-----BEGIN PRIVACY-ENHANCED MESSAGE----- Proc-Type: 2001,MIC-CLEAR Originator-Name: webmaster@www.sec.gov Originator-Key-Asymmetric: MFgwCgYEVQgBAQICAf8DSgAwRwJAW2sNKK9AVtBzYZmr6aGjlWyK3XmZv3dTINen TWSM7vrzLADbmYQaionwg5sDW3P6oaM5D3tdezXMm7z1T+B+twIDAQAB MIC-Info: RSA-MD5,RSA, CUlR8Q3JUdkqq8IkhPJrCgyYc9Ck7VR92rej+bYNKTUqv7kb+BIhIYH/Gqd6ItJD Jjgkig69VRJhS7L9pd63BA== 0001047469-08-011325.txt : 20081029 0001047469-08-011325.hdr.sgml : 20081029 20081029114921 ACCESSION NUMBER: 0001047469-08-011325 CONFORMED SUBMISSION TYPE: 6-K PUBLIC DOCUMENT COUNT: 16 CONFORMED PERIOD OF REPORT: 20080930 FILED AS OF DATE: 20081029 DATE AS OF CHANGE: 20081029 FILER: COMPANY DATA: COMPANY CONFORMED NAME: SUNCOR ENERGY INC CENTRAL INDEX KEY: 0000311337 STANDARD INDUSTRIAL CLASSIFICATION: PETROLEUM REFINING [2911] IRS NUMBER: 000000000 STATE OF INCORPORATION: A0 FISCAL YEAR END: 1231 FILING VALUES: FORM TYPE: 6-K SEC ACT: 1934 Act SEC FILE NUMBER: 001-12384 FILM NUMBER: 081146867 BUSINESS ADDRESS: STREET 1: 112 4TH AVENUE SW PO BOX 38 STREET 2: CALGARY CITY: ALBERTA CANADA STATE: A0 ZIP: T2P 2V5 BUSINESS PHONE: 4032698100 MAIL ADDRESS: STREET 1: 112 FOURTH AVE SW BOX 38 STREET 2: CALGARY CITY: ALBERTA CANADA ZIP: T2P 2V5 FORMER COMPANY: FORMER CONFORMED NAME: SUNCOR INC DATE OF NAME CHANGE: 19970430 FORMER COMPANY: FORMER CONFORMED NAME: GREAT CANADIAN OIL SANDS & SUN OIL CO LTD DATE OF NAME CHANGE: 19791129 6-K 1 a2188650z6-k.htm FORM 6-K
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FORM 6-K

SECURITIES AND EXCHANGE COMMISSION
WASHINGTON, D.C. 20549

Report of Foreign Private Issuer
Pursuant to Rule 13a-16 or 15d-16 of
the Securities Exchange Act of 1934


For the month of: October 2008		Commission File Number: 1-12384

SUNCOR ENERGY INC.
(Name of registrant)

112 Fourth Avenue S.W.
P.O. Box 38
Calgary, Alberta
Canada, T2P 2V5

Indicate by check mark whether the registrant files or will file annual reports under cover of Form 20-F or Form 40-F:

Form 20-F o Form 40-F þ

Indicate by check mark whether the registrant by furnishing the information contained in this Form is also thereby furnishing the information to the SEC pursuant to Rule 12g3-2(b) under the Securities Exchange Act of 1934:

Yes o No þ

If "Yes" is marked, indicate the number assigned to the registrant in connection with Rule 12g3-2(b):

N/A

CONTROLS AND PROCEDURES

A.: Disclosure Controls and Procedures

See page 14 of Exhibit 99.2.

B.: Changes in Internal Control Over Financial Reporting

See page 14 of Exhibit 99.2.

SIGNATURES

Pursuant to the requirements of the Securities Exchange Act of 1934, the registrant has duly caused this report to be signed on its behalf by the undersigned, thereunto duly authorized.


	SUNCOR ENERGY INC.
Date: October 29, 2008
	By:	/s/ TERRENCE J. HOPWOOD Terrence J. Hopwood Senior Vice President and General Counsel

EXHIBIT INDEX

Exhibit			Description of Exhibit

	99.1		Press Release Including 2008 Outlook
	99.2		Interim Management's Discussion and Analysis for the third fiscal quarter ended September 30, 2008
	99.3		Interim Unaudited Financial Statements of Suncor Energy Inc. for the nine months ended September 30, 2008
	99.4		Certification of the President and Chief Executive Officer
	99.5		Certification of the Senior Vice President and Chief Financial Officer

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CONTROLS AND PROCEDURES
SIGNATURES
EXHIBIT INDEX
EX-99.1 2 a2188650zex-99_1.htm EXHIBIT 99.1
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Exhibit 99.1

Press Release Including 2008 Outlook


THIRD QUARTER 2008
Report to shareholders for the period ended September 30, 2008

Suncor Energy releases third quarter results

All financial figures are unaudited and in Canadian dollars unless noted otherwise. Certain financial measures referred to in this document are not prescribed by Canadian generally accepted accounting principles (GAAP). For a description of these measures, see "Non-GAAP Financial Measures" in Suncor's 2008 third quarter management's discussion and analysis. This document makes reference to barrels of oil equivalent (boe). A boe conversion ratio of six thousand cubic feet of natural gas: one barrel of crude oil is based on an energy equivalency conversion method primarily applicable at the burner tip and does not represent a value equivalency at the wellhead. Accordingly, boe measures may be misleading, particularly if used in isolation.

Suncor Energy Inc. recorded third quarter 2008 net earnings of $815 million ($0.87 per common share), compared to $627 million ($0.68 per common share) for the third quarter of 2007. Excluding unrealized foreign exchange impacts on the company's U.S. dollar denominated long-term debt, and project start-up costs, earnings for the third quarter of 2008 were $971 million ($1.04 per common share), compared to $538 million ($0.58 per common share) in the third quarter of 2007.

The increase in earnings was primarily due to improved price realizations for our oil sands products. This was partially offset by an increase in operating expenses, product purchases and Crown royalties in our oil sands business.

Net earnings for the first nine months of 2008 were $2.352 billion, compared to $1.941 billion for the same period in 2007. Excluding unrealized foreign exchange impacts on the company's U.S. dollar denominated long-term debt, the impact of income tax rate reductions on opening future income tax liabilities, and project start-up costs, earnings for the first nine months of 2008 were $2.580 billion, compared to $1.712 billion in the same period for 2007.

Cash flow from operations in the third quarter of 2008 was $1.346 billion, compared to $957 million in the same period of 2007. Cash flow from operations for the first nine months of 2008 was $3.912 billion, compared to $2.809 billion in the first nine months of 2007.

The increase in earnings over the first nine months of 2008, and the increase in cash flow from operations for the three and nine month periods ended September 30, 2008, are due primarily to the same factors that impacted third quarter earnings.

Suncor's total upstream production averaged 281,000 barrels of oil equivalent (boe) per day in the third quarter of 2008, compared to 274,300 boe per day in the third quarter of 2007. In Suncor's natural gas business, production was 213 million cubic feet equivalent (mmcfe) per day compared to third quarter 2007 production of 211 mmcfe per day. Oil sands production contributed 245,600 barrels per day (bpd) in the third quarter of 2008 compared to 239,100 bpd in the third quarter of 2007.

Oil sands cash operating costs in the third quarter of 2008 averaged $34.00 per barrel, compared to $25.10 per barrel during the third quarter of 2007. The increase in cash operating costs per barrel was due to higher operating expenses and increased natural gas input costs.

Production volumes were lower than planned in the third quarter and as a result, Suncor has adjusted its production outlook to an annual average of 235,000 bpd with a corresponding increase in cash operating costs to a target of $36.50 per barrel.

"We've had a challenging quarter with unplanned maintenance, including issues at our hydrogen facilities that impacted our product mix," said Rick George, president and chief executive officer.

Production volumes in the quarter were impacted by unplanned maintenance activities in our upgrading and extraction assets. In addition, an unplanned shutdown of facilities that supply hydrogen reduced production of higher-value sweet (low sulphur) synthetic crude oil and diesel. Repairs to the facilities are complete and production of sweet products is increasing.

"With these issues behind us, we continue to target production of approximately 300,000 barrels per day by the end of the year as we work to realize the full value of our expanded oil sands production facilities," said George.

Commissioning of Suncor's $2.3 billion expansion to one of two oil sands upgraders is nearing completion and production volumes are expected to continue ramping up in 2009 toward design capacity of 350,000 bpd.

Bitumen feedstock from Suncor's Firebag in-situ operations is also expected to increase following the lifting in July of a production cap imposed by provincial regulators. Wells that had been shut in have begun steaming and small amounts of incremental production are expected to come on line in the fourth quarter of 2008.

Operations and growth update

On October 23, Suncor announced an update to the schedule of its $20.6 billion Voyageur growth strategy, including reporting plans for 2009 capital spending of $6 billion.

"In light of current financial market conditions, we've modified our capital plans for 2009, reducing targeted spending by more than a third," said George. "Our aim is to ensure we are living within our means during a time of market uncertainty, while also making the strategic spending decisions that will allow us to continue on our growth path."

The company's growth outlook maintains spending and construction timelines for the third and fourth stages of Firebag in-situ operations. Completion of Firebag Stages 3 and 4 (in 2009 and 2010, respectively) is expected to provide increases in bitumen production and future cash flow.

In the near-term, Suncor expects to scale down spending and the pace of construction on the company's planned Voyageur upgrader, delaying targeted completion by approximately one year to the end of 2012. Stages 5 and 6 of Firebag in-situ operations are expected to proceed but, as they are at relatively early phases of development, spending and scheduling plans remain flexible to respond to market conditions.

Of the total Voyageur capital budget of $20.6 billion, Suncor had spent approximately $5.3 billion at the end of the third quarter.

"We remain committed to an integrated expansion strategy and targeted oil sands production of 550,000 barrels per day," said George. "However, we've always had options available to us in terms of how the expansion is rolled out – and we believe in the current economic environment it's prudent to exercise that flexibility."

The company's 2009 capital spending plan is expected to be financed through undrawn credit facilities and cash flow from operations. As Suncor invests for future growth, prudent debt management remains a priority. Net debt levels increased to $5.3 billion in the third quarter of 2008 from $3.2 billion at year-end 2007.

Outlook

Suncor's outlook provides management's targets for 2008 in certain key areas of the company's business. Users of this information are cautioned that actual results can vary from the targets disclosed.


		Nine Month Actuals Ended September 30, 2008	2008 Full Year Outlook

Oil Sands
Production (bpd) ⁽¹⁾		222 600	235 000
	Diesel	9%	9%
	Sweet	33%	34%
	Sour	57%	56%
	Bitumen	1%	1%
Realization on crude sales basket ⁽¹⁾		WTI @ Cushing less Cdn$3.37 per barrel	WTI @ Cushing less Cdn$3.50 to Cdn$4.50 per barrel
Cash operating costs ⁽¹⁾ ⁽²⁾		$37.45 per barrel	$36.50 per barrel

Natural Gas
	Production ⁽¹⁾ ⁽³⁾ (mmcf equivalent per day)	223	220
	Natural gas	91%	91%
	Liquids	9%	9%

(1): Based on third quarter results and expectations for the fourth quarter, the outlook for oil sands production, cash operating costs, realization on crude sales basket and natural gas production has been adjusted. The June 30 oil sands production outlook was 240,000 to 250,000 bpd (diesel 12%, sweet 38%, sour 50%, and bitumen 0%) with a corresponding cash operating cost range of $35.00 to $36.00 per barrel. The June 30 realization on crude sales basket was WTI @ Cushing less Cdn$2.50 to Cdn$3.50. The June 30 natural gas production outlook was 210 to 220 mmcf equivalent per day.
(2): Cash operating cost estimates are based on the following assumptions: production volumes and sales mix as described in the table above and a natural gas price of $8.00 per gigajoule at AECO. Based on natural gas prices in the first nine months of 2008 and expectations for the fourth quarter, the natural gas price assumption has been adjusted. The June 30 natural gas price assumption was $6.70 per gigajoule at AECO. This estimate also includes costs incurred for third-party bitumen purchases. Cash operating costs per barrel are not prescribed by Canadian generally accepted accounting principles (GAAP). This non-GAAP financial measure does not have any standardized meaning and therefore is unlikely to be comparable to similar measures presented by other companies. Suncor includes this non-GAAP financial measure because investors may use this information to analyze operating performance. This information should not be considered in isolation or as a substitute for measures of performance prepared in accordance with GAAP.
(3): Production target includes natural gas liquids (NGL) and crude oil converted into mmcf equivalent at a ratio of one barrel of NGL/crude oil: six thousand cubic feet of natural gas. This conversion ratio is based on an energy equivalency conversion method primarily applicable at the burner tip and does not represent a value equivalency at the wellhead. This mmcf equivalent may be misleading, particularly if used in isolation.

Assumptions used to develop our outlook are based on year-to-date performance and management's best estimates for the remainder of the year.

Factors that could potentially impact Suncor's operations and financial performance in 2008 include:

•: Bitumen supply. Ore grade quality, unplanned mine equipment and extraction plant maintenance, tailings storage and regulatory restrictions could impact 2008 production targets. Production could also be impacted by the availability of third-party bitumen.
•: Planned maintenance to portions of Upgrader 2. Although this maintenance is reflected in operational targets for the year, production estimates could be impacted if unplanned work is identified, or the schedule is impacted by labour or material supply issues.
•: Crude oil hedges. Suncor has hedging agreements for 10,000 bpd in 2008. These costless collar hedges have an average floor of US$59.85 per barrel with an average ceiling of US$101.06 per barrel.

The preceding paragraphs and table contain forward-looking information and users of this information are cautioned that actual results may differ. For additional information on risks, uncertainties and other factors that could cause actual results to differ, please refer to our 2008 Third Quarter Management's Discussion and Analysis, 2007 Annual Report and 2007 Annual Information Form/Form 40-F on file with securities regulators.

Suncor Energy Inc.
Inquiries John Rogers (403) 269-8670 2008 Third Quarter 003

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Exhibit 99.1

EX-99.2 3 a2188650zex-99_2.htm EXHIBIT 99.2
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Exhibit 99.2

Interim Management's Discussion and Analysis for the third fiscal quarter ended September 30, 2008

Management's Discussion and Analysis
October 28, 2008

This Management's Discussion and Analysis (MD&A) contains forward-looking statements. These statements are based on certain estimates and assumptions and involve risks and uncertainties. Users of forward-looking information are cautioned that actual results may differ materially from those expressed or implied. Forward-looking information and the factors or assumptions used to develop such information are identified throughout this MD&A and under the Legal Notice on page 18. For information on risks, uncertainties and other factors that could cause actual results to differ, see page 18.

This MD&A should be read in conjunction with our September 30, 2008 unaudited interim consolidated financial statements and notes. Readers should also refer to our MD&A on pages 10 to 48 of our 2007 Annual Report and to our Annual Information Form (AIF) dated February 27, 2008. All financial information is reported in Canadian dollars (Cdn$) and in accordance with Canadian generally accepted accounting principles (GAAP) unless noted otherwise. The financial measures: cash flow from operations, return on capital employed (ROCE) and cash and total operating costs per barrel referred to in this MD&A are not prescribed by GAAP and are outlined and reconciled in Non-GAAP Financial Measures on page 46 of our 2007 Annual Report, and page 16 of this MD&A.

Certain amounts in prior years have been reclassified to enable comparison with the current year's presentation.

Barrels of oil equivalent (boe) may be misleading, particularly if used in isolation. A boe conversion ratio of six thousand cubic feet (mcf) of natural gas: one barrel of crude oil is based on an energy equivalency conversion method primarily applicable at the burner tip and does not represent a value equivalency at the wellhead.

References to "we," "our," "us," "Suncor," or "the company" mean Suncor Energy Inc., its subsidiaries, partnerships and joint ventures, unless the context otherwise requires.

The tables and charts in this document form an integral part of this MD&A.

Additional information about Suncor filed with Canadian securities commissions and the United States Securities and Exchange Commission (SEC), including periodic quarterly and annual reports and the AIF filed with the SEC under cover of Form 40-F, is available on-line at www.sedar.com, www.sec.gov and our website www.suncor.com. Information contained in or otherwise accessible through our website does not form a part of this MD&A and is not incorporated into the MD&A by reference.

In order to provide shareholders with full disclosure relating to potential future capital expenditures, we have provided cost estimates for significant capital projects that, in some cases, are still in the early stages of development. These costs are preliminary estimates only. The actual amounts are expected to differ and these differences may be material. For a further discussion of our significant capital projects, see the Significant Capital Project Update on page 12.

Selected Financial Information

Industry Indicators

Three months ended
September 30

Nine months ended
September 30

(average for the period)

2008

2007

2008

2007

West Texas Intermediate (WTI) crude oil US$/barrel at Cushing

118.00

75.40

113.30

66.20

Canadian 0.3% par crude oil Cdn$/barrel at Edmonton

123.00

80.25

115.90

73.10

Light/heavy crude oil differential US$/barrel WTI at Cushing less Western Canadian Select at Hardisty

18.05

22.85

20.40

19.60

Natural Gas US$/mcf at Henry Hub

10.10

6.15

9.65

6.90

Natural Gas (Alberta spot) Cdn$/mcf at AECO

9.25

5.60

8.55

6.80

New York Harbour 3-2-1 crack ⁽¹⁾ US$/barrel

10.65

11.95

10.30

15.40

Exchange rate: US$/Cdn$

0.96

0.96

0.98

0.91

(1): New York Harbour 3-2-1 crack is an industry indicator measuring the margin on a barrel of oil for gasoline and distillate. It is calculated by taking two times the New York Harbour gasoline margin plus the New York Harbour distillate margin and dividing by three.


Outstanding Share Data ⁽¹⁾ (as at September 30, 2008)

Common shares			934 916 409
Common share options – total			46 829 297
Common share options – exercisable			25 646 718

(1): On May 14, 2008, the Company implemented a two-for-one stock split of its issued and outstanding common shares.

Suncor Energy Inc.
004 2008 Third Quarter For more information about Suncor Energy, visit our website www.suncor.com

Summary of Quarterly Results


		Three months ended
($ millions, except per share)		Sept 30 2008	June 30 2008	Mar 31 2008	Dec 31 2007	Sept 30 2007	June 30 2007	Mar 31 2007	Dec 31 2006

Revenues		8 946	7 959	5 988	5 185	4 802	4 525	4 053	3 936
Net earnings		815	829	708	1 042	627	738	576	334

Net earnings per common share
	Basic	0.87	0.89	0.76	1.13	0.68	0.80	0.63	0.36
	Diluted	0.86	0.87	0.75	1.10	0.66	0.78	0.61	0.35

Analysis of Consolidated Statements of Earnings and Cash Flows

Net earnings for the third quarter of 2008 were $815 million, compared to $627 million for the third quarter of 2007. Excluding unrealized foreign exchange impacts on the company's U.S. dollar denominated long-term debt, and project start-up costs, earnings for the third quarter of 2008 were $971 million, compared to $538 million in the third quarter of 2007.

Our effective tax rate for the first nine months of 2008 was 29%, compared to 28% in the first nine months of 2007. During the nine months ended September 30, 2008 we recorded $406 million in current income tax expense, compared to $314 million in the nine months ended September 30, 2007 (see page 10 for discussion of cash income taxes).

Suncor Energy Inc.
Inquiries John Rogers (403) 269-8670 2008 Third Quarter 005

Net Earnings Components

This table explains some of the factors impacting net earnings on an after-tax basis. For comparability purposes, readers should rely on the reported net earnings presented in our unaudited interim consolidated financial statements and notes in accordance with Canadian GAAP.


		Three months ended September 30				Nine months ended September 30
($ millions, after-tax)		2008		2007		2008		2007

Earnings before the following items:		971		538		2 580		1 712
	Unrealized foreign exchange gain (loss) on U.S. dollar denominated long-term debt	(150	)	108		(207	)	199
	Impact of income tax rate reductions on opening future income tax liabilities	—		—		—		67
	Project start-up costs	(6	)	(19	)	(21	)	(37	)

Net earnings as reported		815		627		2 352		1 941

Analysis of Segmented Earnings and Cash Flows

Oil Sands

Oil sands recorded 2008 third quarter net earnings of $854 million, compared with $494 million in the third quarter of 2007. Excluding the impact of project start-up costs, earnings for the third quarter of 2008 were $860 million, compared to $511 million in the third quarter of 2007.

Earnings increased primarily as a result of strong price realizations due to higher benchmark WTI crude oil prices. Earnings were negatively impacted by an increase in operating expenses, product purchases and Crown royalties, in addition to decreased production of higher-value sweet crude oil products resulting from an unplanned shutdown of facilities that supply hydrogen used to remove sulphur from synthetic crude oil and diesel fuel.

Purchases of crude oil and products were $175 million in the third quarter of 2008, compared to $68 million in the third quarter of 2007. The increase was primarily a result of purchases of product to facilitate transportation of sour crude shipments during the quarter, in addition to third-party bitumen purchases due to additional upgrading capacity.

Operating expenses were $799 million in the third quarter of 2008, compared to $604 million in the third quarter of 2007. The increase in operating expenses in the third quarter of 2008 was primarily due to higher maintenance expenses aimed at improving reliability, increased energy input costs, higher contract mining costs and increased employee costs resulting from higher overall salaries and an increased number of employees.

Alberta Crown royalty expense was $249 million in the third quarter of 2008, compared to $145 million in the third quarter of 2007. The increase was due mainly to higher revenues resulting from continued strong WTI crude pricing. This increase was partially offset by the impact of both higher operating expenses and higher capital expenditures eligible for deduction under Crown royalty formulas. For a further discussion of Crown royalties, see page 7.

Cash flow from operations was $1.109 billion in the third quarter of 2008, compared to $829 million in the third quarter of 2007. The increase was primarily due to the same factors that impacted oil sands earnings.

Suncor Energy Inc.
006 2008 Third Quarter For more information about Suncor Energy, visit our website www.suncor.com

Net earnings for the first nine months of 2008 were $2.300 billion, compared to $1.438 billion in the first nine months of 2007. Cash flow from operations for the first nine months of 2008 increased to $3.193 billion from $2.086 billion in the first nine months of 2007. The year-to-date increases in net earnings and cash flow from operations were due primarily to the same factors that impacted third quarter oil sands results.

Oil sands production averaged 245,600 barrels per day (bpd) in the third quarter of 2008 compared to production of 239,100 bpd during the third quarter 2007. Unplanned maintenance in our upgrading and extraction assets and wet weather in August that impacted mine production restricted production volumes in the third quarter of 2008. Production volumes in the third quarter of 2007 were impacted by a planned shutdown. Based on third quarter results and expectations for the fourth quarter, the oil sands production outlook has been reduced to an annual average of 235,000 bpd.

Sales volumes during the third quarter of 2008 averaged 219,000 bpd, compared with 223,900 bpd during the third quarter of 2007. The proportion of higher value diesel fuel and sweet crude products decreased to 27% of total sales volumes in the third quarter of 2008, compared to 55% in the third quarter of 2007, primarily due to the unplanned hydrogen facilities shutdown.

The average price realization for oil sands crude products increased to $116.32 per barrel in the third quarter of 2008, compared to $76.97 per barrel in the third quarter of 2007, as a result of a 56% increase in benchmark WTI crude oil prices, partially offset by a decreased premium to WTI for sweet crude blends and an increased discount to WTI for sour crude blends.

During the third quarter of 2008, cash operating costs averaged $34.00 per barrel, compared to $25.10 per barrel during the third quarter of 2007. The increase in cash operating costs per barrel was primarily due to higher operating expenses and increased natural gas input costs. Based on third quarter results and expectations for the fourth quarter, the oil sands cash operating cost outlook has been increased to an annual average of $36.50 per barrel. Refer to page 16 for further details on cash operating costs as a non-GAAP financial measure, including the calculation and reconciliation to GAAP measures.

Oil Sands Operations and Growth Update

Commissioning of Suncor's $2.3 billion expansion to one of two oil sands upgraders is nearing completion and production volumes are expected to continue ramping up toward a target of approximately 300,000 bpd by the end of the year. With additional bitumen feedstock planned to come on line from Firebag, we expect upgrading operations to begin ramping up in 2009 toward design capacity of 350,000 bpd.

Production from Suncor's Firebag in-situ operations had been limited by provincial regulators to 42,000 bpd due to sulphur emissions that exceeded regulatory limits in 2007. With the lifting of the production cap in July, Suncor began steaming new wells in the third quarter and expects small amounts of incremental production to come on line in the fourth quarter of 2008.

On October 23, we announced an update to the schedule of Suncor's $20.6 billion Voyageur growth strategy, including reporting plans for 2009 capital spending of $6 billion.

We believe it is prudent to reduce capital spending from previously anticipated levels during a time of financial market uncertainty that has impacted the cost of issuing new debt. At currently planned spending, we expect to finance our 2009 capital program through existing undrawn credit facilities and cash flow from operations.

The modified capital plan and related growth outlook maintains spending and construction timelines for the third and fourth stages of Firebag in-situ operations. Completion of Firebag Stages 3 and 4 (in 2009 and 2010, respectively) is expected to provide increases in bitumen production and future cash flow.

We had previously expected to complete construction of a third upgrader, the centerpiece of the Voyageur expansion, in late 2011 with oil sands production capacity of 550,000 bpd in place in 2012. Suncor has delayed these plans and is scaling down spending and the pace of construction on the planned upgrader, extending targeted completion by approximately one year to the end of 2012. Stages 5 and 6 of Firebag in-situ operations are expected to proceed but, as they are at relatively early phases of development, spending and scheduling plans remain flexible to respond to market conditions.

Of the total Voyageur capital budget of $20.6 billion, Suncor had spent approximately $5.3 billion at the end of the third quarter.

For an update on our significant growth projects currently in progress see page 12. The information provided in the growth update contains forward-looking statements and users of this information are cautioned that actual results may differ. For additional information on risks, uncertainties and other factors that could cause actual results to differ, please see page 18.

Suncor Energy Inc.
Inquiries John Rogers (403) 269-8670 2008 Third Quarter 007

Oil Sands Crown Royalties

For a description of the Alberta Crown royalty regimes in effect for our oil sands operations, see page 19 of our 2007 Annual Report and note 11 of our third quarter 2008 financial statements.

In the third quarter of 2008, we recorded a pretax royalty estimate of $249 million, compared to $145 million for the third quarter of 2007. In 2008, the estimation process for calculating the quarterly royalty provision was changed from being based on an annual royalty estimate to being based on the actual eligible revenues and costs recorded in the period. If the annualized approach was used for 2008, pretax royalties would have been $86 million higher for the first nine months of 2008.

The following table sets forth our estimates of royalties in the years 2008 through 2012, and certain assumptions on which we have based our estimates.

Oil Sands Mining and In-Situ Royalties


WTI Price/bbl (US$)	80	100	130

Natural gas (Alberta spot) Cdn$/mcf at AECO	7.50	8.00	9.50

Light/heavy oil differential of WTI at Cushing less Maya at the U.S. Gulf Coast US$	14.00	18.00	23.00

Differential of Maya at the U.S. Gulf Coast less Western Canadian Select at Hardisty, Alberta US$	7.00	7.00	7.00

US$/Cdn$ exchange rate	1.00	1.00	1.05

Crown Royalty Expense (based on percentage of total oil sands revenue) %
2008 – Mining synthetic crude oil, in-situ bitumen (25% and 1% min)	8-9	9-10	10-11
2009 – Bitumen (mining old rates – 25% and 1% min; in-situ new rates)	6-8	9-11	11-13
2010 to 2012 – Bitumen (new rates – cap 30% for mining)	6-8	9-11	12-14

The previous table contains forward-looking information and users of this information are cautioned that actual Crown royalty expense may vary from the ranges disclosed in the table. The royalty ranges disclosed in the table were developed using the following assumptions: current agreements with the government of Alberta (assuming the government enacts their proposed framework), royalty rates proposed by the government of Alberta, current forecasts of production, capital and operating costs, and the commodity prices and exchange rates described in the table.

The following material risk factors could cause actual royalty rates to differ materially from the rates contained in the foregoing table:

(i): Pursuant to the new royalty framework, the government proposed on June 30, 2008 a generic "bitumen valuation methodology" for determining the gross revenues less related transportation costs related to bitumen. The proposal uses the Hardisty, Alberta pricing of Western Canadian Select (WCS), a widely traded blend of Alberta bitumen, diluents and conventional heavy oil, as a benchmark. The proposed pricing formula is adjusted for transportation to Hardisty, the value of diluent in the WCS blend and the constituent bitumen quality. The proposal also provides for a floor price based on Maya at the U.S. Gulf Coast if there are unusual market fluctuations affecting WCS relative to the North American market. Following a consultation period with industry, the government expects to implement the new bitumen valuation methodology January 1, 2009, with further refinements for bitumen quality determination expected January 1, 2010. The estimated impact of quality adjustments and other assumptions have been incorporated into the above table. Those assumptions and the final determination of the bitumen valuation methodology may have a material impact on royalties payable to the Crown. For our mining operations, the proposed bitumen methodology is consistent with Suncor's January 2008 Crown Agreement which places certain limitations on the bitumen valuation methodology;
(ii): The government announced in April 2008 it will implement recommendations to enhance how the performance of the royalty regime is measured and reported. They are also in the process of reviewing technical policy details and business rules that are being changed to align with the new royalty framework announced in October 2007. Steps taken by the government may affect the calculation of royalties; and
(iii): Changes in crude oil and natural gas pricing, production volumes, foreign exchange rates, and capital and operating costs for each oil sands project; changes to the generic royalty regime by the government of Alberta; changes in other legislation and the occurrence of unexpected events all have the potential to have an impact on royalties payable to the Crown.

Suncor Energy Inc.
008 2008 Third Quarter For more information about Suncor Energy, visit our website www.suncor.com

Natural Gas

Our natural gas business recorded net earnings of $18 million in the third quarter of 2008, compared with nil during the third quarter of 2007. Net earnings increased primarily as a result of higher revenues driven by stronger price realizations, including higher sulphur prices. These factors were partially offset by higher royalties and dry hole costs, and increased depreciation, depletion and amortization (DD&A) expense resulting from increased production from areas with larger capital bases.

Cash flow from operations for the third quarter of 2008 was $103 million, compared to $47 million in the third quarter of 2007. The increase is primarily due to the same factors affecting net earnings, excluding the impact of DD&A and dry hole costs.

Net earnings in the first nine months of 2008 were $89 million, compared to nil in the first nine months of 2007. Net earnings increased primarily as a result of higher revenues driven by stronger price realizations, higher sulphur prices and increased production, in addition to a gain on the sale of non-core assets. These factors were partially offset by higher royalties and increased DD&A expense. Cash flow from operations for the first nine months of the year was $304 million, compared to $181 million reported in the same period in 2007. The increase is primarily due to the same factors affecting net earnings, excluding the impact of DD&A and the gain on the sale of non-core assets.

Natural gas and liquids production in the third quarter of 2008 was 213 million cubic feet equivalent (mmcfe) per day, compared to 211 mmcfe per day in the third quarter of 2007. The increased production compared to the prior year was primarily due to the addition of new wells. Our 2008 planned production is expected to offset Suncor's estimated purchases of natural gas for internal consumption at our oil sands operations.

Realized natural gas prices in the third quarter of 2008 were $9.10 per thousand cubic feet (mcf), compared to $5.39 per mcf in the third quarter of 2007, reflecting higher benchmark prices.

Refining and Marketing

Refining and marketing recorded 2008 third quarter net earnings of $46 million, compared to net earnings of $69 million in the third quarter of 2007. The decrease in net earnings primarily resulted from reduced margins on gasoline, asphalt and other heavy products as well as significantly lower refined product demand driven by the high prices of finished products, particularly gasoline. These factors were partially offset by gains from energy marketing and trading activities, which increased to $99 million in the third quarter of 2008, from $1 million in the third quarter of 2007. This increase was primarily due to gains on crude oil financial contracts.

As a result of adopting a required FIFO (first-in-first-out) valuation accounting policy for inventory, net earnings were $134 million lower than they would have been under the previous LIFO (last-in-first-out) accounting policy. Under FIFO accounting, earnings are impacted by the change in value of crude feedstock inventories. In the third quarter of 2007, FIFO accounting resulted in a $29 million positive impact. For further details of this change in accounting policy, see page 15.

Cash flow from operations was $85 million in the third quarter of 2008, compared to $126 million in the third quarter of 2007. Cash flow from operations decreased primarily due to the same factors affecting net earnings, excluding the impact of unrealized gains from energy marketing and trading activities.

Suncor Energy Inc.
Inquiries John Rogers (403) 269-8670 2008 Third Quarter 009

During the third quarter of 2008, refinery crude oil utilization was 99%, compared to 102% in the third quarter of 2007. This lower rate was primarily due to unplanned maintenance at our Commerce City, Colorado refinery. In addition, our Sarnia refinery completed a planned maintenance shut-down that began on September 2, 2008 and lasted until October 11, 2008. This turnaround was completed on schedule and on budget, and did not have a significant impact on the quarter over quarter utilization comparison as Sarnia completed a similar scope turnaround during the third quarter of 2007.

Our refining and marketing business recorded net earnings of $232 million for the first nine months of 2008, compared to $413 million during the first nine months of 2007. Cash flow from operations for the first nine months of 2008 was $485 million, compared to $648 million in the first nine months of 2007. The year-to-date decreases in net earnings and cash flow from operations were due to the same factors that impacted third quarter results.

Corporate and Eliminations

After-tax net corporate expense was $103 million in the third quarter of 2008, compared to earnings of $64 million in the third quarter of 2007. Excluding the impact of group elimination entries, after-tax net corporate expense was $115 million in the third quarter of 2008 (earnings of $64 million in the third quarter of 2007). Net expense increased mainly due to unrealized foreign exchange losses on our U.S dollar denominated long-term debt. After-tax unrealized foreign exchange losses on U.S. dollar denominated long-term debt were $150 million in the third quarter of 2008, compared to gains of $108 million in the third quarter of 2007. Group elimination entries increased to $12 million in the third quarter of 2008, from nil in the third quarter of 2007, primarily as a result of profit elimination on inventory sold from oil sands to refining and marketing.

Breakdown of Net Corporate Expense


Three months ended September 30 ($ millions)	2008		2007

Corporate (expense) earnings	(115	)	64
Group eliminations	12		—

Total	(103	)	64

Cash flow from operations was $49 million in the third quarter of 2008, compared to cash used in operations of $45 million in the third quarter of 2007. This was primarily due to a foreign exchange gain on operational activities in the third quarter of 2008, compared to a loss in the third quarter of 2007.

Corporate net expense was $269 million in the first nine months of 2008, compared to net earnings of $90 million in the same period of 2007. Net expense increased mainly due to unrealized foreign exchange losses on our U.S. dollar denominated long-term debt. After-tax unrealized foreign exchange losses on U.S. dollar denominated long-term debt were $207 million in the nine months ended September 30, 2008, compared to gains of $199 million in the first nine months of 2007. Cash used in operations was $70 million in the first nine months of 2008, compared to $106 million in the first nine months of 2007.

Cash Income Taxes

We estimate we will have cash income taxes of 30% to 50% of our effective tax rate during 2008. Thereafter, we anticipate our cash income tax position may fluctuate to a maximum of approximately 100% of our effective tax rate by 2015. Cash income taxes are sensitive to crude oil and natural gas commodity price volatility and the timing of deductibility of capital expenditures for income tax purposes, among other things. This estimate is based on the following assumptions: current forecasts of production, capital and operating costs, the commodity prices and exchange rates described in the table "Oil Sands Mining and In-Situ Royalties" on page 8 and effective income tax rates within 2% of the statutory income tax rates, assuming there are no changes to the current income tax regime. Our outlook on cash income tax is a forward-looking statement and users of this information are cautioned that actual cash income taxes may vary from our outlook.

Suncor Energy Inc.
010 2008 Third Quarter For more information about Suncor Energy, visit our website www.suncor.com

Analysis of Financial Condition and Liquidity

Excluding cash and cash equivalents, short-term debt and future income taxes, Suncor had an operating working capital deficiency of $111 million at the end of the third quarter of 2008, compared to a deficiency of $430 million at the end of the third quarter of 2007, due primarily to an increase in inventory values, reflecting higher commodity prices.

During the first nine months of 2008, net debt increased to $5.260 billion from $3.248 billion at December 31, 2007, primarily due to increased capital spending to fund our growth strategies.

During 2008, the company's $2 billion committed syndicated credit facility was increased to $3.75 billion and its term was extended to 2013, while our $410 million committed bilateral credit facility was reduced to $370 million and extended to 2009.

In May 2008, the company issued 5.80% Medium Term Notes with a principal amount of $700 million under an outstanding $2 billion debt shelf prospectus. Interest on the notes is paid semi-annually, and the notes mature on May 22, 2018. The net proceeds received were added to our general funds to repay outstanding commercial paper, which originally funded our working capital needs, sustaining capital expenditures and growth capital expenditures.

In June 2008, the company issued 6.10% Notes with a principal amount of US$1.25 billion and 6.85% Notes with a principal amount of US$750 million under an amended US$3.65 billion debt shelf prospectus. Interest on the notes is paid semi-annually, and the notes mature on June 1, 2018, and June 1, 2039, respectively. The net proceeds received were added to our general funds, which are used for our working capital needs, sustaining capital expenditures, growth capital expenditures and to repay outstanding commercial paper borrowings.

At September 30, 2008, our undrawn credit facilities were approximately $3.5 billion and we had cash and cash equivalents of approximately $1.3 billion. Outstanding debt shelf prospectuses filed in 2007 enable the company to issue debt in Canada and the United States. We believe we have the capital resources from our undrawn credit facilities and cash flow from operations to meet our current working capital requirements and fund the remainder of our $7.5 billion 2008 capital program and recently announced $6 billion 2009 capital program. For additional information on risks, uncertainties and other factors affecting our ability to fund our capital program, see page 18.

Suncor Energy Inc.
Inquiries John Rogers (403) 269-8670 2008 Third Quarter 011

Significant Capital Project Update

A summary of the progress on our significant projects under construction to support both our growth and sustaining needs is provided below. All projects listed below have received board of directors approval.


		Cost						% complete			Target
		estimate		Estimate		Spent					completion
Project	Plan	$ millions	⁽¹⁾	% Accuracy	⁽¹⁾	to date		Engineering	Construction	⁽²⁾	date

Coker Unit	Expected to increase production capacity by 90,000 bpd	2 100		+13/-7		2 285		100	100		Complete

Naphtha Unit	Increases sweet product mix	650		+10/-10		575		99	45		2009

Steepbank Extraction Plant	New location and new technologies aimed at improving operational performance	850		+10/-10		585		100	60		2009

Firebag Sulphur Plant	Support emission abatement plan at Firebag; capacity to support Stages 1-6	340		+10/-10		220		85	40		2009

North Steepbank Mine Expansion	Expected to supply ore to generate about 180,000 bpd of bitumen	400		+10/-10		110		50	30		2010	⁽³⁾

Voyageur Strategy: Firebag ⁽⁴⁾	Expansion of Firebag 3-6 is expected to generate about 270,000 bpd of bitumen	9 000		+18/-13		2 770	⁽⁵⁾

	– Stage 3							95	40		2009

	– Stage 4 ⁽⁶⁾ ⁽⁷⁾							60	—		2010

	– Stage 5 ⁽⁶⁾ ⁽⁷⁾							10	—		2012	⁽⁸⁾

	– Stage 6 ⁽⁶⁾ ⁽⁷⁾							10	—		2012	⁽⁸⁾

Voyageur Strategy: Upgrader 3 ⁽⁹⁾	Expected to increase production capacity by 200,000 bpd	11 600		+12/-8		2 570	⁽⁵⁾	70	10		2012	⁽⁸⁾

(1): Excludes commissioning and start-up costs. Cost estimates and estimate accuracy reflect budgets approved by Suncor's Board of Directors.
(2): Excludes commissioning and start-up.
(3): As a result of an update in operating plans, management has adjusted its target completion date to 2010 from 2009. Production from the mine expansion is targeted to begin in 2012.
(4): Ramp-up to full capacity of each stage can take up to eighteen months from completion of construction.
(5): Spending to date includes procurement of major project components. For Firebag Stage 3, procurement at September 30, 2008 was 90% complete; for Stage 4, 81% complete; for Stage 5, 15% complete; and for Stage 6, 48%. For Upgrader 3, procurement was 70% complete.
(6): Pending regulatory approval.
(7): Construction of shared and common services is included in Stage 3 construction.
(8): As a result of changes to the timing of capital spending plans, management has adjusted its target completion date to 2012 from 2011.
(9): Construction completion targeted in 2012 with ramp-up to full capacity during 2013.

The previous table contains forward-looking information and users of this information are cautioned that the actual timing, amount of the final capital expenditures and expected results for each of these projects may vary from the plans disclosed in the table. The material risk factors that could cause actual timing, amount of the final capital expenditures and expected results to differ materially from those contained in this table are contained in our 2007 Annual Report, pages 21 to 26. For additional information on risks, uncertainties and other factors that could cause actual results to differ, please see page 18.

The material factors used to develop the target completion dates and cost estimates are: capital spending plans, the current status of procurement, design and engineering phases of the project; updates from third parties on delivery of services and goods associated with the project; and estimates from major projects teams on completion of future phases of the project. We have assumed that commitments from third parties will be honoured and that material delays and increased costs related to the risk factors referred to above, will not be encountered.

Suncor Energy Inc.
012 2008 Third Quarter For more information about Suncor Energy, visit our website www.suncor.com

Derivative Financial Instruments

On January 1, 2008, Suncor adopted the Canadian Institute of Chartered Accountants (CICA) Handbook sections 3862 "Financial Instruments – Disclosures" and 3863 "Financial Instruments – Presentation", which enhance existing disclosures for financial instruments. In particular, section 3862 focuses on the identification of risk exposures and our approach to management of these risks. These new disclosures have been incorporated in the following discussion and in the notes to our unaudited financial statements.

We periodically enter into derivative contracts to hedge against the potential adverse impact of market price volatility due to changes in the underlying indices. We also use physical and financial energy contracts to earn trading and marketing revenues.

We have estimated fair values of financial instruments by assessing 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.

Commodity and Treasury Hedging Activities

To provide an element of stability to future earnings and cash flow, we have approval from the board of directors to fix a price or range of prices for up to approximately 30% of our total planned production of crude oil for specified periods of time. The company has hedged a portion of its forecasted U.S. dollar denominated sales subject to U.S. dollar West Texas Intermediate (WTI) commodity price risk. As of September 30, 2008, costless collar crude oil hedges totaling 10,000 bpd of production were outstanding for the remainder of 2008. Prices for these barrels are fixed within a range from an average of US$59.85/bbl up to an average of US$101.06/bbl. In addition to these hedges, we have crude oil puts for 55,000 bpd of production for 2009 and 2010 that provide us with a floor price of US$60.00/bbl.

In addition to our strategic crude oil hedging program, Suncor uses derivative contracts to hedge risks related to purchases and sales of natural gas and refined products, and to hedge risks specific to individual transactions.

Settlement of our commodity hedging contracts result in cash receipts or payments for the difference between the derivative contract and market rates for the applicable volumes hedged during the contract term. For accounting purposes, amounts received or paid on settlement are recorded as part of the related hedged sales or purchase transactions in the Consolidated Statements of Earnings and Comprehensive Income.

We periodically enter into interest rate swap contracts as part of our strategy to manage exposure to interest rates. The interest rate swap contracts involve an exchange of floating rate and fixed rate interest payments between ourselves and investment grade counterparties. The differentials on the exchange of periodic interest payments are recognized as an adjustment to interest expense. In addition to our interest rate swap contracts, we also manage variability in market interest rates and foreign exchange rates during periods of debt issuance through the use of interest rate locks and foreign exchange forward contracts.

The earnings impact associated with changes in the fair values of our commodity and treasury hedging derivative financial instruments in the third quarter of 2008 was a pretax gain of $74 million (2007 – pretax gain of $2 million). The earnings impact in the first nine months of 2008 was a pretax loss of $14 million (2007 – pretax loss of $9 million).

Energy Marketing and Trading Activities

In addition to derivative contracts used for hedging activities, Suncor uses physical and financial energy derivatives to earn trading and marketing revenues. These energy contracts are comprised of crude oil, natural gas, heating oil and gasoline derivative contracts. The results of these trading activities are reported as revenue and as energy marketing and trading expenses in the Consolidated Statements of Earnings and Comprehensive Income. The net pretax gains associated with our energy marketing and trading activities in the third quarter of 2008 were $99 million (2007 – pretax earnings of $1 million). The net pretax earnings in the first nine months of 2008 were $116 million (2007 – pretax earnings of $26 million).

Suncor Energy Inc.
Inquiries John Rogers (403) 269-8670 2008 Third Quarter 013

Fair Value of Derivative Financial Instruments

The fair value of derivative financial instruments is the estimated amount we would receive (pay) to terminate the contracts. Such amounts, which also represent the unrealized gain (loss) on the contracts, were as follows:


($ millions)		September 30 2008		December 31 2007

Derivative financial instruments accounted for as hedges
	Assets	17		20
	Liabilities	(6	)	(11	)
Derivative financial instruments not accounted for as hedges
	Assets	148		18
	Liabilities	(20	)	(21	)

Net derivative financial instruments		139		6

For further details on our derivative financial instruments, see note 3 to the unaudited interim consolidated financial statements on page 28.

Environmental Regulation and Risk

Production from Suncor's Firebag in-situ operations had been limited by regulators to 42,000 bpd due to sulphur emissions that exceeded regulatory limits in 2007. With the lifting of the production cap during the third quarter, Suncor began steaming new wells, with small amounts of incremental production expected to come on line in the fourth quarter of 2008.

In April 2007, the Canadian federal government introduced the Clean Air regulatory framework, which is expected to regulate both greenhouse gas (GHG) emissions and air pollutants from industrial emitters. Further details on the GHG framework were released in March 2008. Suncor has been engaged in the ongoing consultations on this framework. In support of developing regulation, Suncor submitted production, operations and emissions information for designated facilities to the federal government in May. Draft GHG regulations are expected in fall 2008, with final regulations in fall 2009 and the provisions coming into force on January 1, 2010. The financial impact of this proposed legislation will be dependent on the details of Clean Air Act regulations.

On June 26, 2008, the Energy Resources Conservation Board (ERCB) released a draft directive, Tailings Performance Criteria and Requirements for Oil Sands Mining Schemes, for industry review and comment until September 15, 2008. The directive proposes to establish performance criteria for consolidated tailings (CT) operations, a requirement for specific approval and monitoring of CT ponds, a requirement for reporting tailings plans, and changes to the ERCB annual mine plan requirements and approval process to regulate tailings operations. We do not expect any significant impact resulting from the directive as currently drafted.

There remains uncertainty around the outcome and impacts of climate change and other environmental regulations. Depending on the scope of any final regulations, these impacts may have an adverse effect on our operational and financial results in the future. We continue to actively work to mitigate our environmental impact, investing in renewable energy such as wind power and biofuels, accelerating land reclamation, installing new emission abatement equipment and investigating other mitigation opportunities such as carbon capture and sequestration.

Control Environment

Based on their evaluation as of September 30, 2008, our chief executive officer and chief financial officer concluded that our disclosure controls and procedures (as defined in Rules 13(a) – 15(e) and 15(d) – 15(e) under the United States Securities Exchange Act of 1934 (the Exchange Act)) are effective to ensure that information required to be disclosed in reports that we file or submit under the Exchange Act is recorded, processed, summarized and reported within the time periods specified in Securities and Exchange Commission rules and forms. In addition, as of September 30, 2008, there were no changes in our internal control over financial reporting that occurred during the three month period ended September 30, 2008 that have materially affected, or are reasonably likely to materially affect our internal control over financial reporting. We will continue to periodically evaluate our disclosure controls and procedures and internal control over financial reporting, and will make any modifications from time to time as deemed necessary.

Suncor Energy Inc.
014 2008 Third Quarter For more information about Suncor Energy, visit our website www.suncor.com

Change in Accounting Policies

(a) Inventories

On January 1, 2008 Suncor was required to retroactively adopt CICA Handbook section 3031 "Inventories". Under the new standard, the use of a LIFO (last-in-first-out) based valuation approach for inventory has been eliminated. The standard also requires any impairment to net realizable value of inventory to be written down at each reporting period, with subsequent reversals when applicable. Suncor transitioned to a FIFO (first-in-first-out) based valuation approach for inventory effective January 1, 2008. The impact of adopting this standard is as follows:

Change in Consolidated Balance Sheets

September 30

December 31

($ millions, increase/(decrease))

2008

2007

Inventories

473

404

Total Assets

473

404

Accounts payable and accured liabilities

(25

)

—

Future income taxes

157

121

Retained earnings

341

283

Total liabilities and shareholders' equity

473

404

Change in Consolidated Statements of Earnings and Comprehensive Income


	Three months ended September 30				Nine months ended September 30
($ millions, increase/(decrease))	2008		2007		2008		2007

Purchase of crude oil and products	191		(19	)	(144	)	(94	)
Operating, selling and general	186		89		50		(14	)
Future income taxes	(110	)	(20	)	36		36

Net earnings	(267	)	(50	)	58		72

Per common share – basic (dollars)	(0.28	)	(0.05	)	0.06		0.08
Per common share – diluted (dollars)	(0.28	)	(0.05	)	0.06		0.08

Segmented Net Earnings Impact


		Three months ended September 30				Nine months ended September 30
($ millions, increase/(decrease))		2008		2007		2008		2007

Net earnings
	Oil sands	(135	)	(62	)	(39	)	10
	Refining and marketing	(134	)	29		125		68
	Corporate and eliminations	2		(17	)	(28	)	(6	)

Total		(267	)	(50	)	58		72

(b) Capital Disclosure

On January 1, 2008, Suncor adopted CICA Handbook section 1535 "Capital Disclosures". This section establishes disclosure requirements for management's policies and processes in defining and managing its capital. There is no financial impact to previously reported financial statements as a result of the implementation of this new standard.

(c) Financial Instruments – Disclosures and Presentation

On January 1, 2008, Suncor adopted CICA Handbook sections 3862 "Financial Instruments – Disclosures" and 3863 "Financial Instruments – Presentation", which enhance existing disclosures for financial instruments. In particular, section 3862 focuses on the identification of risk exposures and the company's approach to management of these risks. There is no financial impact to previously reported financial statements as a result of the implementation of this new standard.

Suncor Energy Inc.
Inquiries John Rogers (403) 269-8670 2008 Third Quarter 015

(d) International Financial Reporting Standards

In February 2008, the Accounting Standards Board confirmed that International Financial Reporting Standards (IFRS) will replace Canadian GAAP in 2011 for publicly accountable enterprises. Accordingly, Suncor will be required to report its results under IFRS starting in 2011. We continue to assess the impact of the transition to IFRS on our financial reporting and disclosures. We are developing a full transition plan for compliance, but are not currently able to assess the overall impact of the change. Key disclosures surrounding our transition will be made in our year-end 2008 Consolidated Financial Statements and Management's Discussion and Analysis, consistent with the recent reporting standards requirements release.

Non-GAAP Financial Measures

Certain financial measures referred to in this MD&A, namely cash flow from operations, return on capital employed (ROCE) and oil sands cash and total operating costs per barrel, are not prescribed by GAAP. 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. Suncor includes these non-GAAP financial measures 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.

Suncor provides a detailed numerical reconciliation of ROCE on an annual basis in our annual MD&A, which is to be read in conjunction with our annual consolidated financial statements. For a summarized narrative reconciliation of ROCE calculated on a September 30, 2008 interim basis, please refer to page 40 of our third quarter report to shareholders.

Cash flow from operations is expressed before changes in non-cash working capital. A reconciliation of net earnings to cash flow from operations is provided in the Schedules of Segmented Data, which are an integral part of Suncor's September 30, 2008 unaudited interim consolidated financial statements.

A reconciliation of cash flow from operations on a per common share basis is presented in the following table:

Three months ended
September 30

Nine months ended
September 30

2008

2007

2008

2007

Cash flow from operations ($ millions)

1 346

957

3 912

2 809

Weighted average number of shares
outstanding (millions of shares)

934.5

923.1

930.4

921.6

Cash flow from operations ($ per share)

(A/B

)

1.44

1.04

4.20

3.05

The following tables outline the reconciliation of oil sands cash and total operating costs to expenses included in the Schedules of Segmented Data in the company's financial statements.

Suncor Energy Inc.
016 2008 Third Quarter For more information about Suncor Energy, visit our website www.suncor.com

Oil Sands Operating Costs – Total Operations


		Three months ended September 30						Nine months ended September 30
		2008			2007 ⁽¹⁾			2008			2007 ⁽¹⁾
		$ millions		$/barrel	$ millions		$/barrel	$ millions		$/barrel	$ millions		$/barrel

Operating, selling and general expenses		799			604			2 156			1 769
	Less: natural gas costs, inventory changes, stock-based compensation and other	(183	)		(106	)		(341	)		(243	)
	Less: non-monetary transactions	(25	)		(17	)		(81	)		(80	)
Accretion of asset retirement obligations		14			10			41			30
Taxes other than income taxes		24			15			57			39

Cash costs		629		27.80	506		23.00	1 832		30.00	1 515		24.15
Natural gas		97		4.30	46		2.10	347		5.70	223		3.55
Imported bitumen (net of other reported product purchases)		42		1.90	—		—	107		1.75	3		0.05

Total cash operating costs		768		34.00	552		25.10	2 286		37.45	1 741		27.75
Project start-up costs		8		0.35	24		1.10	29		0.50	47		0.75

Total cash operating costs after start-up costs		776		34.35	576		26.20	2 315		37.95	1 788		28.50
Depreciation, depletion and amortization		151		6.70	126		5.70	412		6.75	334		5.30

Total operating costs		927		41.05	702		31.90	2 727		44.70	2 122		33.80

Production (thousands of barrels per day)		245.6			239.1			222.6			229.8

(1): Prior period amounts have been restated to reflect the change in accounting policy noted on page 15.

Oil Sands Operating Costs – In-Situ Bitumen Production Only


		Three months ended September 30						Nine months ended September 30
		2008			2007			2008			2007
		$ millions		$/barrel	$ millions		$/barrel	$ millions		$/barrel	$ millions		$/barrel

Operating, selling and general expenses		78			67			243			204
	Less: natural gas costs and inventory changes	(42	)		(30	)		(133	)		(100	)
Taxes other than income taxes		4			2			8			5

Cash costs		40		10.75	39		11.85	118		11.75	109		11.15
Natural gas		42		11.30	30		9.10	133		13.25	100		10.25

Cash operating costs		82		22.05	69		20.95	251		25.00	209		21.40
In-situ (Firebag) start-up costs		3		0.80	—		—	9		0.90	—		—

Total cash operating costs		85		22.85	69		20.95	260		25.90	209		21.40
Depreciation, depletion and amortization		20		5.40	22		6.70	63		6.30	58		5.95

Total operating costs		105		28.25	91		27.65	323		32.20	267		27.35

Production (thousands of barrels per day)		40.4			35.8			36.6			35.8

Suncor Energy Inc.
Inquiries John Rogers (403) 269-8670 2008 Third Quarter 017

Legal Notice – Forward-Looking Information

This Management's Discussion and Analysis contains certain forward-looking statements that are based on Suncor's current expectations, estimates, projections and assumptions that were made by the company in light of its experience and its perception of historical trends.

All statements that address expectations or projections about the future, including statements about Suncor's strategy for growth, expected and future expenditures, commodity prices, costs, schedules, production volumes, operating and financial results and expected impact of future commitments, are forward-looking statements. Some of the forward-looking statements may be identified by words like "expects," "anticipates," "estimates," "plans," "scheduled," "intends," "believes," "projects," "invests," "could," "focus," "goal," "proposed," "target," "objective," "potential," "forecast," "predict," "enable," "outlook," and similar expressions. These 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 and readers are cautioned not to place undue reliance on them.

The risks, uncertainties and other factors that could influence actual results have not changed since the 2008 second quarter report other than the additional risk that Suncor's ability to borrow in the capital debt markets at acceptable rates may be affected by market instability. Other risks include but are not limited to, changes in the general economic, market and business conditions; fluctuations in supply and demand for Suncor's products; volatility of and assumptions regarding commodity prices, interest rates and currency exchange rates; Suncor's ability to respond to changing markets and to receive timely regulatory approvals; the successful and timely implementation of capital projects including growth projects (for example, the Voyageur project, including our Firebag in-situ development) and regulatory projects (for example, the emissions reduction modifications at our Firebag in-situ development); 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 needed to reduce the margin of error and increase the level of accuracy; the integrity and reliability of Suncor's capital assets; the cumulative impact of other resource development; the cost of compliance with current and future environmental laws; the accuracy of Suncor's reserve, resource and future production estimates and its success at exploration and development drilling and related activities; the maintenance of satisfactory relationships with unions, employee associations and joint venture partners; 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; uncertainties resulting from potential delays or changes in plans with respect to projects or capital expenditures; actions by governmental authorities including the imposition of taxes or changes to fees and royalties, changes in environmental and other regulations (for example, the Government of Alberta's implementation of recommendations to enhance how the performance of the royalty regime is measured and reported, the Government of Canada's proposed Clean Air regulatory framework and the development of greenhouse gas regulation by other provincial and state governments); the future potential for lawsuits against greenhouse gas emitters, based on links drawn between greenhouse gas emissions and climate change; unexpected issues associated with management and reclamation of our tailings ponds; the ability and willingness of parties with whom we have material relationships to perform their obligations to us; and the occurrence of unexpected events such as fires, blowouts, freeze-ups, equipment failures and other similar events affecting Suncor or other parties whose operations or assets directly or indirectly affect Suncor. The foregoing important factors are not exhaustive.

Many of these risk factors are discussed in further detail throughout this Management's Discussion and Analysis and in the company's Annual Information Form/Form 40-F on file with Canadian securities commissions at www.sedar.com and the United States Securities and Exchange Commission (SEC) at www.sec.gov. Readers are also referred to the risk factors 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.

Suncor Energy Inc.
018 2008 Third Quarter For more information about Suncor Energy, visit our website www.suncor.com

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Exhibit 99.2

EX-99.3 4 a2188650zex-99_3.htm EXHIBIT 99.3
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Exhibit 99.3

Interim Unaudited Financial Statements of Suncor Energy Inc. for the nine months ended September 30, 2008

Consolidated statements of earnings and comprehensive income
(unaudited)


		Third Quarter			Nine months ended September 30
		2008	2007		2008		2007
($ millions)			(restated) (note 2)				(restated) (note 2)

Revenues (note 3)		8 946	4 802		22 893		13 380

Expenses
	Purchases of crude oil and products (note 2)	2 301	1 714		5 499		4 304
	Operating, selling and general (notes 2, 3 and 7)	998	814		2 857		2 450
	Energy marketing and trading activities (note 3)	3 494	882		8 608		2 323
	Transportation and other costs	61	46		175		134
	Depreciation, depletion and amortization	263	216		763		610
	Accretion of asset retirement obligations	16	12		48		36
	Exploration	30	9		73		78
	Royalties (note 11)	301	170		804		490
	Taxes other than income taxes	170	165		487		487
	Loss (gain) on disposal of assets	4	(1	)	(14	)	—
	Project start-up costs	8	26		29		52
	Financing expenses (income) (note 5)	156	(100	)	241		(185	)

		7 802	3 953		19 570		10 779

Earnings Before Income Taxes		1 144	849		3 323		2 601

Provision for Income Taxes (notes 2 and 10)
	Current	192	69		406		314
	Future	137	153		565		346

		329	222		971		660

Net Earnings		815	627		2 352		1 941

	Other comprehensive income (loss) (note 13)	104	(76	)	91		(170	)

Comprehensive Income		919	551		2 443		1 771

Net Earnings per Common Share (dollars), (note 6)
	Basic	0.87	0.68		2.53		2.11

	Diluted	0.86	0.66		2.48		2.06

Cash dividends		0.05	0.05		0.15		0.14

See accompanying notes.

Suncor Energy Inc.
Inquiries John Rogers (403) 269-8670 2008 Third Quarter 019

Consolidated balance sheets
(unaudited)

September 30
2008

December 31
2007

($ millions)

(restated)
(note 2)

Assets

Current assets

Cash and cash equivalents

1 315

569

Accounts receivable (note 3)

1 784

1 438

Inventories (note 2)

1 349

1 012

Income taxes receivable

Future income taxes

Total current assets

4 551

3 160

Property, plant and equipment, net

25 213

20 945

Deferred charges and other (note 3)

767

404

Total assets

30 531

24 509

Liabilities and Shareholders' Equity

Current liabilities

Short-term debt

Accounts payable and accrued liabilities (notes 2, 3 and 11)

3 148

2 797

Taxes other than income taxes

Income taxes payable

244

Future income taxes

177

Total current liabilities

3 464

3 156

Long-term debt (note 12)

6 568

3 811

Accrued liabilities and other (notes 3 and 8)

1 345

1 434

Future income taxes (notes 2, 3 and 10)

4 662

4 212

Shareholders' equity (see below)

14 492

11 896

Total liabilities and shareholders' equity

30 531

24 509

Shareholders' Equity

Number

Number

(thousands)

Share capital

934 916

1 104

925 566

881

Contributed surplus

263

194

Accumulated other comprehensive loss (note 13)

(162

)

(253

)

Retained earnings (note 2)

13 287

11 074

Total shareholders' equity

14 492

11 896

See accompanying notes.

Suncor Energy Inc.
020 2008 Third Quarter For more information about Suncor Energy, visit our website www.suncor.com

Consolidated statements of cash flows
(unaudited)


		Third Quarter				Nine months ended September 30
		2008		2007		2008		2007
($ millions)				(restated) (note 2)				(restated) (note 2)

Operating Activities
Cash flow from operations		1 346		957		3 912		2 809
Decrease (increase) in operating working capital
	Accounts receivable	115		(136	)	(343	)	(211	)
	Inventories	255		19		(337	)	(154	)
	Accounts payable and accrued liabilities	(546	)	(165	)	136		29
	Taxes payable/receivable	59		(55	)	(125	)	152

Cash flow from operating activities		1 229		620		3 243		2 625

Cash Used in Investing Activities		(1 893	)	(1 256	)	(5 081	)	(3 678	)

Net Cash Deficiency Before Financing Activities		(664	)	(636	)	(1 838	)	(1 053	)

Financing Activities
Decrease in short-term debt		—		(1	)	(1	)	(2	)
Net proceeds from issuance of long-term debt		—		428		2 704		1 835
Net (decrease) increase in long-term debt		(152	)	18		(195	)	(469	)
Issuance of common shares under stock option plan		15		16		184		44
Dividends paid on common shares		(46	)	(42	)	(134	)	(120	)
Deferred revenue		—		1		—		4

Cash flow provided by financing activities		(183	)	420		2 558		1 292

Increase in Cash and Cash Equivalents		(847	)	(216	)	720		239
Effect of Foreign Exchange on Cash and Cash Equivalents		16		(20	)	26		(44	)
Cash and Cash Equivalents at Beginning of Period		2 146		952		569		521

Cash and Cash Equivalents at End of Period		1 315		716		1 315		716

See accompanying notes.

Suncor Energy Inc.
Inquiries John Rogers (403) 269-8670 2008 Third Quarter 021

Consolidated statements of changes in shareholders' equity
(unaudited)


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

At December 31, 2006, as previously reported	794	100		(71	)	8 129
Retroactive adjustment for change in accounting policy (note 2)	—	—		—		132

At December 31, 2006, as restated	794	100		(71	)	8 261
Net earnings	—	—		—		1 941
Dividends paid on common shares	—	—		—		(120	)
Issued for cash under stock option plan	53	(9	)	—		—
Issued under dividend reinvestment plan	9	—		—		(9	)
Stock-based compensation expense	—	62		—		—
Income tax benefit of stock option deduction in the U.S.	—	2		—		—
Adjustment to opening retained earnings arising from ineffective portion of cash flow hedges at January 1, 2007	—	—		—		5
Adjustment to opening AOCI arising from effective portion of cash flow hedges at January 1, 2007	—	—		8		—
Change in AOCI related to foreign currency translation	—	—		(186	)	—
Change in AOCI related to derivative hedging activities	—	—		16		—

At September 30, 2007, as restated	856	155		(233	)	10 078

At December 31, 2007, as previously reported	881	194		(253	)	10 791
Retroactive adjustment for change in accounting policy (note 2)	—	—		—		283

At December 31, 2007, as restated	881	194		(253	)	11 074
Net earnings	—	—		—		2 352
Dividends paid on common shares	—	—		—		(134	)
Issued for cash under stock option plan	218	(34	)	—		—
Issued under dividend reinvestment plan	5	—		—		(5	)
Stock-based compensation expense	—	94		—		—
Income tax benefit of stock option deduction in the U.S.	—	9		—		—
Change in AOCI related to foreign currency translation	—	—		93		—
Change in AOCI related to derivative hedging activities	—	—		(2	)	—

At September 30, 2008	1 104	263		(162	)	13 287

See accompanying notes.

Suncor Energy Inc.
022 2008 Third Quarter For more information about Suncor Energy, visit our website www.suncor.com

Schedules of Segmented Data
(unaudited)


Third Quarter
	Oil Sands				Natural Gas				Refining and Marketing				Corporate and Eliminations				Total
($ millions)	2008		2007		2008		2007		2008		2007		2008		2007		2008		2007

EARNINGS
Revenues
Operating revenues	2 339		1 618		201		120		2 841		2 169		3		1		5 384		3 908
Energy marketing and trading activities	—		—		—		—		3 594		907		(44	)	(23	)	3 550		884
Intersegment revenues	315		94		15		1		—		—		(330	)	(95	)	—		—
Interest	—		—		—		—		—		—		12		10		12		10

	2 654		1 712		216		121		6 435		3 076		(359	)	(107	)	8 946		4 802

Expenses
Purchases of crude oil and products	175		68		—		—		2 516		1 715		(390	)	(69	)	2 301		1 714
Operating, selling and general	799		604		44		35		170		160		(15	)	15		998		814
Energy marketing and trading activities	—		—		—		—		3 495		906		(1	)	(24	)	3 494		882
Transportation and other costs	48		32		6		6		7		8		—		—		61		46
Depreciation, depletion and amortization	151		126		59		43		40		38		13		9		263		216
Accretion of asset retirement obligations	14		10		2		2		—		—		—		—		16		12
Exploration	7		—		23		9		—		—		—		—		30		9
Royalties (note 11)	249		145		52		25		—		—		—		—		301		170
Taxes other than income taxes	28		24		2		1		140		140		—		—		170		165
Loss (gain) on disposal of assets	11		—		2		(1	)	(2	)	—		(7	)	—		4		(1	)
Project start-up costs	8		24		—		—		—		2		—		—		8		26
Financing expenses (income)	—		—		—		—		—		—		156		(100	)	156		(100	)

	1 490		1 033		190		120		6 366		2 969		(244	)	(169	)	7 802		3 953

Earnings (loss) before income taxes	1 164		679		26		1		69		107		(115	)	62		1 144		849
Income taxes	(310	)	(185	)	(8	)	(1	)	(23	)	(38	)	12		2		(329	)	(222	)

Net earnings (loss)	854		494		18		—		46		69		(103	)	64		815		627

Suncor Energy Inc.
Inquiries John Rogers (403) 269-8670 2008 Third Quarter 023

Schedules of Segmented Data (continued)
(unaudited)


Third Quarter
				Oil Sands				Natural Gas				Refining and Marketing				Corporate and Eliminations				Total
($ millions)				2008		2007		2008		2007		2008		2007		2008		2007		2008		2007

CASH FLOW BEFORE FINANCING ACTIVITIES
Cash flow from (used in) operating activities:
	Cash flow from (used in) operations
		Net earnings (loss)		854		494		18		—		46		69		(103	)	64		815		627
		Exploration expenses		—		—		19		2		—		—		—		—		19		2
		Non-cash items included in earnings
			Depreciation, depletion and amortization	151		126		59		43		40		38		13		9		263		216
			Future income taxes	149		140		4		—		(8	)	13		(8	)	—		137		153
			Loss (gain) on disposal of assets	11		—		2		(1	)	(2	)	—		(7	)	—		4		(1	)
			Stock-based compensation expense	12		12		1		1		4		7		8		4		25		24
			Other	(13	)	—		—		2		4		—		145		(122	)	136		(120	)
		Increase (decrease) in deferred credits and other		(55	)	57		—		—		1		(1	)	1		—		(53	)	56

Total cash flow from (used in) operations				1 109		829		103		47		85		126		49		(45	)	1 346		957
Decrease (increase) in operating working capital				647		75		105		1		(706	)	(169	)	(163	)	(244	)	(117	)	(337	)

Total cash flow from (used in) operating activities				1 756		904		208		48		(621	)	(43	)	(114	)	(289	)	1 229		620

Cash from (used in) investing activities:
	Capital and exploration expenditures			(1 732	)	(1 227	)	(77	)	(67	)	(49	)	(101	)	(11	)	(22	)	(1 869	)	(1 417	)
	Deferred maintenance shutdown expenditures			(59	)	(42	)	(3	)	—		(28	)	(16	)	—		—		(90	)	(58	)
	Deferred outlays and other investments			(6	)	—		—		—		—		2		3		(16	)	(3	)	(14	)
	Proceeds from disposals			—		—		1		5		—		—		7		—		8		5
	Decrease (increase) in investing working capital			69		224		—		—		(1	)	4		(7	)	—		61		228

Total cash (used in) investing activities				(1 728	)	(1 045	)	(79	)	(62	)	(78	)	(111	)	(8	)	(38	)	(1 893	)	(1 256	)

Net cash surplus (deficiency) before financing activities				28		(141	)	129		(14	)	(699	)	(154	)	(122	)	(327	)	(664	)	(636	)

Suncor Energy Inc.
024 2008 Third Quarter For more information about Suncor Energy, visit our website www.suncor.com

Schedules of Segmented Data (continued)
(unaudited)


Nine months ended September 30
	Oil Sands				Natural Gas				Refining and Marketing				Corporate and Eliminations				Total
($ millions)	2008		2007		2008		2007		2008		2007		2008		2007		2008		2007

EARNINGS
Revenues
Operating revenues	6 022		4 395		572		400		7 642		6 206		13		4		14 249		11 005
Energy marketing and trading activities	—		—		—		—		8 728		2 376		(109	)	(25	)	8 619		2 351
Intersegment revenues	1 045		388		45		9		—		—		(1 090	)	(397	)	—		—
Interest	—		—		—		—		—		4		25		20		25		24

	7 067		4 783		617		409		16 370		8 586		(1 161	)	(398	)	22 893		13 380

Expenses
Purchases of crude oil and products	336		137		—		—		6 311		4 534		(1 148	)	(367	)	5 499		4 304
Operating, selling and general	2 156		1 769		123		112		527		511		51		58		2 857		2 450
Energy marketing and trading activities	—		—		—		—		8 612		2 350		(4	)	(27	)	8 608		2 323
Transportation and other costs	140		96		13		15		22		23		—		—		175		134
Depreciation, depletion and amortization	412		334		169		128		148		117		34		31		763		610
Accretion of asset retirement obligations	41		30		6		5		1		1		—		—		48		36
Exploration	16		13		57		65		—		—		—		—		73		78
Royalties (note 11)	661		401		143		89		—		—		—		—		804		490
Taxes other than income taxes	81		65		5		4		400		417		1		1		487		487
Loss (gain) on disposal of assets	13		—		(22	)	(1	)	2		1		(7	)	—		(14	)	—
Project start-up costs	29		47		—		—		—		5		—		—		29		52
Financing expenses (income)	—		—		—		—		—		—		241		(185	)	241		(185	)

	3 885		2 892		494		417		16 023		7 959		(832	)	(489	)	19 570		10 779

Earnings (loss) before income taxes	3 182		1 891		123		(8	)	347		627		(329	)	91		3 323		2 601
Income taxes	(882	)	(453	)	(34	)	8		(115	)	(214	)	60		(1	)	(971	)	(660	)

Net earnings (loss)	2 300		1 438		89		—		232		413		(269	)	90		2 352		1 941

As at September 30
TOTAL ASSETS	23 161		16 739		1 807		1 724		5 681		4 545		(118	)	(229	)	30 531		22 779

Suncor Energy Inc.
Inquiries John Rogers (403) 269-8670 2008 Third Quarter 025

Schedules of Segmented Data (continued)
(unaudited)


Nine months ended September 30
				Oil Sands				Natural Gas				Refining and Marketing				Corporate and Eliminations				Total
($ millions)				2008		2007		2008		2007		2008		2007		2008		2007		2008		2007

CASH FLOW BEFORE FINANCING ACTIVITIES
Cash flow from (used in) operating activities:
	Cash flow from (used in) operations
		Net earnings (loss)		2 300		1 438		89		—		232		413		(269	)	90		2 352		1 941
		Exploration expenses		—		—		48		54		—		—		—		—		48		54
		Non-cash items included in earnings
			Depreciation, depletion and amortization	412		334		169		128		148		117		34		31		763		610
			Future income taxes	515		252		20		(8	)	72		106		(42	)	(4	)	565		346
			Loss (gain) on disposal of assets	13		—		(22	)	(1	)	2		1		(7	)	—		(14	)	—
			Stock-based compensation expense	47		30		3		3		15		15		29		14		94		62
			Other	(29	)	(13	)	(3	)	6		14		—		185		(237	)	167		(244	)
		Increase (decrease) in deferred credits and other		(65	)	45		—		(1	)	2		(4	)	—		—		(63	)	40

Total cash flow from (used in) operations				3 193		2 086		304		181		485		648		(70	)	(106	)	3 912		2 809
Decrease (increase) in operating working capital				183		422		41		12		(542	)	(239	)	(351	)	(379	)	(669	)	(184	)

Total cash flow from (used in) operating activities				3 376		2 508		345		193		(57	)	409		(421	)	(485	)	3 243		2 625

Cash from (used in) investing activities:
	Capital and exploration expenditures			(4 581	)	(3 138	)	(241	)	(425	)	(103	)	(224	)	(20	)	(42	)	(4 945	)	(3 829	)
	Deferred maintenance shutdown expenditures			(318	)	(98	)	(5	)	(1	)	(49	)	(28	)	—		—		(372	)	(127	)
	Deferred outlays and other investments			(37	)	1				—				—		1		(16	)	(36	)	(15	)
	Proceeds from disposals			—		—		26		5		—		1		7		—		33		6
	Decrease (increase) in investing working capital			260		314		—		—		(14	)	(27	)	(7	)	—		239		287

Total cash (used in) investing activities				(4 676	)	(2 921	)	(220	)	(421	)	(166	)	(278	)	(19	)	(58	)	(5 081	)	(3 678	)

Net cash surplus (deficiency) before financing activities				(1 300	)	(413	)	125		(228	)	(223	)	131		(440	)	(543	)	(1 838	)	(1 053	)

Suncor Energy Inc.
026 2008 Third Quarter For more information about Suncor Energy, visit our website www.suncor.com

NOTES TO THE CONSOLIDATED FINANCIAL STATEMENTS
(unaudited)

1. ACCOUNTING POLICIES

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, except for the accounting policy changes as described in note 2, Changes in Accounting Policies. 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, 2008 and the results of its operations and cash flows for the three and nine month periods ended September 30, 2008 and 2007.

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

2. CHANGES IN ACCOUNTING POLICIES

(a) Inventories

On January 1, 2008, the company retroactively adopted the Canadian Institute of Chartered Accountants (CICA) Handbook section 3031 "Inventories". Under the new standard, the use of a LIFO (last-in-first-out) based valuation approach for inventory has been eliminated. The standard also required any impairment to net realizable value of inventory to be written down at each reporting period, with subsequent reversals when applicable. The company transitioned to a FIFO (first-in-first-out) based valuation approach for inventory effective January 1, 2008. The impact of adopting this accounting standard is as follows:

Change in Consolidated Balance Sheets


($ millions, increase/(decrease))	As at September 30 2008		As at December 31 2007

Inventories	473		404

Total assets	473		404

Accounts payable and accrued liabilities	(25	)	—
Future income taxes	157		121
Retained earnings	341		283

Total liabilities and shareholders' equity	473		404

Change in Consolidated Statements of Earnings and Comprehensive Income



	Third quarter				Nine months ended September 30
($ millions, increase/(decrease))	2008		2007		2008		2007

Purchases of crude oil and products	191		(19	)	(144	)	(94	)
Operating, selling and general	186		89		50		(14	)
Future income taxes	(110	)	(20	)	36		36

Net earnings	(267	)	(50	)	58		72

Per common share – basic (dollars)	(0.28	)	(0.05	)	0.06		0.08
Per common share – diluted (dollars)	(0.28	)	(0.05	)	0.06		0.08

Suncor Energy Inc.
Inquiries John Rogers (403) 269-8670 2008 Third Quarter 027

(b) Capital Disclosure

On January 1, 2008, the company adopted CICA Handbook section 1535 "Capital Disclosures". This section establishes disclosure requirements for management's policies and processes in defining and managing its capital. There was no financial impact to previously reported financial statements as a result of the implementation of this new standard.

(c) Financial Instruments – Disclosures and Presentation

On January 1, 2008, the company adopted CICA Handbook sections 3862 "Financial Instruments – Disclosures" and 3863 "Financial Instruments – Presentation", which enhance existing disclosures for financial instruments. In particular, section 3862 focuses on the identification of risk exposures and the company's approach to management of these risks. There was no financial impact to previously reported financial statements as a result of the implementation of this new standard.

3. FINANCIAL INSTRUMENTS AND FINANCIAL RISK FACTORS

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 (hedge) 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.

Forwards and futures are contracts to purchase or sell a specific item at a specified date and price. When used as hedges, forwards and futures help to manage the exposure to losses that could result if commodity prices, foreign currency exchange rates, or interest rates change adversely.

An option is a contract where its holder, for a fee, has purchased the right (but not the obligation) to buy or sell a specified item at a fixed price during a specified period. Options used as hedges help to protect against adverse changes in commodity prices, interest rates, or foreign currency exchange rates.

A costless collar is a combination of two option contracts that limit the holder's exposure to changes in prices to within a specific range. The "costless" nature of this derivative is achieved by buying a put option (the right to sell) for consideration equal to the premium received from selling a call option (the right to purchase).

A swap is a contract where two parties exchange commodity, currency, interest or other payments in order to alter the nature of the payments. For example, fixed interest rate payments on debt may be converted to payments based on a floating interest rate, or vice versa; a domestic currency debt may be converted to a foreign currency debt.

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 has elected to use hedge accounting on certain derivatives linked to future commodity and financial transactions.

Financial Instruments

(a) Balance Sheet Financial Instruments

The company's financial instruments in the Consolidated Balance Sheets consist of cash and cash equivalents, accounts receivable, derivative contracts, substantially all current liabilities (except for the current portions of asset retirement and pension obligations), and long-term debt. 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's fixed-term debt is accounted for under the amortized cost method. Upon initial recognition, the cost of the debt is its fair value, adjusted for any associated transaction costs. We do 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 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, 2008, the carrying value of our fixed-term debt accounted for under the amortized cost method was $5.8 billion (fair value – $4.9 billion).

Suncor Energy Inc.
028 2008 Third Quarter For more information about Suncor Energy, visit our website www.suncor.com

(b) Hedges – Documented as Part of a Qualifying Hedge Relationship

Fair Value Hedges

Suncor periodically enters into derivative financial instrument contracts such as interest rate swaps as part of its risk management strategy to manage its exposure to benchmark interest rate fluctuations. The interest rate swap contracts involve an exchange of floating rate versus fixed rate interest payments between the company and investment grade counterparties. The differentials on the exchange of periodic interest payments are recognized in the accounts as an adjustment to interest expense. The fair value of the underlying debt is adjusted by the fair value change in the derivative financial instrument with the offset to interest expense. At September 30, 2008, the company had interest rate derivatives classified as fair value hedges outstanding for up to 3 years relating to fixed-rate debt. There was no ineffectiveness recognized on interest rate swaps designated as fair value hedges during the three and nine month periods ended September 30, 2008 (no ineffectiveness during the three and nine month periods ended September 30, 2007). The fair value of interest rate swap contracts outstanding at September 30, 2008 is detailed in note 12, Long-term debt.

The company periodically enters into derivative contracts to hedge risks specific to individual transactions. The differentials between the fair value of the hedged transactions and the fair value of the derivative contracts are recognized in the accounts as an adjustment to operating revenues. The earnings impact associated with hedge ineffectiveness on derivative contracts to hedge risks specific to individual transactions during the three month period ended September 30, 2008 was a loss of $1 million, net of income taxes of $1 million (2007 – nil). During the nine month period ended September 30, 2008, the earnings impact was a loss of $4 million, net of income taxes of $2 million (2007 – nil).

Cash Flow Hedges

Suncor operates in a global industry where the market price of its petroleum and natural gas products is largely determined based on floating benchmark indices. The company periodically enters into derivative financial instrument contracts such as forwards, futures, swaps, options and costless collars to hedge against the potential adverse impact of changing market prices due to changes in the underlying indices. Specifically, the company manages crude sales price variability by entering into West Texas Intermediate (WTI) derivative transactions, and manages variability in market interest rates and foreign exchange rates during periods of debt issuance through the use of interest rate locks and foreign exchange forward contracts.

At September 30, 2008, the company had hedged a portion of its forecasted U.S. dollar denominated cash flows subject to U.S. dollar WTI commodity risk for 2008, as well as cash flows related to natural gas production in 2008.

There was no earnings impact associated with realized and unrealized hedge ineffectiveness on derivative contracts designated as cash flow hedges during the three month period ended September 30, 2008 (2007 – gain of $2 million), and there was also no earnings impact during the nine month period ended September 30, 2008 (2007 – loss of $4 million, net of income taxes of $2 million).

Certain derivative contracts do not require the payment of premiums or cash margin deposits prior to settlement. On settlement, these contracts result in cash receipts or payments by the company for the difference between the contract and market rates for the applicable dollars and volumes hedged during the contract term. Such cash receipts or payments offset corresponding decreases or increases in the company's sales revenues or crude oil purchase costs. For collars, if market rates are not different than, or are within the range of contract prices, the options contracts making up the collar will expire with no exchange of cash.

Revenue hedge contracts outstanding at September 30, 2008 were as follows:

Crude Oil

Quantity
(bpd)

Average Price
(US$/bbl)

^(a)

Revenue Hedged
(Cdn$ millions)

^(b)

Hedge
Period ^(c)

Costless collars

10 000

59.85 - 101.06

58 - 99

2008

Natural Gas

Quantity
(GJ/day)

Average Price
(Cdn$/GJ)

Revenue Hedged
(Cdn$ millions)

Hedge
Period ^(d)

Costless collars

15 000

7.00 - 8.71

3 - 4

2008

(a): Average price for crude oil costless collars is US$ WTI per barrel at Cushing, Oklahoma.
(b): The revenue hedged is translated to Cdn$ at the September 30, 2008 exchange rate for convenience purposes.
(c): Original hedge term is for the full year.
(d): For the period of October 2008, inclusive.

Suncor Energy Inc.
Inquiries John Rogers (403) 269-8670 2008 Third Quarter 029

Fair Value of Hedging Derivative Financial Instruments

The fair value of hedging derivative financial instruments as recorded, is the estimated amount that the company would receive (pay) to terminate the hedging derivative contracts. Such amounts, which also represent the unrealized gain (loss) on the contracts, were as follows:


($ millions)	September 30 2008		December 31 2007

Revenue hedge collars	(6	)	(11	)
Fixed to floating interest rate swaps	13		8
Specific hedges of individual transactions	4		12

Fair value of outstanding hedging derivative financial instruments	11		9

Accumulated Other Comprehensive Income (AOCI)

A reconciliation of changes in AOCI attributable to derivative hedging activities for the nine month period ending September 30, 2008 is as follows:


($ millions)	2008

AOCI attributable to derivatives and hedging activities, at December 31, 2007, net of income taxes of $4	13
Current year net changes arising from cash flow hedges, net of income taxes of $3	(7	)
Net unrealized hedging losses at the beginning of the year reclassified to earnings during the period, net of income taxes of $2	5

AOCI attributable to derivatives and hedging activities, at September 30, 2008, net of income taxes of $3	11

(c) Hedges – Not Documented as Part of a Qualifying Hedge Relationship

Suncor also periodically enters into derivative financial instruments such as options, basis swaps, and heat rate swaps that either do not qualify for hedge accounting treatment or hedges that Suncor has not elected to document as part of a qualifying hedge relationship. These financial instruments are accounted for using the mark-to-market method and, as such, these derivative instruments are recorded at fair value at each balance sheet date. The earnings impact associated with these contracts for the three month period ended September 30, 2008, was a gain of $54 million, net of income taxes of $22 million (2007 – a gain of less than $1 million, net of income taxes of less than $1 million). During the nine month period ended September 30, 2008, the earnings impact was a loss of $6 million net of income taxes of $2 million (2007 – a loss of $2 million, net of income taxes of $1 million).

Significant contracts outstanding at September 30 were as follows:

Crude Oil ^(d)

Quantity
(bpd)

Price
(US$/bbl)

^(a)

Revenue Hedged
(Cdn$ millions)

^(b)

Hedge
Period ^(c)

Purchased puts

55 000

60.00

1 277

2009

Purchased puts

55 000

60.00

1 277

2010

(a): Price for crude puts is US$ WTI per barrel at Cushing, Oklahoma.
(b): The revenue hedged is translated to Cdn$ at the September 30, 2008 exchange rate for convenience purposes.
(c): Original hedge term is for the full year.
(d): Premium paid was US$59 million.

(d) Energy Marketing and Trading Activities

In addition to the financial derivatives used for hedging activities, the company uses physical and financial energy contracts, including swaps, forwards and options to earn trading and marketing revenues. These energy contracts are comprised of crude oil, natural gas, heating oil and gasoline contracts. Financial energy trading activities are accounted for using the mark-to-market method. Physical energy marketing contracts involve activities intended to enhance prices and satisfy physical deliveries to customers. The results of these activities are reported as revenue and as energy marketing and trading expenses in the Consolidated Statements of Earnings

Suncor Energy Inc.
030 2008 Third Quarter For more information about Suncor Energy, visit our website www.suncor.com

and Comprehensive Income. Net pretax earnings (loss) for the three and nine month periods ended September 30 for our energy and trading activities in our refining and marketing segment were as follows:

Net Pretax Earnings (Loss)



	Third quarter				Nine Months ended September 30
($ millions)	2008		2007		2008		2007

Physical energy contracts trading activity	105		5		117		35
Financial energy contracts trading activity	(5	)	(3	)	3		(7	)
General and administrative costs	(1	)	(1	)	(4	)	(2	)

Total	99		1		116		26

(e) Fair Value of Non-Designated Derivative Financial Instruments

The fair value of unsettled (unrealized) energy derivative assets and liabilities, which includes all financial contracts referenced in section (c) & (d) above are as follows:


($ millions)	September 30 2008	December 31 2007

Energy trading assets	148	18
Energy trading liabilities	20	21

Net energy trading assets (liabilities)	128	(3	)

Change in fair value of net assets


($ millions)	2008

Fair value of contracts at December 31, 2007	(3	)
Fair value of contracts realized during the period	79
Fair value of contracts entered into during the period	64
Changes in values attributable to market price and other market changes during the period	(12	)

Fair value of contracts outstanding at September 30, 2008	128

Financial Risk Factors

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. Our Risk Management Committee (RMC) is charged with the oversight of the company's risk management for trading risk management 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, and is unchanged from the prior year.

1) Market Risk

Market risk is the risk or uncertainty arising from possible 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 (crude oil, natural gas and electricity price), foreign currency exchange risk and interest rate risk.

Suncor Energy Inc.
Inquiries John Rogers (403) 269-8670 2008 Third Quarter 031

(a) Commodity Price Risk

The company'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 electricity prices. The company's policies permit the use of various financial instruments in managing these price exposures. Our strategic crude oil hedging program gives management approval to fix a price or range of prices for approximately 30% of the total crude oil planned production for specified periods of time. Historically, the company has leveraged hedging instruments to stabilize cash flows during periods of growth and expansion. The company will consider additional strategic hedging opportunities as they become available.

A key component of our overall business strategy is to produce sufficient natural gas to meet or exceed internal demands for natural gas purchased for consumption in our oil sands operation, thus creating a price hedge which reduces our exposure to natural gas price volatility. In addition, existing corporate policies also permit the hedging of natural gas exposures to manage regional price differentials and pricing indexes as identified.

Changes in commodity prices on our financial contracts would have the following impact on our net earnings and other comprehensive income for the three months ended September 30, 2008:

Sensitivity Analysis

($ millions)

September 30, 2008

⁽¹⁾

Change

Net
Earnings

Other
Comprehensive Income

Crude Oil

US$104.24/barrel

Price increase

US$1.00/barrel

(29

)

Price decrease

US$1.00/barrel

Natural Gas

US$7.51/mcf

Price increase

US$0.10/mcf

—

Price decrease

US$0.10/mcf

—

(1): Prices represent the average of the forward strip prices at September 30, 2008.

(b) Foreign Currency Exchange Risk

The company is exposed to changes in foreign exchange rates as revenues, capital expenditures, or financial instruments may fluctuate due to changing rates. As crude oil, the company's primary product, is priced in U.S. dollars, fluctuations in US$/Cdn$ exchange rates may have a significant impact on revenues. The company's exposure is partially offset through the issuance of U.S. dollar denominated long-term debt (refer to note 12) and by sourcing capital projects in U.S. dollars. The company does not currently hedge foreign currency risk on estimated revenues. The effect of a $0.01 change in the US$/Cdn$ exchange rate on our U.S. dollar denominated long-term debt would change after-tax earnings by approximately $40 million.

Where an operating unit has substantial exposure to capital expenditures in currencies other than the U.S. dollar, the company may hedge these risks through a combination of forward and option instruments. Transactions in the applicable financial market are executed consistent with established risk management policies.

(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 notes and commercial paper. The company seeks to optimize this risk through the use of interest rate swaps by swapping fixed rates of interest for variable rates (see – fair value hedges) and other derivative instruments.

To optimize the company's position with respect to interest expense, the company targets 30% to 50% of interest should be based on floating rates. Over time this floating/fixed rate mix will fluctuate based on prevailing market conditions and management's assessment of overall risk.

The proportion of floating interest rate exposure inclusive of interest rate swaps at September 30, 2008 was 8% of total debt outstanding. The weighted average interest rate on total debt for the quarter ending September 30, 2008 was 6.2%.

Suncor Energy Inc.
032 2008 Third Quarter For more information about Suncor Energy, visit our website www.suncor.com

The company's cash flows are sensitive to changes in interest rates on the floating rate portion of the company's debt. Given our current growth and expansion plans, all interest is currently being capitalized and therefore there is no earnings impact. If the interest rates applicable to floating rate instruments were to have increased by 1%, it is estimated that the company's cash flow for the quarter would decrease by approximately $1 million. This assumes that the amount and mix of fixed and floating rate debt remains unchanged from September 30, 2008, and that the change in interest rates is effective from the beginning of the period.

2) Liquidity Risk

Liquidity risk is the risk that an entity will encounter difficulty in meeting obligations associated with financial liabilities. The company believes that it has access to sufficient capital through internally generated cash flows and external sources (bank credit markets and debt capital markets), and to undrawn committed borrowing facilities to meet current spending forecasts.

Surplus cash is invested into a range of short-dated money market securities and the company seeks to ensure the security and liquidity of those investments. Investments are only permitted in high credit quality government or corporate securities. Diversification of these investments is supported through maintaining counterparty credit limits.

The following table shows the timing of cash outflows relating to trade and other payables and finance debt.

September 30, 2008

December 31, 2007

($ millions)

Trade and
other payables

⁽¹⁾

Finance
debt

⁽²⁾

Trade and
other payables

⁽¹⁾

Finance
debt ⁽²⁾

Within one year

2 992

720

2 843

764

1 to 3 years

295

1 297

347

427

3 to 5 years

—

733

—

917

Over 5 years

11 914

6 985

3 307

14 664

3 209

9 093

(1): These balances exclude non-financial liabilities (pension liabilities, asset retirement obligation, future income taxes and financial instruments) totaling $1,495 million and $1,375 million at September 30, 2008 and December 31, 2007 respectively.
(2): Finance debt includes long-term debt, capital leases and interest payments on fixed-term debt and commercial paper.

3) Credit Risk

Credit risk is the risk that a customer or counterparty will fail to perform an obligation or fail to pay amounts due causing a financial loss. We have a credit policy that 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 is assigned and a maximum credit limit is allocated. 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 credit limit allocated. 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 September 30, 2008, substantially all of the company's trade receivables were current, and there were no counterparties that individually constituted more than 10% of the outstanding balance.

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 with positive fair values at the reporting date. At September 30, 2008, the company's exposure was $165 million (December 31, 2007 – $38 million).

Suncor Energy Inc.
Inquiries John Rogers (403) 269-8670 2008 Third Quarter 033

4. CAPITAL STRUCTURE FINANCIAL POLICIES

Suncor'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.

Suncor monitors capital through two key ratios: net debt to cash flow from operations and total debt to total debt plus shareholders' equity.

Net debt to cash flow from operations is calculated as short-term debt plus long-term debt less cash and cash equivalents divided by 12 month trailing cash flow from operations.

Total debt to total debt plus shareholders' equity is calculated as short term-debt plus long-term debt divided by short-term debt plus long-term debt plus shareholders' equity.

Suncor's strategy during Q3 2008, which was unchanged from 2007, was to maintain the measure set out in the following schedule. Suncor believes that maintaining our 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

2008

2007

Components of ratios

Short-term debt

Long-term debt

6 568

3 468

Total debt

6 575

3 473

Cash and equivalents

1 315

716

Net debt

5 260

2 757

Shareholders' equity

14 492

10 856

Total capitalization (total debt + shareholders' equity)

21 067

14 329

Cash flow from operations (trailing 12 months)

5 112

3 521

Net debt/cash flow from operations

<2.0 times

1.0

0.8

Total debt/total debt plus shareholders' equity

31%

24%

5. FINANCING EXPENSES (INCOME)


		Third quarter				Nine months ended September 30
($ millions)		2008		2007		2008		2007

Interest expense on debt		101		51		242		131
Capitalized interest		(101	)	(51	)	(242	)	(131	)

	Net interest expense	—		—		—		—
Foreign exchange (gain) loss on long-term debt		173		(126	)	238		(233	)
Other foreign exchange (gain) loss		(17	)	26		3		48

Total financing expenses (income)		156		(100	)	241		(185	)

Suncor Energy Inc.
034 2008 Third Quarter For more information about Suncor Energy, visit our website www.suncor.com

6. RECONCILIATION OF BASIC AND DILUTED EARNINGS PER COMMON SHARE

Third quarter

Nine months ended
September 30

($ millions)

2008

2007
(restated)

2008

2007
(restated)

Net earnings

815

627

2 352

1 941

(millions of common shares)

Weighted-average number of common shares

935

923

930

922

Dilutive securities:

Options issued under stock-based compensation plans

Weighted-average number of diluted common shares

953

943

948

942

(dollars per common share)

Basic earnings per share ^(a)

0.87

0.68

2.53

2.11

Diluted earnings per share ^(b)

0.86

0.66

2.48

2.06

Note:: An option will have a dilutive effect under the treasury stock method only when the average market price of the common stock during the period exceeds the exercise price of the option.
(a): Basic earnings per share is net earnings divided by the weighted-average number of common shares.
(b): Diluted earnings per share is net earnings, divided by the weighted-average number of diluted common shares.

7. SHARE CAPITAL AND STOCK-BASED COMPENSATION

A common share option gives the holder the right, but not the obligation, to purchase common shares at a predetermined price over a specified period of time.

After the date of grant, employees and non-employee directors that hold options must earn the right to exercise them. This is done by the holder fulfilling a time requirement for service to the company, and with respect to certain options, is subject to accelerated vesting should the company meet predetermined performance criteria. Once this right has been earned, these options are considered vested.

The predetermined price at which an option can be exercised is equal to or greater than the market price of the common shares on the date the option is granted.

A performance vesting share unit is an award entitling employees to receive cash to varying degrees contingent upon Suncor's shareholder return relative to a peer group of companies.

A restricted share unit is a time-vested award with a three-year term entitling employees to receive cash.

(a) Stock Split

In May 2008, the Company implemented a two-for-one stock split of its issued and outstanding common shares. Information related to common shares, stock-based compensation, and earnings per share has been restated to reflect the impact of the Company's two-for-one stock split.

(b) Stock Option Plans:

(i) SunShare 2012 Performance Stock Option Plan

The company granted 730,000 options in the third quarter of 2008 under its new employee stock-based compensation plan ("SunShare 2012"), for a total of 1,786,000 options granted in the nine months ended September 30, 2008 (15,392,000 options granted in the three and nine months ended September 30, 2007). During the second quarter, in connection with the achievement of a predetermined performance criterion, 25% of the outstanding options vested under the SunShare 2012 plan and will become exercisable on January 1, 2010. The remaining 75% of outstanding options may vest on January 1, 2013 if further specified performance targets are met. All unvested options at January 1, 2013, which have not previously expired or been cancelled, will automatically expire.

Suncor Energy Inc.
Inquiries John Rogers (403) 269-8670 2008 Third Quarter 035

(ii) SunShare Performance Stock Option Plan

Granting of options under the company's previous employee stock option incentive plan ("SunShare") ended in December 2007. During the third quarter of 2007, 546,000 options were granted to eligible full-time and part-time employees under the SunShare plan (2,066,000 options granted in the first nine months of 2007). Final vesting of all unvested SunShare options occurred on April 30, 2008.

(iii) Executive Stock Option Plan

Under this plan, the company granted 42,000 common share options in the third quarter of 2008, for a total of 870,000 options granted in the nine months ended September 30, 2008 (44,000 options granted during the third quarter of 2007; 958,000 granted in the nine months ended September 30, 2007) to non-employee directors and certain executives and other senior members of the company. Options granted have a ten-year life and vest annually over a three-year period.

(iv) Key Contributor Stock Option Plan

Under this plan, the company granted 11,000 common share options in the third quarter of 2008, for a total of 2,373,000 options granted in the nine months ended September 30, 2008 (12,000 options granted during the third quarter of 2007; 2,364,000 granted in the nine months ended September 30, 2007) to non-insider senior managers and key employees. Options granted have a ten-year life and vest annually over a three-year period.

Fair Value of Options Granted

The fair values of all common share options granted during the period are estimated as at the grant date using the Monte Carlo simulation approach for the SunShare 2012 option plan and the Black-Scholes option-pricing model for all other option plans. The weighted-average fair values of the options granted during the various periods and the weighted-average assumptions used in their determination are as noted below:

Third quarter

Nine months ended
September 30

2008

2007

2008

2007

Quarterly dividend per share

$0.05

$0.05

$0.05

$0.05

Risk-free interest rate

3.08%

4.26%

3.44%

4.22%

Expected life

5 years

7 years

6 years

6 years

Expected volatility

30%

30%

29%

30%

Weighted-average fair value per option

$12.89

$15.19

$14.73

$14.89

*: In 2007, quarterly dividends of $0.04 per share were paid in the first quarter, and $0.05 per share was paid in the second and third quarters.

Stock-based compensation expense recognized in the third quarter of 2008 related to stock option plans was $25 million (2007 – $24 million). For the nine months ended September 30, 2008 stock-based compensation expense recognized was $94 million (2007 – $62 million).

Suncor Energy Inc.
036 2008 Third Quarter For more information about Suncor Energy, visit our website www.suncor.com

Common share options granted prior to January 1, 2003 are not recognized as compensation expense in the Consolidated Statements of Earnings. The company's reported net earnings attributable to common shareholders and earnings per share prepared in accordance with the fair value method of accounting for stock-based compensation would have been reduced for all common share options granted prior to 2003 to the pro forma amounts stated below:

Third quarter

Nine months ended
September 30

($ millions, except per share amounts)

2008

2007
(restated)

2008

2007
(restated)

Net earnings – as reported

815

627

2 352

1 941

Less: compensation cost under the fair value method for pre-2003 options

—

Pro forma net earnings

815

624

2 348

1 933

Basic earnings per share

As reported

0.87

0.68

2.53

2.11

Pro forma

0.87

0.68

2.52

2.10

Diluted earnings per share

As reported

0.86

0.66

2.48

2.06

Pro forma

0.86

0.66

2.48

2.05

(c) Performance Share Units (PSUs)

In the third quarter of 2008, the company issued 2,000 PSUs (2007 – 2,000). For the nine months ended September 30, 2008, the company issued 782,000 PSUs (2007 – 830,000). Recovery recognized in the third quarter of 2008 was $13 million (2007 – $10 million in expense). Recovery recognized for the nine months ended September 30, 2008 was $3 million (2007 – $46 million in expense).

(d) SunShare 2012 Restricted Share Units (RSUs)

In the third quarter of 2008, the company issued 49,000 RSUs under its new employee stock-based compensation plan. For the nine months ended September 30, 2008, the company issued 1,025,000 RSUs. Expense recognized in the third quarter of 2008 was $1 million and expense recognized for the nine months ended September 30, 2008 was $10 million.

8. EMPLOYEE FUTURE BENEFITS LIABILITY

The company's pension plans and other post-retirement benefits programs are described in note 9 of the company's 2007 Annual Report. The following is the status of the net periodic benefit cost for the three and nine months ended September 30.


	Pension Benefits
	Third Quarter				Nine months ended September 30
	2008		2007		2008		2007

Current service costs	14		13		42		39
Interest costs	12		12		36		34
Expected return on plan assets	(11	)	(11	)	(33	)	(32	)
Amortization of net actuarial loss	6		6		17		18

Net periodic benefit cost	21		20		62		59


	Other Post-Retirement Benefits
	Third Quarter		Nine months ended September 30
	2008	2007	2008	2007

Current service costs	1	1	3	3
Interest costs	2	2	7	6
Amortization of net actuarial loss	1	1	2	2

Net periodic benefit cost	4	4	12	11

Suncor Energy Inc.
Inquiries John Rogers (403) 269-8670 2008 Third Quarter 037

9. SUPPLEMENTAL INFORMATION


	Third quarter		Nine months ended September 30
($ millions)	2008	2007	2008	2007

Interest paid	54	56	178	133
Income taxes paid	103	112	507	167

10. INCOME TAXES

During the fourth quarter of 2007, the federal government substantively enacted a 3.5% reduction to its federal corporate tax rates. Accordingly, the company recognized a reduction in future income tax expense of $360 million related to the revaluation of its opening future income tax balances.

During the second quarter of 2007, the federal government substantively enacted a 0.5% reduction to its federal corporate tax rates. Accordingly, the company recognized a reduction in future income tax expense of $67 million related to the revaluation of its opening future income tax balances.

11. ROYALTY ESTIMATE MEASUREMENT UNCERTAINTY

Our current estimation of Alberta Crown royalties is based on regulations currently in effect. Alberta Crown royalties in effect for each oil sands project require payments to the Government of Alberta based on annual gross revenues less related transportation costs (R) less allowable costs (C), including the deduction of certain capital expenditures (the 25% R-C royalty), subject to a minimum payment of 1% of R.

Oil Sands royalties payable in 2008 are highly sensitive to, among other factors, changes in crude oil and natural gas pricing, foreign exchange rates and total capital and operating costs for each project. The oil sands pretax royalty estimate was $661 million for the first nine months of 2008, compared to $401 million for the first nine months of 2007. The balance of the consolidated royalty expense is in respect of natural gas royalties of $143 million (2007 – $89 million).

In 2008, the estimation process for calculating the quarterly royalty provision was changed from being based on an annual estimate to being based on the actual eligible revenues and costs recorded in the period. If the annualized approach was used for 2008, pretax royalties would have been $86 million higher for the first nine months of 2008.

12. LONG-TERM DEBT AND CREDIT FACILITIES

In May 2008, the company issued 5.80% Medium Term Notes with a principal amount of $700 million under an outstanding $2 billion debt shelf prospectus. These notes bear interest, which is paid semi-annually, and mature on May 22, 2018. The net proceeds received were added to our general funds to repay outstanding commercial paper, which originally funded our working capital needs, sustaining capital expenditures and growth capital expenditures.

Suncor Energy Inc.
038 2008 Third Quarter For more information about Suncor Energy, visit our website www.suncor.com

funds, which are used for our working capital needs, sustaining capital expenditures, growth capital expenditures and to repay outstanding commercial paper borrowings.


($ millions)	September 30 2008		December 31 2007

Fixed-term debt, redeemable at the option of the Company
6.85% Notes, denominated in U.S. dollars, due in 2039 (US$750)	795		—
6.50% Notes, denominated in U.S. dollars, due in 2038 (US$1150)	1 219		1 137
5.95% Notes, denominated in U.S. dollars, due in 2034 (US$500)	530		494
7.15% Notes, denominated in U.S. dollars, due in 2032 (US$500)	530		494
6.10% Notes, denominated in U.S. dollars, due in 2018 (US$1250)	1 324		—
5.39% Series 4 Medium Term Notes, due in 2037	600		600
5.80% Series 4 Medium Term Notes, due in 2018	700		—
6.70% Series 2 Medium Term Notes, due in 2011	500		500

	6 198		3 225
Revolving-term debt, with interest at variable rates
Commercial Paper	318		522

Total unsecured long-term debt	6 516		3 747
Secured long-term debt	14		1
Capital Leases	102		102
Fair value of interest rate swaps	8		6
Deferred financing costs	(72	)	(45	)

Total long-term debt	6 568		3 811

At September 30, 2008, undrawn lines of credit were approximately $3,531 million, as follows:


($ millions)			2008

Facility that is fully revolving for 364 days, has a term period of one year and expires in 2009			370
Facility that is fully revolving for a period of five years and expires in 2013			3 750
Facilities that can be terminated at any time at the option of the lenders			53

Total available credit facilities			4 173

Credit facilities supporting outstanding commercial paper			318
Credit facilities supporting standby letters of credit			324

Total undrawn credit facilities			3 531

13. ACCUMULATED OTHER COMPREHENSIVE INCOME

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


($ millions)	September 30 2008		December 31 2007

Unrealized foreign currency translation adjustments	(173	)	(266	)
Unrealized gains and losses on derivative hedging activities	11		13

Total	(162	)	(253	)

Suncor Energy Inc.
Inquiries John Rogers (403) 269-8670 2008 Third Quarter 039

Highlights
(unaudited)


		2008	2007 (restated)

Cash Flow from Operations
(dollars per common share – basic)
For the three months ended September 30
Cash flow from operations ⁽¹⁾		1.44	1.04

For the nine months ended September 30
Cash flow from operations ⁽¹⁾		4.20	3.05

Ratios
For the twelve months ended September 30
Return on capital employed (%) ⁽²⁾		28.7	24.0
Return on capital employed (%) ⁽³⁾		21.0	17.9

Net debt to cash flow from operations (times) ⁽⁴⁾		1.0	0.8

Interest coverage on long-term debt (times)
	Net earnings ⁽⁵⁾	14.2	18.4
	Cash flow from operations ⁽⁶⁾	18.6	22.9

As at September 30
Debt to debt plus shareholders' equity (%) ⁽⁷⁾		31.2	24.2

Common Share Information ⁽⁸⁾
As at September 30
Share price at end of trading
	Toronto Stock Exchange – Cdn$	44.00	47.23
	New York Stock Exchange – US$	42.14	47.41

Common share options outstanding (thousands)		46 829	55 743

For the nine months ended September 30
Average number outstanding, weighted monthly (thousands)		930 393	921 578

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

(1): Cash flow from operations for the period; divided by the weighted average number of common shares outstanding during the period.
(2): For the twelve month period ended; net earnings (2008 – $3,500 million; 2007 – $2,157 million) adjusted for after-tax financing expense (2008 – $105 million; 2007 – income of $118 million) divided by average capital employed (2008 – $12,196 million; 2007 – $8,982 million). Average capital employed is the sum of shareholders' equity and short-term debt plus long-term debt less cash and cash equivalents, at the beginning and end of the year, divided by two, less capitalized costs related to major projects in progress (as applicable). Return on capital employed (ROCE) for Suncor operating segments as presented in the Quarterly Operating Summary is calculated in a manner consistent with consolidated ROCE. For a detailed reconciliation of ROCE prepared on an annual basis, see page 46 of Suncor's 2007 Annual Report to Shareholders.
(3): If capital employed were to include capitalized costs related to major projects in progress (average capital employed including major projects in progress: 2008 – $16,703 million; 2007 – $12,065 million), the return on capital employed would be as stated on this line.
(4): Short-term debt plus long-term debt less cash and cash equivalents, divided by cash flow from operations for the twelve month period then ended.
(5): Net earnings plus income taxes and interest expense, divided by the sum of interest expense and capitalized interest.
(6): Cash flow from operations plus current income taxes and interest expense; divided by the sum of interest expense and capitalized interest.
(7): Short-term debt plus long-term debt; divided by the sum of short-term debt, long-term debt and shareholders' equity.
(8): In May 2008, Suncor's common shares were split on a two-for-one basis. Prior periods have been restated to reflect the split.

Suncor Energy Inc.
040 2008 Third Quarter For more information about Suncor Energy, visit our website www.suncor.com

Quarterly operating summary
(unaudited)


	For the quarter ended					Nine months ended		Total year
	Sept 30 2008	June 30 2008	Mar 31 2008	Dec 31 2007	Sept 30 2007	Sept 30 2008	Sept 30 2007	Dec 31 2007

OIL SANDS
Production ^(1),(a)
Total production	245.6	174.6	248.0	252.5	239.1	222.6	229.8	235.6
Firebag	40.4	34.7	34.6	40.4	35.8	36.6	35.8	36.9
Sales ^(a)
Light sweet crude oil	48.1	68.2	96.2	102.2	99.3	70.7	101.6	101.7
Diesel	10.9	21.2	28.0	26.0	23.9	20.0	24.6	25.0
Light sour crude oil	157.4	91.8	120.8	118.2	94.1	123.4	96.9	102.3
Bitumen	2.6	0.3	0.1	5.4	6.6	1.0	5.7	5.7

Total sales	219.0	181.5	245.1	251.8	223.9	215.1	228.8	234.7

Average sales price ^{(2), (b)}
Light sweet crude oil	121.96	122.12	100.93	87.34	81.00	112.52	74.87	78.03
Other (diesel, light sour crude oil and bitumen)	114.74	120.52	93.09	78.48	73.76	108.83	67.84	70.86
Total	116.32	121.12	96.16	82.07	76.97	110.04	71.02	74.01
Total *	117.14	122.39	96.22	82.36	76.97	110.70	70.99	74.07
Cash operating costs and Total operating costs – Total operations ^(c)
Cash costs	27.80	40.10	25.10	24.10	23.00	30.00	24.15	24.15
Natural gas	4.30	8.75	5.00	3.60	2.10	5.70	3.55	3.55
Imported bitumen	1.90	2.00	1.45	0.20	—	1.75	0.05	0.10

Cash operating costs ⁽³⁾	34.00	50.85	31.55	27.90	25.10	37.45	27.75	27.80
Project start-up costs	0.35	0.90	0.30	0.55	1.10	0.50	0.75	0.95

Total cash operating costs ⁽⁴⁾	34.35	51.75	31.85	28.45	26.20	37.95	28.50	28.75
Depreciation, depletion and amortization	6.70	8.30	5.75	5.60	5.70	6.75	5.30	5.40

Total operating costs ⁽⁵⁾	41.05	60.05	37.60	34.05	31.90	44.70	33.80	34.15

Cash operating costs and Total operating costs – In-situ bitumen production only ^(c)
Cash costs	10.75	10.10	14.60	9.95	11.85	11.75	11.15	10.85
Natural gas	11.30	14.55	14.10	9.15	9.10	13.25	10.25	9.90

Cash operating costs ⁽⁶⁾	22.05	24.65	28.70	19.10	20.95	25.00	21.40	20.75
In-situ (Firebag) start-up costs	0.80	1.65	0.35	—	—	0.90	—	—

Total cash operating costs ⁽⁷⁾	22.85	26.30	29.05	19.10	20.95	25.90	21.40	20.75
Depreciation, depletion and amortization	5.40	6.70	6.75	6.80	6.70	6.30	5.95	6.20

Total operating costs ⁽⁸⁾	28.25	33.00	35.80	25.90	27.65	32.20	27.35	26.95

(for the period ended)
Capital employed ⁽ⁱ⁾	9 035	7 716	6 837	6 605	6 071
(for the twelve months ended)
Return on capital employed ^(j)	46.0	43.6	44.3	43.0	32.3
Return on capital employed ^(j)****	28.6	27.3	28.0	27.9	21.7

Suncor Energy Inc.
Inquiries John Rogers (403) 269-8670 2008 Third Quarter 041

Quarterly operating summary (continued)
(unaudited)


	For the quarter ended						Nine months ended		Total year
	Sept 30 2008	June 30 2008	Mar 31 2008	Dec 31 2007	Sept 30 2007		Sept 30 2008	Sept 30 2007	Dec 31 2007

NATURAL GAS
Gross production ^**
Natural gas ^(d)	197	205	209	210	193		204	192	196
Natural gas liquids and crude oil ^(a)	2.6	3.4	3.3	3.2	3.1		3.1	3.1	3.1
Total gross production ^(e)	35.4	37.7	38.2	38.2	35.2		37.1	35.0	35.8
Total gross production ^(f)	213	226	229	229	211		223	210	215
Average sales price ⁽²⁾
Natural gas ^(g)	9.10	9.62	7.30	6.08	5.39		8.66	6.41	6.32
Natural gas ^(g) ^*	9.14	9.68	7.31	6.02	5.14		8.70	6.37	6.27
Natural gas liquids and crude oil ^(b)	96.88	86.14	64.14	60.31	58.11		81.37	55.33	56.64
Net wells drilled
Conventional – exploratory ^***	4	2	2	6	1		8	7	14
– development	6	6	7	6	2		19	12	17

	10	8	9	12	3		27	19	31

(for the period ended)
Capital employed ⁽ⁱ⁾	1 120	1 226	1 175	1 153	1 090
(for the twelve months ended)
Return on capital employed ^(j)	10.3	8.3	3.5	2.5	(0.6	)

REFINING AND MARKETING
Refined product sales ^(h)
Transportation fuels
Gasoline – retail	4.5	4.5	4.6	4.9	5.1		4.6	5.3	5.2
– other	11.5	11.8	10.8	11.0	12.0		11.3	11.9	11.6
Distillate	10.6	11.5	10.4	11.0	10.8		10.8	10.5	10.6

Total transportation fuel sales	26.6	27.8	25.8	26.9	27.9		26.7	27.7	27.4
Petrochemicals	1.0	0.9	0.6	0.7	0.9		0.8	1.0	0.9
Asphalt	1.9	1.7	2.2	1.4	2.1		1.9	1.7	1.7
Other	2.5	2.7	1.9	3.8	4.2		2.3	3.4	3.5

Total refined product sales	32.0	33.1	30.5	32.8	35.1		31.7	33.8	33.5

Crude oil supply and refining
Processed at refineries ^(h)	25.1	26.0	23.0	22.1	25.9		24.7	26.1	25.1
Utilization of refining capacity ^(j)	99	102	90	87	102		97	102	98

(for the period ended)
Capital employed ⁽ⁱ⁾	3 289	2 534	2 837	2 489	2 332
(for the twelve months ended)
Return on capital employed ^(j)	9.3	12.6	18.3	20.0	20.9
Return on capital employed ^(j) ^****	9.0	11.6	16.5	17.4	17.9

Suncor Energy Inc.
042 2008 Third Quarter For more information about Suncor Energy, visit our website www.suncor.com

Quarterly operating summary (continued)

Non GAAP Financial Measures

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.

Definitions


(1) Total operations production	–	Total operations production includes total production from both mining and in-situ operations.
(2) Average sales price	–	This operating statistic is calculated before royalties and net of related transportation costs (including or excluding the impact of hedging activities as noted).
(3) Cash operating costs – Total operations	–	Include cash costs that are defined as operating, selling and general expenses (excluding inventory changes), accretion expense, taxes other than income taxes 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.
(4) Total cash operating costs – Total operations	–	Include cash operating costs – Total operations as defined above and cash start-up costs. Per barrel amounts are based on total production volumes.
(5) Total operating costs – Total operations	–	Include total cash operating costs – Total operations as defined above and non-cash operating costs. Per barrel amounts are based on total production volumes.
(6) Cash operating costs – In-situ bitumen production	–	Include cash costs that are defined as operating, selling and general expenses (excluding inventory changes), accretion expense and taxes other than income taxes. Per barrel amounts are based on in-situ production volumes only.
(7) 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.
(8) 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.

Explanatory Notes


*		Excludes the impact of hedging activities.
**		Currently production is located in the Western Canada Sedimentary Basin.
***		Excludes exploratory wells in progress.
****		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.


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

Metric Conversion


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

Suncor Energy Inc.
Inquiries John Rogers (403) 269-8670 2008 Third Quarter 043

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Exhibit 99.3

EX-99.4 5 a2188650zex-99_4.htm EXHIBIT 99.4
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Exhibit 99.4

Certification of the President and Chief Executive Officer

CERTIFICATION

I, RICHARD L. GEORGE, certify that:

1.

I have reviewed this quarterly report on Form 6-K of Suncor Energy Inc.;

2.

Based on my knowledge, this report does not contain any untrue statement of a material fact or omit to state a material fact necessary to make the statements made, in light of the circumstances under which such statements were made, not misleading with respect to the period covered by this report;

3.

Based on my knowledge, the financial statements, and other financial information included in this report, fairly present in all material respects the financial condition, results of operations and cash flows of the registrant as of, and for, the periods presented in this report;

4.

The registrant's other certifying officer and I are responsible for establishing and maintaining disclosure controls and procedures (as defined in Exchange Act Rules 13a-15(e) and 15d-15(e) and internal control over financial reporting (as defined in Exchange Act Rules 13a-15(f) and 15d-15(f)) for the registrant and have:

(a): Designed such disclosure controls and procedures, or caused such disclosure controls and procedures to be designed under our supervision to ensure that material information relating to the registrant, including its consolidated subsidiaries, is made known to us by others within those entities, particularly during the period in which this report is being prepared;
(b): Designed such internal control over financial reporting, or caused such internal control over financial reporting to be designed under our supervision, to provide reasonable assurance regarding the reliability of financial reporting and the preparation of financial statements for external purposes in accordance with generally accepted accounting principles;
(c): Evaluated the effectiveness of the registrant's disclosure controls and procedures and presented in this report our conclusions about the effectiveness of the disclosure controls and procedures, as of the end of the period covered by this report based on such evaluation; and
(d): Disclosed in this report any change in the registrant's internal control over financial reporting that occurred during the registrant's most recent fiscal quarter that has materially affected, or is reasonably likely to materially affect, the registrant's internal control over financial reporting; and

5.

The registrant's other certifying officer and I have disclosed, based on our most recent evaluation of internal control over financial reporting, to the registrant's auditors and the audit committee of the registrant's board of directors (or persons performing the equivalent functions):

(a): All significant deficiencies and material weaknesses in the design or operation of internal control over financial reporting which are reasonably likely to adversely affect the registrant's ability to record, process, summarize and report financial information; and
(b): Any fraud, whether or not material, that involves management or other employees who have a significant role in the registrant's internal control over financial reporting.


Date: October 29, 2008		/s/ RICHARD L. GEORGE Richard L. George President and Chief Executive Officer

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Exhibit 99.4

EX-99.5 6 a2188650zex-99_5.htm EXHIBIT 99.5
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Exhibit 99.5

Certification of the Senior Vice President and Chief Financial Officer

CERTIFICATION

I, J. KENNETH ALLEY, certify that:

1.

I have reviewed this quarterly report on Form 6-K of Suncor Energy Inc.;

2.

3.

4.

(a): Designed such disclosure controls and procedures, or caused such disclosure controls and procedures to be designed under our supervision to ensure that material information relating to the registrant, including its consolidated subsidiaries, is made known to us by others within those entities, particularly during the period in which this report is being prepared;
(b): Designed such internal control over financial reporting, or caused such internal control over financial reporting to be designed under our supervision, to provide reasonable assurance regarding the reliability of financial reporting and the preparation of financial statements for external purposes in accordance with generally accepted accounting principles;
(c): Evaluated the effectiveness of the registrant's disclosure controls and procedures and presented in this report our conclusions about the effectiveness of the disclosure controls and procedures, as of the end of the period covered by this report based on such evaluation; and
(d): Disclosed in this report any change in the registrant's internal control over financial reporting that occurred during the registrant's most recent fiscal quarter that has materially affected, or is reasonably likely to materially affect, the registrant's internal control over financial reporting; and

5.

(a): All significant deficiencies and material weaknesses in the design or operation of internal control over financial reporting which are reasonably likely to adversely affect the registrant's ability to record, process, summarize and report financial information; and
(b): Any fraud, whether or not material, that involves management or other employees who have a significant role in the registrant's internal control over financial reporting.


Date: October 29, 2008		/s/ J. KENNETH ALLEY J. Kenneth Alley Senior Vice President and Chief Financial Officer

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Exhibit 99.5

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