

137

257

Total current assets

8 963

8 331

Property, plant and equipment, net

54 853

54 198

Other assets

448

491

Goodwill

3 201

3 201

Future income taxes

193

Assets of discontinued operations (note 4)

950

3 332

Total assets

68 468

69 746

Liabilities and Shareholders' Equity

Current liabilities

Short-term debt

Current portion of long-term debt (note 13)

518

Accounts payable and accrued liabilities

6 416

6 307

Income taxes payable

819

1 254

Future income taxes

Liabilities of discontinued operations (note 4)

242

Total current liabilities

7 832

7 848

Long-term debt (note 13)

11 534

13 855

Accrued liabilities and other

4 222

4 372

Future income taxes

8 571

8 367

Liabilities of discontinued operations (note 4)

581

1 193

Shareholders' equity

35 728

34 111

Total liabilities and shareholders' equity

68 468

69 746


		Three months ended September 30				Nine months ended September 30
($ millions)		2010		2009		2010		2009

Operating Activities
Net earnings from continuing operations		609		965		1 391		730
Adjustments for:
	Depreciation, depletion and amortization	1 070		523		2 939		1 103
	Future income taxes	92		(99	)	261		(514	)
	Accretion of asset retirement obligations	44		38		132		94
	Unrealized foreign exchange gain on U.S. dollar denominated long-term debt (note 7)	(252	)	(400	)	(136	)	(657	)
	Change in fair value of derivative contracts (note 6)	—		(333	)	(253	)	1 039
	Loss (gain) on disposal of assets	(105	)	(10	)	(133	)	12
	Stock-based compensation	80		125		—		228
	Gain on effective settlement of pre-existing contract with Petro-Canada	—		(438	)	—		(438	)
	Other	(93	)	61		(241	)	(127	)
	Exploration expenses	40		52		74		83
Decrease (increase) in non-cash working capital related to operating activities (note 10)		21		(22	)	(751	)	(679	)

Cash flow provided by continuing operations		1 506		462		3 283		874
Cash flow provided by discontinued operations		138		211		459		228

Cash flow provided by operating activities		1 644		673		3 742		1 102

Investing Activities
Capital and exploration expenditures		(1 443	)	(888	)	(3 966	)	(2 590	)
Other investments		(16	)	25		(19	)	(6	)
Proceeds from disposal of assets		143		9		265		36
Cash acquired through business combination		—		248		—		248
Increase in non-cash working capital related to investing activities		(109	)	(30	)	(250	)	(708	)

Cash flow used in continuing investing activities		(1 425	)	(636	)	(3 970	)	(3 020	)
Cash flow provided by (used in) discontinued investing activities		1 390		(81	)	2 409		(121	)

Cash flow used in investing activities		(35	)	(717	)	(1 561	)	(3 141	)

Financing Activities
Increase in short-term debt		—		—		—		1
Net increase (decrease) in revolving-term debt		(1 318	)	311		(1 672	)	2 209
Issuance of common shares under stock option plan		12		8		47		30
Dividends paid on common shares		(155	)	(155	)	(462	)	(249	)

Cash flow provided by (used in) financing activities		(1 461	)	164		(2 087	)	1 991

Increase (Decrease) in Cash and Cash Equivalents		148		120		94		(48	)
Effect of Foreign Exchange on Cash and Cash Equivalents		(5	)	(18	)	(1	)	(25	)
Cash and Cash Equivalents at Beginning of Period		455		485		505		660

Cash and Cash Equivalents at End of Period		598		587		598		587

Suncor Energy Inc.
058 2010 Third Quarter For more information about Suncor Energy, visit our website www.suncor.com


($ millions)	Share Capital	Contributed Surplus		Accumulated Other Comprehensive Income (Loss)		Retained Earnings

At December 31, 2008	1 113	288		97		13 025
Net earnings	—	—		—		689
Dividends paid on common shares	—	—		—		(249	)
Issued for cash under stock option plan	38	(8	)	—		—
Issued under dividend reinvestment plan	2	—		—		—
Stock-based compensation expense	—	77		—		—
Issued for Petro-Canada acquisition (note 2)	18 878	—		—		—
Fair value of Petro-Canada stock options exchanged for Suncor stock options	—	147		—		—
Income tax benefit of stock option deduction in the U.S.	—	4		—		—
Change in accumulated other comprehensive income (loss)	—	—		(247	)	—

At September 30, 2009	20 031	508		(150	)	13 465

At December 31, 2009	20 053	526		(233	)	13 765
Net earnings	—	—		—		2 218
Dividends paid on common shares	—	—		—		(462	)
Issued for cash under stock option plans	61	(14	)	—		—
Issued under dividend reinvestment plan	6	—		—		(6	)
Stock-based compensation expense	—	39		—		—
Change in accumulated other comprehensive income (loss)	—	—		(225	)	—

At September 30, 2010	20 120	551		(458	)	15 515


Three months ended September 30
	Oil Sands				Natural Gas				International and Offshore				Refining and Marketing				Corporate, Energy Trading and Eliminations				Total
($ millions)	2010		2009		2010		2009		2010		2009		2010		2009		2010		2009		2010		2009

EARNINGS
Revenues
Operating revenues	1 728		1 190		161		90		1 063		474		5 139		3 850		10		47		8 101		5 651
Less: Royalties	(290	)	(219	)	(19	)	(6	)	(278	)	(215	)	—		—		—		—		(587	)	(440	)

Operating revenues (net of royalties)	1 438		971		142		84		785		259		5 139		3 850		10		47		7 514		5 211
Energy supply and trading activities	—		—		—		—		—		—		—		—		1 119		2 608		1 119		2 608
Intersegment revenues	709		987		19		32		173		97		55		2		(956	)	(1 118	)	—		—
Interest and other income	115		438		—		—		—		—		—		—		(112	)	—		3		438

	2 262		2 396		161		116		958		356		5 194		3 852		61		1 537		8 636		8 257

Expenses
Purchases of crude oil and products	226		16		—		—		—		16		4 270		3 258		(1 002	)	(1 006	)	3 494		2 284
Operating, selling and general	1 060		981		89		79		111		39		553		409		69		160		1 882		1 668
Energy supply and trading activities	—		—		—		—		—		—		—		—		1 164		2 572		1 164		2 572
Transportation	63		62		44		14		16		15		50		35		(8	)	(4	)	165		122
Depreciation, depletion and amortization	298		242		330		97		307		81		120		96		15		7		1 070		523
Accretion of asset retirement obligations	30		30		7		5		7		3		—		—		—		—		44		38
Exploration	1		2		2		50		64		32		—		—		—		—		67		84
Gain on disposal of assets	—		—		(89	)	(5	)	—		—		(16	)	(5	)	—		—		(105	)	(10	)
Project start-up costs	21		12		—		—		—		—		—		—		—		—		21		12
Financing expenses (income)	4		—		1		—		4		1		3		—		(154	)	(348	)	(142	)	(347	)

	1 703		1 345		384		240		509		187		4 980		3 793		84		1 381		7 660		6 946

Earnings (loss) before income taxes	559		1 051		(223	)	(124	)	449		169		214		59		(23	)	156		976		1 311
Income taxes	(147	)	(313	)	56		27		(213	)	(76	)	(62	)	(14	)	(1	)	30		(367	)	(346	)

Net earnings (loss) from continuing operations	412		738		(167	)	(97	)	236		93		152		45		(24	)	186		609		965

CAPITAL AND EXPLORATION EXPENDITURES – continuing operations	(962	)	(603	)	(43	)	(39	)	(175	)	(154	)	(152	)	(88	)	(111	)	(4	)	(1 443	)	(888	)

Suncor Energy Inc.
060 2010 Third Quarter For more information about Suncor Energy, visit our website www.suncor.com

Schedules of Segmented Data from Continuing Operations (continued)
(unaudited)


Nine months ended September 30
	Oil Sands				Natural Gas				International and Offshore				Refining and Marketing				Corporate, Energy Trading and Eliminations				Total
($ millions)	2010		2009		2010		2009		2010		2009		2010		2009		2010		2009		2010		2009

EARNINGS
Revenues
Operating revenues	5 094		2 953		547		194		3 283		474		14 991		7 106		52		136		23 967		10 863
Less: Royalties	(542	)	(365	)	(58	)	(6	)	(928	)	(215	)	—		—		—		—		(1 528	)	(586	)

Operating revenues (net of royalties)	4 552		2 588		489		188		2 355		259		14 991		7 106		52		136		22 439		10 277
Energy supply and trading activities	—		—		—		—		—		—		—		—		2 050		6 896		2 050		6 896
Intersegment revenues	1 877		1 527		87		54		467		97		206		2		(2 637	)	(1 680	)	—		—
Interest and other income	305		438		—		—		—		—		39		—		(272	)	1		72		439

	6 734		4 553		576		242		2 822		356		15 236		7 108		(807	)	5 353		24 561		17 612

Expenses
Purchases of crude oil and products	728		242		—		—		163		16		12 545		5 718		(2 514	)	(1 474	)	10 922		4 502
Operating, selling and general	3 274		2 977		234		146		281		39		1 605		754		126		272		5 520		4 188
Energy supply and trading activities	—		—		—		—		—		—		—		—		1 999		6 857		1 999		6 857
Transportation	203		178		82		22		67		15		143		44		(24	)	(13	)	471		246
Depreciation, depletion and amortization	1 021		622		647		174		870		81		352		203		49		23		2 939		1 103
Accretion of asset retirement obligations	90		82		20		8		20		3		2		1		—		—		132		94
Exploration	6		8		13		83		141		32		—		—		—		—		160		123
Loss (gain) on disposal of assets	11		17		(126	)	(20	)	—		—		(19	)	15		1		—		(133	)	12
Project start-up costs	45		38		—		—		3		—		—		—		—		—		48		38
Financing expenses (income)	4		—		(3	)	—		(28	)	1		2		—		171		(417	)	146		(416	)

	5 382		4 164		867		413		1 517		187		14 630		6 735		(192	)	5 248		22 204		16 747

Earnings (loss) before income taxes	1 352		389		(291	)	(171	)	1 305		169		606		373		(615	)	105		2 357		865
Income taxes	(347	)	(68	)	79		41		(643	)	(76	)	(177	)	(117	)	122		85		(966	)	(135	)

Net earnings (loss) from continuing operations	1 005		321		(212	)	(130	)	662		93		429		256		(493	)	190		1 391		730

CAPITAL AND EXPLORATION EXPENDITURES – continuing operations	(2 642	)	(2 097	)	(113	)	(189	)	(608	)	(154	)	(395	)	(141	)	(208	)	(9	)	(3 966	)	(2 590	)

These interim consolidated financial statements have been prepared in accordance with Canadian generally accepted accounting principles and follow the same accounting policies and methods of computation as, and should be read in conjunction with, the most recent annual financial statements. Certain information and disclosures normally required to be included in notes to the annual consolidated financial statements have been condensed or omitted.

In the opinion of management, these interim consolidated financial statements contain all adjustments of a normal and recurring nature necessary to present fairly Suncor Energy Inc.'s (Suncor) financial position at September 30, 2010 and the results of its operations and cash flows for the three and nine month periods ended September 30, 2010 and 2009.

Certain prior period comparative figures have been reclassified to conform to the current period presentation.

On August 1, 2009, Suncor completed its merger with Petro-Canada. The company has accounted for this business combination as prescribed by Canadian Institute of Chartered Accountants (CICA) Handbook section 1581 "Business Combinations." As the acquirer, the company is required to recognize Petro-Canada assets and liabilities as at August 1, 2009. The results of Petro-Canada operations are included in the consolidated financial statements of the company from August 1, 2009.

The following estimated fair values were assigned to the net assets of Petro-Canada as at August 1, 2009:


($ millions)

Current assets		4 645
Property, plant and equipment		27 407
Other assets		537

	Total assets	32 589

Current liabilities		3 741
Long-term debt		4 410
Accrued liabilities and other		3 416
Future income taxes		4 570

	Total liabilities	16 137

Net assets purchased		16 452
Goodwill		3 178

	Total purchase price	19 630

The purchase price allocation was based on best estimates by Suncor's management and was based principally on valuations prepared by independent valuation specialists. Management finalized the purchase price allocation during the second quarter of 2010 and did not make any amendments to the preliminary allocation.

Suncor Energy Inc.
062 2010 Third Quarter For more information about Suncor Energy, visit our website www.suncor.com

During the first quarter of 2010, as a result of planned divestitures of the company's assets in Trinidad and Tobago, The Netherlands and certain assets in the United Kingdom (U.K.) (described in note 4), the company combined its International and East Coast Canada segments into one new segment, International and Offshore. Continuing operations for the International and Offshore segment are comprised of activity offshore Newfoundland and Labrador, including interests in the Hibernia, Terra Nova, White Rose and Hebron oilfields, and the exploration for, and production of, crude oil and natural gas in the U.K., Norway, Libya and Syria.

The company is divesting certain non-core assets as part of its continuing strategic alignment.

On August 31, 2010, the company completed the sale of non-core natural gas properties located in west central Alberta (Bearberry and Ricinus) for net proceeds of $275 million.

On September 30, 2010, the company completed the sale of non-core assets in southern Alberta (Wildcat Hills) for net proceeds of $351 million.

In the first quarter of 2010, the company completed the sale of its oil and gas producing assets in the U.S. Rockies for net proceeds of US$481 million (Cdn$502 million). In the second quarter of 2010, the company completed the sale of non-core natural gas properties located in northeast British Columbia (Blueberry and Jedney) for net proceeds of $383 million, and non-core assets in central Alberta (Rosevear and Pine Creek) for net proceeds of $229 million.

On August 5, 2010, the company completed the Trinidad and Tobago asset sale for net proceeds of US$378 million (Cdn$383 million).

On August 13, 2010, the company completed the sale of its shares in Petro-Canada Netherlands BV for net proceeds of €316 million (Cdn$420 million).

On September 8, 2010, the company reached an agreement to sell non-core U.K. offshore assets (Scott/Telford and Triton) for gross proceeds of £240 million. The sale is expected to close during the first quarter of 2011 and is subject to closing conditions and regulatory approvals typical of transactions of this nature.

Net income from discontinued operations reported in the Consolidated Statements of Earnings is as follows:


		Three months ended September 30
		Natural Gas				International and Offshore				Total
($ millions)		2010		2009		2010		2009		2010		2009

Revenues
	Operating revenues⁽¹⁾	53		86		174		119		227		205
	Less: Royalties	(8	)	(10	)	—		—		(8	)	(10	)

	Operating revenues (net of royalties)	45		76		174		119		219		195
	Gain on disposal of assets	271		—		169		—		440		—

		316		76		343		119		659		195

Expenses
	Operating, selling and general	14		35		16		53		30		88
	Transportation	9		6		4		5		13		11
	Depreciation, depletion and amortization	27		51		110		47		137		98
	Accretion of asset retirement obligations	2		2		4		5		6		7
	Exploration	1		—		11		45		12		45
	Financing expenses (income)	—		—		3		(1	)	3		(1	)

		53		94		148		154		201		248

	Earnings before income taxes	263		(18	)	195		(35	)	458		(53	)
	Income taxes	66		(4	)	(21	)	(13	)	45		(17	)

	Net earnings	197		(14	)	216		(22	)	413		(36	)

Suncor Energy Inc.
064 2010 Third Quarter For more information about Suncor Energy, visit our website www.suncor.com


		Nine months ended September 30
		Natural Gas				International and Offshore			Total
($ millions)		2010		2009		2010	2009		2010		2009

Revenues
	Operating revenues⁽¹⁾	277		148		546	119		823		267
	Less: Royalties	(41	)	(26	)	—	—		(41	)	(26	)

	Operating revenues (net of royalties)	236		122		546	119		782		241
	Gain on disposal of assets	646		—		169	—		815		—

		882		122		715	119		1 597		241

Expenses
	Operating, selling and general	64		51		88	53		152		104
	Transportation	24		9		18	5		42		14
	Depreciation, depletion and amortization	95		84		169	47		264		131
	Accretion of asset retirement obligations	8		4		15	5		23		9
	Exploration	1		—		16	45		17		45
	Financing expenses (income)	7		—		11	(1	)	18		(1	)

		199		148		317	154		516		302

	Earnings before income taxes	683		(26	)	398	(35	)	1 081		(61	)
	Income taxes	175		(7	)	79	(13	)	254		(20	)

	Net earnings	508		(19	)	319	(22	)	827		(41	)

The assets and liabilities of discontinued operations presented on the Consolidated Balance Sheets are as follows:



		Natural Gas		International and Offshore		Total
($ millions)		September 30 2010	December 31 2009	September 30 2010	December 31 2009	September 30 2010	December 31 2009

Assets
	Current assets	7	34	130	223	137	257
	Property, plant and equipment, net	202	1 600	748	1 732	950	3 332

	Total assets	209	1 634	878	1 955	1 087	3 589

Liabilities
	Current liabilities	5	64	50	178	55	242
	Accrued liabilities and other	74	286	256	404	330	690
	Future income taxes	—	31	251	472	251	503

	Total liabilities	79	381	557	1 054	636	1 435

During the third quarter of 2010, the company recognized a write-down of $106 million related to certain North Sea assets in the International and Offshore operating segment. An agreement to sell these assets was entered into during the quarter and the assets were written down to reflect fair value less cost to sell.

During the third quarter of 2010, the company recognized a charge of $222 million to reflect the write-down of certain assets in the Natural Gas operating segment to reflect fair value based on discounted future cash flows.

During the second quarter of 2010, the company recognized a write-down of $189 million related to certain extraction equipment in the Oil Sands operating segment. Also during the second quarter of 2010, the company recognized a charge of $44 million in the Natural Gas operating segment to reflect the write-down of certain Western Canada and Alaska land leases.

These charges are included in depreciation, depletion and amortization expenses and net earnings from discontinued operations in the Consolidated Statements of Earnings.

Derivatives are financial instruments that either imitate or counter the price movements of stocks, bonds, currencies, commodities and interest rates. Suncor uses derivatives to reduce its exposure to fluctuations in commodity prices and foreign currency exchange rates and to manage interest rate or currency-sensitive assets and liabilities. Suncor also uses derivatives for trading purposes. When used in a trading activity, the company is attempting to realize a gain on the fluctuations in the market value of the derivative.

Hedge accounting is a method for recognizing the gains, losses, revenues and expenses associated with the items in a hedging relationship at the time when the underlying transaction impacts earnings. Suncor elects to use hedge accounting on certain derivatives linked to future commodity and financial transactions.

Physical trading commodity contracts that exceed the company's expected purchase, sale or usage requirements are accounted for as derivative financial instruments whereby realized and unrealized gains and losses, and the underlying settlement of these contracts is recognized and reported on a net basis in Energy Supply and Trading Activities revenue. The related inventory is carried at fair value less costs to sell, with changes in fair value recognized as gains or losses within Energy Supply and Trading Activities revenue.

The company's financial instruments in the Consolidated Balance Sheets consist of cash and cash equivalents, accounts receivable, derivative contracts, substantially all current liabilities, long-term debt, and a portion of non-current accrued liabilities and other. Unless otherwise noted, carrying values reflect the current fair value of the company's financial instruments.

The estimated fair values of recognized financial instruments have been determined based on the company's assessment of available market information and appropriate valuation methodologies based on industry accepted third-party models; however, these 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 in the market (see page 77 of Suncor's 2009 Annual Report for further detail). As at September 30, 2010, there were no significant changes to the distribution of the fair value hierarchy used to value financial instruments.

The company's fixed-term debt is accounted for under the amortized cost method, with the exception of the portion of debt where future interest payments have been swapped from fixed to floating payments, which is accounted for at fair value. Upon initial recognition, the cost of the debt is its fair value, adjusted for any associated transaction costs. The company does not recognize gains or losses arising from changes in the fair value of this debt until the gains or losses are realized. Gains or losses on

Suncor Energy Inc.
066 2010 Third Quarter For more information about Suncor Energy, visit our website www.suncor.com

our U.S. dollar denominated long-term debt resulting from changes in the exchange rate are recognized in the period in which they occur. At September 30, 2010, the carrying value of the fixed-term debt accounted for under the amortized cost method was $10.0 billion (December 31, 2009 – $10.1 billion) and the fair value was $11.4 billion (December 31, 2009 – $10.7 billion).

At September 30, 2010, the company had interest rate swaps classified as fair value hedges outstanding until August 2011, relating to fixed-rate debt. The fair value of these swaps totalled $8 million at September 30, 2010 (December 31, 2009 – $18 million), and was recorded in accounts receivable in the Consolidated Balance Sheets. There was no ineffectiveness recognized on these interest rate swaps during the three and nine month periods ended September 30, 2010 and September 30, 2009.

At September 30, 2010, the company had no outstanding cash flow hedges in place (December 31, 2009 – nil).

The company periodically enters into derivative contracts which although not accounted for as hedges because they have not been documented as such, or do not qualify under GAAP, are believed to be economically effective at mitigating exposure to commodity price movements and are an important component of Suncor's overall risk management program. The earnings impact associated with these contracts for the three month period ended September 30, 2010, was a loss of $11 million, net of income taxes of $3 million (2009 – a gain of $43 million, net of income taxes of $15 million). During the nine month period ended September 30, 2010, the earnings impact was a gain of $70 million, net of income taxes of $24 million (2009 – loss of $658 million, net of income taxes of $232 million).

The company's Energy Trading group also uses physical and financial energy contracts, including swaps, forwards and options to earn trading revenues. These energy contracts are comprised of crude oil, natural gas and refined products contracts.

The earnings impact associated with these contracts for the three month period ended September 30, 2010, was a loss of $6 million, net of income taxes of $2 million (2009 – a loss of $1 million, net of income taxes of less than $1 million). During the nine month period ended September 30, 2010, the earnings impact was a gain of $44 million, net of income taxes of $18 million (2009 – loss of $37 million, net of income taxes of $16 million).

The company is exposed to a number of different financial risks arising from normal course business exposures, as well as the company's use of financial instruments. These risk factors include market risks relating to commodity prices, 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 Risk Management Committee (RMC) is charged with the oversight of the company's risk management for trading activities, which are defined as strategic hedging, optimization trading, marketing and speculative trading. The RMC, acting under board authority, meets regularly to monitor limits on risk exposures, review policy compliance and validate risk-related methodologies and procedures. All risk management activity is carried out by specialist teams that have the appropriate skills, experience and supervision with the appropriate financial and management controls.

At September 30, 2010, the company's exposure to risks arising from the use of financial instruments had not changed significantly from December 31, 2009.

Suncor Energy Inc.
068 2010 Third Quarter For more information about Suncor Energy, visit our website www.suncor.com

The merger of Suncor Energy Inc. and Petro-Canada resulted in a deemed year end for income tax purposes for both companies effective July 31, 2009. This deemed year end generated an increase in income taxes payable as well as an acceleration of the tax payments. The tax payments that would ordinarily have been payable in monthly installments over the August to December period were due and payable at September 30, 2009.

In the third quarter of 2009, the provision for future income tax increased by $152 million due in part to the merger. The combined provincial allocation of both entities caused an increase to the future income tax rate, the impact of which is recorded in net earnings.


		Three months ended September 30		Nine months ended September 30
($ millions)		2010	2009	2010	2009

Net earnings		1 022	929	2 218	689

(millions of common shares)
Weighted-average number of common shares		1 563	1 349	1 562	1 076
Dilutive securities:
	Options issued under stock-based compensation plans	11	13	12	13

	Weighted-average number of diluted common shares	1 574	1 362	1 574	1 089

(dollars per common share)
Basic earnings per share ^(a)		0.65	0.69	1.42	0.64
Diluted earnings per share ^(b)		0.65	0.68	1.41	0.63

Non-cash working capital is comprised of current assets and current liabilities, other than cash and cash equivalents, future income taxes and the current portion of long-term debt.

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

The following is the net periodic benefit cost for the three and nine month periods ended September 30:

Suncor Energy Inc.
070 2010 Third Quarter For more information about Suncor Energy, visit our website www.suncor.com

There are a number of legacy Suncor and legacy Petro-Canada plans that were in place prior to the merger on August 1, 2009, for which granting of options ended on July 31, 2009. For details of the terms and conditions of these plans, refer to pages 88 and 89 of Suncor's 2009 Annual Report.

This plan replaced the pre-merger stock option plans of legacy Suncor and legacy Petro-Canada. Outstanding options that are cancelled, expire or otherwise result in no underlying common share being issued, will be available for issuance as options under this plan. These options have a seven-year life and vest annually over a three-year period.

Options granted under this plan before August 1, 2010 included a tandem stock appreciation right. The company granted 15,000 options with tandem stock appreciation rights during the third quarter of 2010. Effective August 1, 2010, options granted under this plan no longer include tandem stock appreciation rights. The company granted 21,000 options with no tandem stock appreciation rights after August 1, 2010.

Legacy Petro-Canada had a SARs plan for which grants ended on July 31, 2009. For details of the terms and conditions of this plan, refer to page 90 of Suncor's 2009 Annual Report.

The company granted 7,000 SARs under this new plan during the third quarter of 2010. These SARs have a seven-year life and vest annually over a three-year period.

For details of the terms and conditions of the Performance Share Unit (PSU), Restricted Share Unit (RSU) and Deferred Share Unit (DSU) plans, refer to page 91 of Suncor's 2009 Annual Report.

The following table summarizes the stock-based compensation expense (recovery) recorded for all plans within operating, selling and general expense on the Consolidated Statements of Earnings:

Suncor Energy Inc.
072 2010 Third Quarter For more information about Suncor Energy, visit our website www.suncor.com


($ millions)		September 30 2010		December 31 2009

Fixed-term debt, redeemable at the option of the company
6.85% Notes, denominated in U.S. dollars, due in 2039 (US$750)		772		785
6.80% Notes, denominated in U.S. dollars, due in 2038 (US$900)		956		972
6.50% Notes, denominated in U.S. dollars, due in 2038 (US$1150)		1 185		1 204
5.95% Notes, denominated in U.S. dollars, due in 2035 (US$600)		571		578
5.95% Notes, denominated in U.S. dollars, due in 2034 (US$500)		515		523
5.35% Notes, denominated in U.S. dollars, due in 2033 (US$300)		264		266
7.15% Notes, denominated in U.S. dollars, due in 2032 (US$500)		515		523
6.10% Notes, denominated in U.S. dollars, due in 2018 (US$1250)		1 287		1 308
6.05% Notes, denominated in U.S. dollars, due in 2018 (US$600)		631		643
5.00% Notes, denominated in U.S. dollars, due in 2014 (US$400)		420		429
4.00% Notes, denominated in U.S. dollars, due in 2013 (US$300)		308		313
7.00% Debentures, denominated in U.S. dollars, due in 2028 (US$250)		267		271
7.875% Debentures, denominated in U.S. dollars, due in 2026 (US$275)		318		325
9.25% Debentures, denominated in U.S. dollars, due in 2021 (US$300)		390		402
5.39% Series 4 Medium Term Notes, due in 2037		600		600
5.80% Series 4 Medium Term Notes, due in 2018		700		700
6.70% Series 2 Medium Term Notes, due in August 2011		500		500

		10 199		10 342
Revolving-term debt, with variable interest rates
Commercial paper, bankers' acceptances and LIBOR loans		1 570		3 244

Total unsecured long-term debt		11 769		13 586
Secured long-term debt		13		13
Capital leases		322		326
Debt fair value adjustment for interest swaps		8		18
Deferred financing costs		(60	)	(63	)

		12 052		13 880

Current portion of long-term debt
	6.70% Series 2 Medium Term Notes	(500	)	—
	Capital leases	(10	)	(14	)
	Debt fair value adjustment for interest swaps	(8	)	(11	)

Total current portion of long-term debt		(518	)	(25	)

Total long-term debt		11 534		13 855

At September 30, 2010, unutilized lines of credit were $5,742 million, as follows:


($ millions)	2010

Facility that has a term period of one year and expires in 2011	4
Facility that is fully revolving for a period of four years and expires in 2013	206
Facilities that are fully revolving for a period of five years and expire in 2013	7 320
Facilities that can be terminated at any time at the option of the lenders	466

Total available credit facilities	7 996

Credit facilities supporting outstanding commercial paper, bankers' acceptances and LIBOR loans	(1 570	)
Credit facilities supporting letters of credit	(684	)

Total unutilized credit facilities	5 742

The company's primary capital management objective is to maintain 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 monitored through net debt to cash flow from operations ⁽¹⁾ and total debt to total debt plus shareholders' equity.

Net debt to cash flow from operations is calculated as short-term debt plus total long-term debt less cash and cash equivalents divided by the twelve-month trailing cash flow from operations.

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.

Financial covenants associated with the company's various banking and debt arrangements are reviewed regularly and controls are in place to maintain compliance with these covenants. The company complied with all financial covenants for the periods ended September 30, 2010 and December 31, 2009.

During the third quarter of 2010, the company's strategy was to maintain the measure set out in the following schedule. The company believes that maintaining the capital target helps to provide the company access to capital at a reasonable cost by maintaining solid investment-grade credit ratings.

At September 30 ($ millions)

Capital Measure
Target

2010

2009

Components of ratios

Short-term debt

Current portion of long-term debt

518

Long-term debt

11 534

13 826

Total debt

12 054

13 850

Less: Cash and cash equivalents

598

587

Net debt

11 456

13 263

Shareholders' equity

35 728

33 854

Total capitalization (total debt plus shareholders' equity)

47 782

47 704

Cash flow from operations ⁽¹⁾ (trailing twelve months)

5 641

1 901

Net debt to cash flow from operations

<2.0 times

2.0

7.0

Total debt to total debt plus shareholders' equity

25%

29%

Suncor Energy Inc.
074 2010 Third Quarter For more information about Suncor Energy, visit our website www.suncor.com

The company's capital management strategy, objectives, definitions, monitoring measures and targets have not changed significantly from the prior period.

The components of accumulated other comprehensive income (loss), net of income taxes, are as follows:


*		Excludes the impact of realized hedging activities.
**		If capital employed were to include capitalized costs related to major projects in progress, the return on capital employed would be as stated on this line.
***		For the three and nine months ended September 30, 2009, and the twelve months ended December 31, 2009, operating summary information reflects results of operations since the merger with Petro-Canada on August 1, 2009.
****		Users are cautioned that the Syncrude cash costs per barrel measure may not be fully comparable to similar information calculated by other entities (including Suncor's own cash costs per barrel excluding Syncrude) due to differing treatments for operating and capital costs among producers.
*****		Commercial production for Syria commenced on April 19, 2010.


	Three months ended September 30
(dollars)	2010	2009

Basic earnings per share from discontinued operations	0.26	(0.03	)
Diluted earnings per share from discontinued operations	0.26	(0.03	)


	Nine months ended September 30
(dollars)	2010	2009

Basic earnings per share from discontinued operations	0.53	(0.04	)
Diluted earnings per share from discontinued operations	0.53	(0.04	)


	Quantity	Average Price	⁽¹⁾
Crude oil	(bpd)	(US$/bbl)		Period

Purchased puts	55 000	60.00		2010
Sold puts	54 609	60.00		2010
Collars – floor	49 674	50.00		2010
Collars – cap	49 978	68.06		2010


($ millions)	Risk Management		Energy Trading		Total

Fair value of contracts at December 31, 2009	(312	)	(47	)	(359	)
Fair value of contracts realized during the period	157		(60	)	97
Changes in fair value attributable to market price and other market changes during the period	94		62		156

Fair value of contracts outstanding at September 30, 2010 ^(a), ^(b)	(61	)	(45	)	(106	)


(a)	thousands of barrels per day	(e)	thousands of barrels of oil equivalent per day	(i)	$ millions
(b)	dollars per barrel	(f)	millions of cubic feet equivalent per day	(j)	percentage
(c)	dollars per barrel rounded to the nearest $0.05	(g)	dollars per thousand cubic feet equivalent	(k)	thousands of barrels of bitumen per day
(d)	millions of cubic feet per day	(h)	thousands of cubic metres per day	(l)	dollars per barrel of oil equivalent


Crude oil, refined products, etc.		1m ³ (cubic metre) = approx. 6.29 barrels


	Three months ended September 30				Pension Benefits Nine months ended September 30
millions)	2010		2009		2010		2009

Current service costs	21		19		64		49
Interest costs	42		31		126		57
Expected return on plan assets	(36	)	(24	)	(107	)	(44	)
Amortization of net actuarial loss	2		5		6		15

Net periodic benefit cost	29		31		89		77


	Other Post-Retirement Benefits
	Three months ended September 30		Nine months ended September 30
($ millions)	2010	2009	2010	2009

Current service costs	2	2	6	5
Interest costs	7	4	19	9

Net periodic benefit cost	9	6	25	14


	Number (thousands)	Common Shares Amount ($ millions)

Balance as at December 31, 2009	1 559 778	20 053
Issued for cash under stock option plans	2 847	61
Issued under dividend reinvestment plan	197	6

Balance as at September 30, 2010	1 562 822	20 120


	Number (thousands)		Weighted- Average Exercise Price ($)

Outstanding, December 31, 2009	72 024		32.52
Granted	4 296		31.86
Exercised	(2 847	)	14.91
Forfeited/expired	(2 710	)	42.47

Outstanding, September 30, 2010	70 763		32.50


	Number (thousands)

	PSU		RSU		DSU

Outstanding, December 31, 2009	3 247		4 250		2 616
Granted	1 672		2 835		36
Redeemed	(282	)	(101	)	(211	)
Forfeited	(803	)	(417	)	—
Reinvested	21		34		22

Outstanding, September 30, 2010	3 855		6 601		2 463