6-K

SECURITIES AND EXCHANGE COMMISSION
Washington, D.C. 20549

Form 6-K

Report of Foreign Issuer

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

April 1, 2004

Commission File No. 0-29214

Hawker Resources Inc.
(formerly named SYNSORB Biotech Inc.)

(Translation of registrant’s name into English)

Suite 700, 700 – 2nd Street SW
Calgary, Alberta, Canada T2P 2W1

(Address of principal executive office)

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

Form 20-F   þ Form 40-F   o

     Indicate by check mark whether the registrant by furnishing the information contained in this Form is also thereby furnishing the information to the Commission pursuant to Rule 12g3-2(b) under the Securities Act of 1034.

Yes   o No   þ

     If “Yes” is marked, indicate below the file number assigned to the registrant in connection with Rule 12g3-2(b): 82-N/A

Exhibit Number	Exhibit
1.	News release dated March 30, 2004
2.	Management Discussion and Analysis
3.	Annual Financial Statements for the year ended December 31, 2003
4.	Annual Report
5.	Annual Information Form dated March 17, 2004
6.	Notice of Meeting and Information Circular dated April 28, 2004
7.	Erratum
8.	Form of Proxy

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.

	HAWKER RESOURCES, INC. (formerly named SYNSORB Biotech Inc.)
Dated: April 1, 2004	By:	“/s/ Darrell Peterson” Name:  Darrell Peterson Title:    Corporate Secretary

TABLE OF CONTENTS

News Release Dated March 30, 2004

Management Discussion and Analysis

Annual Financial Statements December 31, 2003

Annual Report

Annual Information Form dated March 17, 2003

Notice of Meeting and Information Circular

Erratum

Form of Proxy

Exhibit Number	Exhibit
1.	News release dated March 30, 2004
2.	Management Discussion and Analysis
3.	Annual Financial Statements for the year ended December 31, 2003
4.	Annual Report
5.	Annual Information Form dated March 17, 2004
6.	Notice of Meeting and Information Circular dated April 28, 2004
7.	Erratum
8.	Form of Proxy

EX-1 3 o12483exv1.htm NEWS RELEASE DATED MARCH 30, 2004

Exhibit 1

News release via Canada NewsWire, Calgary 403-269-7605

Attention Business Editors:

Hawker Resources Inc. Releases 2003 Year-End Information and Files Annual Information Form

CALGARY, March 30, 2004 — Hawker Resources Inc. (TSX:HKR) today announces that it has filed its Information Circular in respect of the Annual and Special Meeting of Shareholders to be held April 28, 2004; its Annual Report, and its audited consolidated Financial Statements and accompanying notes for the year ended December 31, 2003 and related Management’s Discussion and Analysis with Canadian securities regulatory authorities on the System for Electronic Document Analysis and Retrieval (SEDAR). Hawker has also filed on SEDAR its Annual Information Form for the year ended December 31, 2003, which includes the disclosure and reports relating to reserves data and other oil and gas information required pursuant to National Instrument 51-101 of the Canadian Securities Administrators. Hawker will also file these documents on the Electronic Data Gathering, Analysis and Retrieval (EDGAR) system in the United States. Copies of these documents may be obtained via www.sedar.com or the company’s Web site, www.hawkerinc.com.

The Toronto Stock Exchange has neither approved nor disapproved the contents of this release.

FOR FURTHER INFORMATION PLEASE CONTACT:

Hawker Resources Inc.

Mr. David A. Tuer, President & CEO
Tel.: (403) 261-6883

Mr. Barry R. Herring, Senior Vice President & CFO
Tel.: (403) 261-6883

ADVISORY: The Toronto Stock Exchange has neither approved nor disapproved of the information contained herein. Certain information regarding the company, including management’s assessment of future plans and operations, may constitute forward-looking statements under applicable securities law and necessarily involve risks associated with oil and gas exploration, production, marketing and transportation such as loss of market, volatility of prices, currency fluctuations, imprecision of reserve estimates, environmental risks, competition from other producers and ability to access sufficient capital from internal and external sources; as a consequence, actual results may differ materially from those anticipated. The company assumes no obligation to update the forward-looking statements or to update the reasons why actual results could differ from those contemplated by the forward-looking statements.

EX-2 4 o12483exv2.htm MANAGEMENT DISCUSSION AND ANALYSIS

Exhibit 2

Management’s Discussion and Analysis

Management’s discussion and analysis of the financial and operating results for the Company should be read in conjunction with the Company’s audited financial statements and related notes for the years ended December 31, 2003 and 2002. This discussion contains forward-looking statements that are not historical in nature and involves risks and uncertainties. Forward-looking statements are not guarantees as to the Company’s future results since there are inherent difficulties in predicting future results. Accordingly, actual results could differ materially from those expressed or implied in the forward-looking statements.

     At the Annual and Special Meeting of SYNSORB Biotech Inc. (“SYNSORB”) shareholders held April 3, 2003, shareholders approved the planned conversion of the company into an oil and gas enterprise and changed the company’s name to Hawker Resources Inc. (“Hawker” or “the Company”). Prior to 2002, SYNSORB conducted pharmaceutical drug research and development. On December 10, 2001 SYNSORB terminated its drug development activities.

     On June 30, 2003, the conversion of the Company to an oil and gas enterprise was completed when Hawker acquired natural gas properties located in the Lavoy and Cold Lake areas. Hawker’s 2003 operating results reflect the costs of converting Hawker into an oil and gas enterprise and the results of its first six months of oil and gas operations. Accordingly, the 2003 operating results are not directly comparable to the 2002 operating results when the Company was winding down its biotech operations and seeking strategic alternatives.

REVENUE

Production revenue for the year ended December 31, 2003 was $17,582,000. The second half of 2003 marked the commencement of oil and gas operations for the Company and accordingly, there were no production revenues for the year ended December 31, 2002.

     All of the Company’s production was natural gas. Natural gas sales volumes for the six months ended December 31, 2003 averaged 16,346 mcf/d and the average price received was $5.84 per mcf. Hawker’s production was from the Lavoy area and the Cold Lake/Bonnyville area.

     The majority of the Company’s natural gas production is sold to aggregators and the Company receives AECO spot or AECO month index prices. The Company has entered into commodity price contracts to reduce the volatility of commodity prices and to ensure that funds are available to support planned capital expenditures. The financial and physical contracts currently in place are summarized in the table on page 26.

     Interest income for the year ended December 31, 2003 was $78,000 versus $32,000 for the year ended December 31, 2002. The increases were due to higher cash balances on hand during the first half of 2003 when the Company did not have bank debt, as compared to 2002.

FINANCIAL HIGHLIGHTS

YEAR ENDED DECEMBER 31	2003		2002
(in thousands of dollars, except per share amounts)
Revenue	$	17,582	$	—
Cash flow from operations (1)		5,985		(1,759	)
Per common share — basic and diluted		0.35		(0.35	)
Net earnings		2,314		3,766
Per common share — basic and diluted		0.14		0.76

⁽¹⁾ Cash flow from operations is a non-GAAP term that represents net earnings adjusted for non-cash items including depletion and depreciation, accretion, future income tax recovery, stock-based compensation, asset write-downs and gains (losses) on sale of assets. Cash flow per share is calculated by dividing cash flow from operations as previously described by the weighted average number of common shares outstanding during the year. The Company evaluates its performance based on earnings and cash flow from operations. The Company considers cash flow from operations a key measure as it demonstrates the Company’s ability to generate the cash flow necessary to fund future growth through capital investment and to repay debt.

- PAGE 25 -

CONTRACT	TERM	VOLUME	AVERAGE PRICE		INDEX
Collar	Jan 2004 - Mar 2004	4,830 GJ/D	$	6.36 - $7.15	AECO
Collar	Apr 2004 - Oct 2004	18,000 GJ/D	$	5.50 - $6.37	AECO
Fixed Price	Jan 2004 - Mar 2004	1,610 GJ/D	$	6.76	AECO
Fixed Price	Apr 2004 - Oct 2004	10,000 GJ/D	$	5.76	AECO

     Other revenue received by the Company during 2003 primarily related to an exclusive license agreement of certain of its patents regarding toxin-binding sugars. Pursuant to this license agreement, the Company received net proceeds of $375,000. The Company also received a milestone payment of $105,000 with respect to the previous sale of its INH Technologies Inc. subsidiary. Other revenue of $107,000 received during the year ended December 31, 2002 also related to a milestone payment received by the Company with respect to the previous sale of its INH Technologies Inc. subsidiary. The Company cannot predict the likelihood, timing or amount of any further milestone or licensing receipts.

ROYALTY EXPENSE

Royalty expense for the year ended December 31, 2003 was $4,205,000, or 24 percent of production revenue. There was no royalty expense for 2002 as the Company did not have oil and gas operations.

PRODUCTION EXPENSE

Production expense for 2003 was $2,028,000 or $0.67 per mcf, including accretion expense of $100,000. There was no production expense for 2002 as the Company did not have oil and gas operations.

OPERATING NETBACKS

($/mcf)	2003
Revenues		5.84
Royalties		(1.40	)
Operating expenses		(0.67	)
Operating netbacks		3.77

GENERAL AND ADMINISTRATIVE EXPENSE

Net general and administrative expense for the year ended December 31, 2003 was $4,590,000, an increase of 183 percent from the $1,621,000 for the year ended December 31, 2002. The increase in general and administrative expenses was attributable to the addition of staff, use of consultants and increased general administrative costs associated with the Company becoming a fully operational oil and gas entity. General and administrative expenses totaling $564,000 were capitalized for the year ended December 31, 2003.

INTEREST EXPENSE

Interest expense for the year ended December 31, 2003 was $679,000 as compared with $71,000 for the year ended December 31, 2002. The increase in interest expense was a result of using the credit facility as an operating line of credit and to fund asset acquisitions.

DEPLETION AND DEPRECIATION

Depletion and depreciation expense for the year ended December 31, 2003 was $8,933,000 as compared with $26,000 for the year ended December 31, 2002. On a unit of production basis, depletion and depreciation expense on oil and gas assets was $17.79 per boe for the year ended December 31, 2003. Depletion and depreciation associated with oil and gas assets accounted for the large increase in depletion and depreciation expense for 2003 as compared with 2002. Depreciation expense for 2002 related solely to computer equipment and office furniture and equipment.

- PAGE 26 -

ASSET RETIREMENT OBLIGATIONS

In 2003, the Company retroactively adopted the recommendations of the Canadian Institute of Chartered Accountants on accounting for asset retirement obligations. The new pronouncement requires the Company to recognize the fair value of a liability for an asset retirement obligation in the period in which it is incurred and a corresponding increase in the carrying value of the related long-lived asset. The liability is subsequently adjusted due to the passage of time, and is recognized as an accretion expense in the statement of earnings. The liability is also adjusted due to revisions in either the timing or the amount of the original estimated cash flows associated with the liability. The increase in the carrying value of the capital asset is amortized using the unit of production method based on estimated gross proven reserves as determined by independent engineers.

     The Company did not have long-lived assets subject to retirement obligations as at December 31, 2002 and therefore this change in accounting policy had no impact on the December 31, 2002 financial statements. The effect of this change on the December 31, 2003 balance sheet was an increase in capital assets of $3,191,000 and the recognition of an asset retirement obligation of $3,499,000. The change in accounting for asset retirement obligations as compared to the site restoration approach resulted in an increase in net earnings of $217,000 for the year ended December 31, 2003 ($0.01 per share).

STOCK-BASED COMPENSATION

Effective January 1, 2003, the Company adopted the recommendations of the Canadian Institute of Chartered Accountants on accounting for stock based compensation. Under this new pronouncement, stock based compensation expense is recorded for all stock options granted on or after January 1, 2003. For the year ended December 31, 2003, the impact of the adoption of this standard on the financial statements as at December 31, 2003 was a decrease in net earnings of $132,000 ($0.01 per share) and a corresponding increase in contributed surplus.

LEASE ABANDONMENT EXPENSE

During the third quarter of 2003, the Company consolidated its office space. A provision of $322,000 was made during the third quarter for residual lease costs on office space no longer occupied by the Company. This provision was increased by $180,000 to a total of $502,000 during the fourth quarter when sublease arrangements were modified. There was no lease abandonment expense for 2002.

OPERATING COSTS AND WRITE-DOWNS ASSOCIATED WITH ASSETS HELD FOR SALE

Assets held for sale are comprised of the pharmaceutical manufacturing facility and related manufacturing equipment associated with the former biotech operations of the Company. For the year ended December 31, 2003, operating costs and write-downs associated with assets held for sale were $190,000 as compared with $7,408,000 for the year ended December 31, 2002. During 2003, the Company wrote-down the carrying value of assets held for sale by $145,000 to the estimated net realizable value. During 2002, assets held for sale were written down by a total of $7,097,000.

INCOME TAXES

The Company’s current income tax expense was solely comprised of the Large Corporations Tax, and for the year ended December 31, 2003, totaled $345,000. There was no tax expense for the year ended December 31, 2002. The increase is due to the higher capital base of the Company attributable to the debt and equity financings completed during 2003.

     On December 5, 2003, the Company issued 2,900,000 flow-through shares for $15,225,000. In accordance with the agreements between the Company and the flow-through shareholders, the Company renounced $15,225,000 of Canadian Cumulative Exploration Expense as of December 31, 2003. This renunciation gave rise to a future tax liability of

- PAGE 27 -

$5,271,000. The tax pools of the Company are sufficient to offset this liability and accordingly, a future tax recovery was recognized in an equal amount.

     Currently, the Company has tax pools that would provide for a $6,787,000 future tax benefit. This benefit has not been recognized due to the uncertainty of the future use of all of the tax pools.

LIQUIDITY AND CAPITAL RESOURCES

Pursuant to various financing agreements entered into April 3, 2003, the Company raised $3,645,000 through the issue of 430,493 Series A Debentures for $3,616,000, 430,493 Series A Warrants for $12,000, 2,152,465 voting preferred shares for $6,000 and 3,874,437 non-voting preferred shares for $11,000.

     Each Series A Warrant entitled the holder thereof to purchase five common shares and nine Class A common shares on the concurrent surrender of the warrant, five voting preferred shares, nine non-voting preferred shares, and one Series A Debenture. On May 29, 2003, immediately after the issue of a receipt for the prospectus offering common shares for sale and issue, the Series A Warrants were exercised and the Company issued 2,152,465 common shares and 3,874,437 Class A common shares upon the surrender of the voting and non-voting preferred shares and Series A Debentures.

     On May 29, 2003, the Company issued a fully marketed prospectus offering 14,286,000 common shares to the public priced at $3.15 per share. The issuance was fully subscribed and the public offering was completed on June 12, 2003. The Company received $42,301,000, net of underwriting fees.

     On December 5, 2003, the Company issued through a private placement, 2,900,000 common shares on a flow-through basis at a price of $5.25 per share. The Company received $14,514,000, net of underwriting fees.

     On December 30, 2003, the Company issued, pursuant to a prospectus offering, 11,200,000 common shares at a price of $4.05 per share. The Company received $43,092,000, net of underwriting fees.

     On March 31, 2003 the Company acquired all of the shares of 1022971 Alberta Ltd. (“1022971”) for a nominal amount and the Company was assigned an option to purchase up to a 49 percent interest in certain oil and gas properties west of the fourth meridian (“W4M Properties”) owned by Southward Energy Ltd. (“Southward”). On April 30, 2003, 1022971 acquired all of the shares of Southward. Immediately thereafter, Southward sold its oil and gas properties, excluding a one percent undivided interest in the W4M Properties and a 100 percent interest in seismic data, to an independent third party.

     On June 30, 2003, the Company exercised its option to purchase the W4M Properties. Further on June 30, 2003, the Company purchased the one percent undivided interest in the W4M Properties of Southward and the non-cash working capital of Southward was conveyed to the Company. Also on June 30, 2003, all of the shares of 1022971, which included Southward and all of its subsidiaries, were sold for nominal consideration to an independent third party. The total purchase price of the 50 percent interest in the W4M Properties and non-cash working capital of $71,337,000 was funded by the net proceeds of the prospectus offering and bank debt.

     On August 14, 2003, the Company acquired all of the shares of 1053638 Alberta Ltd. and 1053639 Alberta Ltd., seismic data companies. On August 19, 2003, the Company sold all of the shares of 1053638 Alberta Ltd. The net cash consideration paid was $1,200,000. On December 31, 2003, 1053639 Alberta Ltd. was amalgamated with Hawker.

     On December 30, 2003, Hawker acquired all of the shares of Pointwest Energy Inc., a privately held oil and gas company with operations in Alberta and B.C., for total consideration of $67,247,000, funded by bank debt and the net proceeds of the December 30, 2003 share issue. Pointwest Energy Inc. was amalgamated with Hawker on December 30, 2003. Upon completion of the review of the minor properties of Pointwest, the Company has

- PAGE 28 -

agreed to sell those properties for approximately $6 million. The Company is also seeking offers on the Valhalla property due to its limited future potential.

     During the year ended December 31, 2003, the Company spent $14,783,000 on capital asset additions, excluding property acquisitions. There were no capital expenditures during 2002, reflecting the wind-down of the biotech operations of the Company.

CAPITAL EXPENDITURES

YEAR ENDED DECEMBER 31	2003
(in thousands of dollars)
Exploration and Development Expenditures
Lease acquisition and retention	$	1,916
Geological and geophysical		4,674
Drilling and completion		5,439
Facilities and equipment		2,475
Total Exploration and Development Expenditures		14,504
Other capital assets		279
Total Capital Expenditures	$	14,783

     During the second half of 2003, the Company participated in the drilling of 35 gross (17.6 net) wells. This resulted in 27 gross (13.6 net) wells and 8 gross (4.0 net) dry holes. As at December 31, 2003, only 12 of these wells had been connected into processing facilities and/or pipelines. The Company and the Lavoy operator are taking steps to accelerate the tie-in process.

     For the year ended December 31, 2003, proceeds of $1,173,000 were received on assets held for sale as compared with $44,000 for the year ended December 31, 2002. The assets held for sale relate to the pharmaceutical manufacturing facility and related manufacturing equipment associated with the former biotech operations of the Company.

     During the 2003, the Company received proceeds of $192,000 from the exercise of stock options under the stock option plan. The options exercised were granted while the Company was operating as a biotech firm.

     The Company has a $54 million extendible revolving term credit facility and a $10 million non-revolving bridge facility. As at December 31, 2003, $9.9 million of the extendible revolving term facility remained unutilized while the $10 million non-revolving bridge facility was fully utilized. The Company plans to use proceeds from oil and gas property sales to fund the repayment of the non-revolving bridge facility. The capacity of the extendible revolving term credit facility, combined with cash flow from operations, is expected to be sufficient to support the Company’s 2004 capital program.

     As at December 31, 2003, the Company’s working capital deficiency was $17,828,000, including the bridge financing of $10,000,000, compared to working capital of $412,000 as at December 31, 2002, reflecting the business acquisitions and year end activity level of the Company.

     Pursuant to the terms of a technology commercialization agreement pertaining to pharmaceutical drug development, the Company received a grant from the Alberta Heritage Foundation for Medical Research (“AHFMR”) in 1995. The Company was required to repay the amount advanced of $387,000 plus a royalty equivalent to the amount initially received. Any required repayment and royalty was based on gross sales of SYNSORB related products commencing January 1, 2000 with payments equal to the lesser of five percent of gross sales or $100,000 per annum commencing 90 days after January 1, 2001. Due to the conversion of the Company into an oil and gas enterprise and the nascent stage of the SYNSORB technology, the AHFMR accepted a royalty payment of $18,550 during the third quarter of 2003 in exchange for a full release of Hawker from the terms of the technology commercialization agreement.

- PAGE 29 -

RISKS AND UNCERTAINTIES

The Company is engaged in the exploration, development, production and acquisition of crude oil and natural gas. This business is inherently risky and there is no assurance that hydrocarbon reserves will be discovered and economically produced. Financial risks associated with the petroleum industry include fluctuations in commodity prices, interest rates, and currency exchange rates along with the credit risk of the Company’s industry partners. Operational risks include reservoir performance uncertainties, the reliance on operators of our non-operated properties, competition, environmental and safety issues, and a complex and changing regulatory environment.

Hawker is taking steps to reduce its business risks by increasing the number of core areas it has and increasing the number of areas it operates. This will spread the operational risks over several areas, reducing the potential impact on Hawker of unfavourable operational issues that may occur at any one area. It will also enable Hawker to control the timing, direction and costs related to exploration and development activities. Environmental and safety risks are mitigated through compliance with provincial and federal environmental and safety regulations, by maintaining adequate insurance, and by adopting appropriate emergency response and safety procedures.

The Company manages commodity pricing uncertainties with a risk management program that encompasses a variety of financial instruments. These include forward sales contracts on natural gas production and financial sales contracts.

RECENT ACCOUNTING DEVELOPMENTS

The Canadian Institute of Chartered Accountants has issued a new accounting guideline related to full cost accounting for oil and gas. The recommendations contained in the guideline are to be implemented effective January 1, 2004 and it is expected adoption will not materially impact results.

OUTLOOK

At the start of 2003, the Company was a failed biotech firm seeking strategic alternatives. During the first half of 2003, the Company successfully transformed into an oil and gas enterprise and, at June 30, 2003, had a 50 percent working interest in two properties: the non-operated Lavoy area and the Cold Lake/Bonnyville area, which is operated by Hawker.

With the acquisition of Pointwest, the Company also has an average 85 percent working interest in the Boundary Lake area and a 100 percent working interest in the Valhalla property, both operated by Hawker, along with some minor non-operated properties. In the six short months since becoming an oil and gas enterprise, Hawker has also developed and drilled two successful gas wells on one of its own internally generated prospects at Chigwell, an emerging core area in that it provides the Company with the opportunity to add value to the property in the future. The Company has also assembled an exploration team and land outside its producing areas, including Purple Springs and Wild River, that will enable it to develop new core areas in 2004.

For fiscal 2004, the Company has budgeted $55.8 million of capital expenditures for exploration and exploitation opportunities. Hawker anticipates achieving an average production level in excess of 7,000 boe/d for 2004.

- PAGE 30 -

EX-1

News Release Dated March 30, 2004

EX-2

Management Discussion and Analysis

EX-3

Exhibit 3

Management’s Report and
Auditors’ Report to Shareholders

MANAGEMENT’S REPORT

The financial statements of Hawker Resources Inc. were prepared by management in accordance with Canadian generally accepted accounting principles. The financial and operating information presented in this annual report is consistent with that shown in the financial statements.

Management has designed and maintains a system of internal controls to provide reasonable assurance that all assets are safeguarded and to facilitate the preparation of financial statements for reporting purposes. Timely release of financial information sometimes necessitates the use of estimates when transactions affecting the current accounting period cannot be finalized until future periods. Such estimates are based on careful judgments made by management.

External auditors appointed by the shareholders have conducted an independent examination of the Company’s accounting records in order to express their opinion on the financial statements.

The Board of Directors is responsible for ensuring that management fulfils its responsibilities for financial and internal control. The Board exercises this responsibility through its Audit Committee. The Audit Committee, which consists of non-management members, has met with the external auditors and management in order to determine that management has fulfilled its responsibilities in the preparation of the financial statements. The Audit Committee has reported its findings to the Board of Directors who have approved the financial statements.

DAVID A. TUER
President and Chief Executive Officer

BARRY HERRING
Senior Vice President and Chief Financial Officer
Calgary, Canada
March 17, 2004

TO THE SHAREHOLDERS OF HAWKER RESOURCES INC.

We have audited the balance sheets of Hawker Resources Inc. as at December 31, 2003 and 2002 and the statements of earnings and deficit and cash flows for the years then ended. These financial statements are the responsibility of the Company’s management. Our responsibility is to express an opinion on these financial statements based on our audits.

We conducted our audits in accordance with Canadian generally accepted auditing standards. Those standards require that we plan and perform an audit to obtain reasonable assurance whether the financial statements are free of material misstatement. An audit includes examining, on a test basis, evidence supporting the amounts and disclosures in the financial statements. An audit also includes assessing the accounting principles used and significant estimates made by management, as well as evaluating the overall financial statement presentation.

In our opinion, these financial statements present fairly, in all material respects, the financial position of the Company as at December 31, 2003 and 2002 and the results of its operations and its cash flows for the years then ended in accordance with Canadian generally accepted accounting principles.

CHARTERED ACCOUNTANTS
Calgary, Canada
March 10, 2004
(except for note 17 which is as of March 17, 2004)

- PAGE 31 -

Balance Sheets

AS AT DECEMBER 31	2003			2002
(in thousands of dollars)
ASSETS
Current
Cash	$	–		$	289
Accounts receivable		11,577			27
Investments		2,500			–
Prepaids and other current assets		1,845			176
		15,922			492
Assets held for sale (Note 5)		2,190			3,500
Capital assets (Notes 4, 6 and 7)		166,990			23
	$	185,102		$	4,015
LIABILITIES AND SHAREHOLDERS’ EQUITY
Current
Accounts payable and accrued liabilities	$	23,750		$	80
Bank loan (Note 7)		10,000			–
		33,750			80
Bank loan (Note 7)		44,149			–
Leasehold inducements		247			–
Alberta Heritage Foundation grant (Note 8)		–			387
Asset retirement obligations (Note 3)		3,499			–
Commitments and contingencies (Notes 4, 15 and 16)
Shareholders’ Equity (Note 9)
Share capital		110,204			12,741
Contributed surplus		132			–
Deficit		(6,879	)		(9,193	)
		103,457			3,548
	$	185,102		$	4,015

See accompanying notes to the financial statements

On behalf of the Board:
DIRECTOR	DIRECTOR

- PAGE 32 -

Statements of Earnings and Deficit

FOR THE YEARS ENDED DECEMBER 31	2003			2002
(in thousands of dollars, except per share amounts)
				Restated
				(Note 4 (d))
Revenue
Production revenue	$	17,582		$	–
Royalties		(4,205	)		–
		13,377			–
Interest income		78			32
Other		487			107
		13,942			139
Expenses
Production		2,028			–
General and administrative (Note 10)		4,590			1,621
Interest on long-term debt		679			71
Depletion and depreciation		8,933			26
		16,230			1,718
Loss before the following		(2,288	)		(1,579	)
Lease abandonment expense		(502	)		–
Operating costs and write-downs associated with assets held for sale		(190	)		(7,408	)
Gain on the sale and distribution of Oncolytics shares		–			13,067
Share of loss from equity investment in Oncolytics		–			(314	)
Alberta Heritage Foundation grant settlement (Note 8)		368			–
Earnings (loss) before taxes		(2,612	)		3,766
Taxes
Future income tax recovery (Note 11)		(5,271	)		–
Capital taxes		345			–
		(4,926	)		–
Net earnings		2,314			3,766
Deficit, beginning of year		(9,193	)		(72,855	)
Reduction of stated capital (Note 9)		–			59,896
Deficit, end of year	$	(6,879	)	$	(9,193	)
Basic and diluted net earnings per common share (Note 9)	$	0.14		$	0.76

See accompanying notes to the financial statements

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Statements of Cash Flows

YEARS ENDED DECEMBER 31	2003			2002
(in thousands of dollars)
				Restated
				(Note 4 (d))
OPERATING ACTIVITIES
Net earnings	$	2,314		$	3,766
Add (deduct) non-cash items:
Depletion, depreciation and asset write-downs		9,078			7,216
Accretion expense		100			–
Alberta Heritage Foundation grant settlement (Note 8)		(368	)		–
Future income tax recovery		(5,271	)		–
Stock-based compensation (Note 10)		132			–
Share of loss from equity investment in Oncolytics		–			314
Gain on sale and distribution of Oncolytics shares		–			(13,067	)
Issuance of stock options for services		–			12
		5,985			(1,759	)
Net change in non-cash working capital (Note 14)		5,660			(4,779	)
		11,645			(6,538	)
INVESTING ACTIVITIES
Proceeds from sale of capital assets		1,173			44
Acquisition of oil and gas properties (Note 4)		(139,784	)		–
Additions to oil and gas properties		(14,504	)		–
Additions to other capital assets		(279	)		–
Leasehold inducements received		247			–
Proceeds from sale of Oncolytics shares		–			6,898
Net change in non-cash working capital (Note 14)		806			–
		(152,341	)		6,942
FINANCING ACTIVITIES
Common shares issued on exercise of options		192			–
Common shares issued for cash		105,633			–
Issue of debentures and warrants		3,645			–
Increase in bank loan		37,720			–
Share issue costs		(6,736	)		–
Costs of distribution of shares in Oncolytics		–			(46	)
Repayment of bank debt		–			(5,910	)
Alberta Heritage Foundation royalty payment (Note 8)		(19	)		–
Net change in non-cash working capital (Note 14)		(28	)		–
		140,407			(5,956	)
Decrease in cash		(289	)		(5,552	)
Cash, beginning of year		289			5,841
Cash, end of year	$	–		$	289

Supplemental disclosure of cash flow information (Note 14)

See accompanying notes to the financial statements

- PAGE 34 -

Notes to Financial Statements

Years ended December 31, 2003 and 2002
(Tabular amounts in thousands of dollars, unless otherwise noted)

1. NATURE OF OPERATIONS

Prior to 2002, SYNSORB Biotech Inc. (“SYNSORB”) conducted pharmaceutical drug research and development. On December 10, 2001 SYNSORB terminated its drug development activities. At the Annual and Special Meeting of SYNSORB shareholders held April 3, 2003, shareholders approved the planned conversion of the company into an oil and gas enterprise and changed the company’s name to Hawker Resources Inc.

2. SUMMARY OF SIGNIFICANT ACCOUNTING POLICIES

The financial statements of Hawker Resources Inc. (the “Company” or “Hawker”) have been prepared in accordance with Canadian generally accepted accounting principles. The timely preparation of financial statements requires that management makes estimates and assumptions, and use judgement regarding assets, liabilities, revenues and expenses. Such estimates primarily relate to unsettled transactions and events as of the date of the financial statements. Accordingly, actual results may differ from estimated amounts. In the opinion of management, these financial statements have been properly prepared within reasonable limits of materiality and within the framework of the significant accounting policies summarized below.

(a) Capital Assets

Cost

The Company follows the full cost method of accounting whereby all costs relating to the acquisition of, exploration for and development of oil and gas reserves are capitalized in a single Canadian cost center. Such costs include lease acquisition, lease rentals on undeveloped properties, geological and geophysical, drilling both productive and non-productive wells, production equipment and overhead charges directly related to acquisition, exploration and development activities.

     Gains or losses are not recognized upon the disposition of oil and gas properties unless such a disposition would change the depletion rate by 20 percent or more. Gains and losses are recognized upon the disposition of other assets.

     Other capital assets are recorded at cost.

Depletion, depreciation and amortization

All costs of acquisition, exploration and development of oil and gas reserves, associated tangible plant and equipment costs (net of salvage value), and estimated costs of future development of proven undeveloped reserves are depleted and depreciated by the unit of production method based on estimated gross proven reserves as determined by independent engineers.

     Costs of unproved properties and seismic costs on undeveloped land are initially excluded from oil and gas properties for the purpose of calculating depletion. When proven reserves are assigned or the property is considered to be impaired, the cost of the property or the amount of the impairment is added to costs subject to depletion.

     The relative volumes of oil and natural gas reserves and production are converted to equivalent barrels of oil based on the relative energy content of each product on a 6 to 1 basis.

     Depreciation of capital assets not related to oil and gas properties is provided using the declining balance method at rates between 20 and 30 percent. Leasehold improvements are amortized on a straight-line basis over the term of the lease.

Impairment

The Company applies a ceiling test to the capitalized costs of its oil and gas properties, net of future income taxes and asset retirement obligations, to ensure that the net carrying value does not exceed the estimated value of future net revenues from production of gross proven reserves plus undeveloped properties less future production-related general and administrative expenses, financing costs, site restoration and abandonment costs and income taxes. Any reduction in the net carrying value of oil and gas properties as a result of the ceiling test is charged to operations.

     The calculation of future net revenues is based on sales prices, costs and regulations in effect at period end.

     The carrying value of undeveloped properties (land and seismic data) is reviewed periodically and written down to net realizable value if impairment is determined.

- PAGE 35 -

(b) Asset Retirement Obligations

The Company recognizes the fair value of a liability for an asset retirement obligation in the period in which it is incurred and records a corresponding increase in the carrying value of the related long-lived asset. The fair value is determined through a review of engineering studies, industry guidelines, and management’s estimate on a site by site basis. The liability is subsequently adjusted for the passage of time, and is recognized as an accretion expense in the statement of earnings under asset retirement obligations. The liability is also adjusted due to revisions in either the timing or the amount of the original estimated cash flows associated with the liability. The increase in the carrying value of the asset is amortized using the unit of production method based on estimated gross proven reserves as determined by independent engineers.

(c) Leasehold Inducements

Leasehold inducements are accounted for as a reduction of rental expense over the term of the related lease.

(d) Revenue Recognition

Oil and natural gas sales are recognized as revenue when the commodities are delivered to purchasers.

     Revenue from milestone payments and royalties is recognized when received.

(e) Hedging and Forward Sales Contracts

In certain circumstances, fixed price commodity contracts or commodity derivative contracts are used to reduce the Company’s exposure to adverse fluctuations in commodity prices to protect future cash flow used to finance the Company’s capital expenditure program. Gains and losses relating to commodity derivative contracts which settle via net cash payment and that meet hedge criteria are recognized as part of natural gas sales concurrently with the hedged transaction. The Company does not enter into financial instruments for trading or speculative purposes.

     The Company believes the derivative financial instruments are effective as hedges, both at inception and over the term of the instrument, as the term to maturity, the notional amount and the commodity price basis in the instruments all match the terms of the future revenue stream being hedged.

     Realized and unrealized gains and losses associated with commodity derivative contracts which have been terminated or cease to be effective prior to maturity, are deferred as other current, or non-current, assets or liabilities on the balance sheet, as appropriate, and recognized in earnings in the period in which the underlying hedged transaction is recognized. In the event a designated hedged item is sold, extinguished or matures prior to the termination of the related derivative instrument, any realized or unrealized gain or loss on such derivative instrument is recognized in earnings.

(f) Joint Ventures

Substantially all of the Company’s exploration, development and production activities are conducted jointly with others and, accordingly, these financial statements reflect only the Company’s proportionate interest in such activities.

(g) Stock Based Compensation

Under the Company’s stock option plan, options to purchase common shares are granted to directors, officers, employees and consultants at current market prices. Options issued by the Company in 2003 are accounted for in accordance with the fair value method of accounting for stock-based compensation, and as such the cost of the option is charged to earnings with an offsetting amount recorded to contributed surplus, based on an estimate of the fair value determined using a Black-Scholes options pricing model. No compensation expense has been recorded on options issued in 2002 (see Note 10).

(h) Investments

Investments in marketable securities are recorded at the lower of cost and market value. At December 31, 2003, the investments had a quoted market value of $3,012,000.

- PAGE 36 -

(i) Future Income Taxes

The Company follows the liability method of accounting for income taxes. Under this method, future tax assets and liabilities are determined based on differences between financial reporting and tax bases of assets and liabilities and are measured using substantially enacted tax rates and laws that will be in effect when the differences are expected to reverse. Income tax expense for the period is the tax payable for the period and any change during the period in future income tax assets and liabilities. A valuation allowance is recorded to the extent that there is uncertainty regarding utilization of future tax assets.

(j) Per Common Share Amounts

The Company uses the treasury stock method to determine the dilutive effect of stock options. This method assumes that proceeds from the exercise of stock options would be used to purchase common shares at the average market price during the year.

(k) Measurement Uncertainty

The amount recorded for depletion and depreciation of petroleum and natural gas properties, the provision for asset retirement obligation costs and the ceiling test calculation are based on estimates of gross proven reserves, production rates, commodity prices, future costs and other relevant assumptions. By their nature, these estimates are subject to measurement uncertainty and the effect on the financial statements of changes in such estimates in future years could be significant.

(l) Flow-through Common Shares

Resource expenditure deductions for income tax purposes related to exploration and development activities funded by flow-through share arrangements are renounced to investors in accordance with income tax legislation. The estimated tax benefits transferred to shareholders are recorded as future income taxes and a reduction to share capital when the expenditures are renounced.

(m) Comparative Figures

Certain figures provided for 2002 have been reclassified to conform to the presentation adopted in 2003.

3. CHANGES IN ACCOUNTING POLICIES

(a) Asset Retirement Obligations

In 2003, the Company retroactively adopted the recommendations of the Canadian Institute of Chartered Accountants on accounting for asset retirement obligations. These recommendations replace the existing policy on future site restoration, and as a result, have been treated as a change in accounting policy.

     The new pronouncement requires the Company to recognize the fair value of a liability for an asset retirement obligation in the period in which it is incurred and a corresponding increase in the carrying value of the related long-lived asset. This fair value is determined through a review of engineering studies, industry guidelines, and management’s estimate on a site by site basis. The liability is subsequently adjusted due to the passage of time, and is recognized as an accretion expense in the statement of earnings. The liability is also adjusted due to revisions in either the timing or the amount of the original estimated cash flows associated with the liability. The increase in the carrying value of the capital asset is amortized using the unit of production method based on estimated gross proven reserves as determined by independent engineers.

     The Company estimates the undiscounted cash flows related to asset retirement obligations, adjusted for inflation, to be incurred over the estimated reserve life of the underlying assets will total approximately $4,972,000. The fair value at December 31, 2003 is $3,499,000 using a discount rate of six percent and an inflation rate of two percent. As at December 31, 2003, no funds have been set aside to settle this obligation.

     As the Company did not have long-lived assets subject to retirement obligations as at December 31, 2002, this change in accounting policy had no impact on the December 31, 2002 financial statements. The effect of this change on the December 31, 2003 balance sheet was an increase in capital assets of $3,191,000, and the recognition of an asset retirement obligation of $3,499,000. Accretion expense of $100,000 was included in production expense for the year ended December 31, 2003. The change in accounting for asset retirement obligations as compared to the site restoration approach resulted in an increase in net earnings of $217,000 for the year ended December 31, 2003 ($0.01 per share).

- PAGE 37 -

(b) Stock Based Compensation

Effective January 1, 2003, the Company adopted the recommendations of the Canadian Institute of Chartered Accountants on accounting for stock based compensation. Under this new pronouncement, stock based compensation expense is recorded for all stock options granted on or after January 1, 2003. As permitted by the standard, the Company applied the change prospectively. The pro forma earnings impact of the stock based compensation expense for stock options granted prior to January 1, 2003 is disclosed in Note 10.

     For the year ended December 31, 2003, the impact of the adoption of this standard on the financial statements as at December 31, 2003 was a decrease in net earnings of $132,000 ($0.01 per share) and a corresponding increase in contributed surplus.

4. BUSINESS ACQUISITIONS AND DISPOSITIONS

(a) 1022971 Alberta Ltd.

On March 31, 2003 the Company acquired all of the shares of 1022971 Alberta Ltd. (“1022971”) for a nominal amount and the Company was assigned an option to purchase up to a 49 percent interest in certain oil and gas properties west of the 4th meridian (“W4M Properties”) owned by Southward Energy Ltd. (“Southward”). On April 30, 2003, 1022971 acquired all of the shares of Southward. Immediately thereafter, Southward sold its oil and gas properties, excluding a one percent undivided interest in the W4M Properties and a 100 percent interest in seismic data, to an independent third party.

     On June 30, 2003, the Company exercised its option to purchase a 49 percent interest in the W4M Properties. Further on June 30, 2003, the Company purchased the one percent undivided interest in the W4M Properties of Southward and the non-cash working capital of Southward was conveyed to the Company. Also on June 30, 2003, all of the shares of 1022971, which included Southward and all of its subsidiaries, were sold for nominal consideration to an independent third party.

     The resultant acquisition of a 50 percent interest in the W4M Properties on June 30, 2003 has been accounted for using the purchase method of accounting. The results of operations for the W4M Properties have been included in the financial statements since June 30, 2003.

     The following table summarizes the estimated fair value of the assets and liabilities assumed at the date of acquisition:

Capital assets	$	70,514
Asset retirement obligations		(2,833	)
Non-cash working capital		3,656
Cash cost	$	71,337

     The Company has agreed to indemnify the purchaser of Southward for income tax and legal expenses to a maximum amount of $1 million for matters arising prior to the April 30, 2003 acquisition of Southward.

(b) 1053638 Alberta Ltd. and 1053639 Alberta Ltd.

On August 14, 2003, the Company acquired all of the shares of 1053638 Alberta Ltd. and 1053639 Alberta Ltd., seismic data companies. On August 19, 2003, the Company sold all of the shares of 1053638 Alberta Ltd. The net acquisitions were accounted for by the purchase method and the purchase price was allocated as follows:

     Allocation of purchase price:

Capital assets	$	1,200
Cash cost	$	1,200

     The disposition of 1053638 Alberta Ltd. did not result in any gain or loss to the Company. On December 31, 2003, 1053639 Alberta Ltd. was amalgamated with the Company.

- PAGE 38 -

(c) Pointwest Energy Inc.

On December 30, 2003 the Company acquired all of the shares of Pointwest Energy Inc. (“Pointwest”), a privately held oil and gas company. The acquisition was accounted for by the purchase method and the purchase price was allocated as follows:

     Allocation of purchase price:

Capital assets	$	89,363
Bank debt		(16,429	)
Asset retirement obligations		(518	)
Non-cash working capital		(5,169	)
Cash cost	$	67,247

     On December 30, 2003, Pointwest was amalgamated with the Company.

(d) Oncolytics Biotech Inc.

As at December 31, 2001, the Company held 6,255,800 common shares of Oncolytics Biotech Inc. (“Oncolytics”). On May 7, 2002 approval was received from both the shareholders of the Company and the shareholders of Oncolytics for the distribution of not less then 4,000,000 Oncolytics shares to the shareholders of the Company on a pro rata basis. On May 8, 2002 the Company received approval from the Court of the Queen’s Bench of Alberta to distribute these Oncolytics shares and the distribution of 4,000,235 Oncolytics shares was made effective May 15, 2002. The deemed value of these shares on the date of distribution, net of legal fees with respect to the transaction, was $11,600,000 resulting in a gain on distribution of $8,325,000. The transaction was marked to market and accounted for as a return of capital (see Note 9). As part of this transaction the Company’s holding of 1,500,000 million shares in BCY Life Sciences Inc. was transferred to Oncolytics. No value had been assigned to these shares in the accounts of the Company and no gain or loss was recorded as a result of the transaction. The market value of the BCY shares on May 15, 2002 was $300,000.

     The Company had used the equity method of accounting for its investment in Oncolytics Biotech Inc. (“Oncolytics”) up until the distribution of the majority of its holding in Oncolytics on May 15, 2002. Under this method of accounting, the Company included in its net earnings its share of the net earnings or losses of Oncolytics. Upon further review of the facts surrounding the distribution of the Oncolytics shares, the Company has concluded that it should have ceased to equity account for Oncolytics at the end of the first quarter of 2002 when it no longer exerted significant influence over Oncolytics. If the Company had ceased equity accounting for its investment in Oncolytics at that time, Hawker would not have recorded the portion of Oncolytics’ second quarter loss included in its statements. To reflect this correction, the Company has restated its financial statements for the year ended December 31, 2002 by decreasing the share of loss from equity investment in Oncolytics and decreasing the gain on the subsequent sale and distribution of Oncolytics shares by $157,000 resulting in no change to reported net earnings for the year. The balance sheet and cash flows for 2002 were not affected by this change.

     During the year ended December 31, 2002, the Company sold 2,255,565 common shares in Oncolytics for net proceeds of $6,898,000 resulting in a gain on sale of $4,742,000. As at December 31, 2002 the Company did not hold any common shares of Oncolytics.

5. ASSETS HELD FOR SALE

Assets held for sale are comprised of the pharmaceutical manufacturing facility and related manufacturing equipment associated with the former biotech operations of the Company. During 2003, manufacturing equipment with a carrying value of $940,000 was sold and the Company wrote down the carrying value of the remaining assets held for sale by $145,000. The assets held for sale are recorded at the lower of carrying value and market value. Market value was based on estimated value as determined by independent realty advisors.

- PAGE 39 -

6. CAPITAL ASSETS

			Accumulated
			Depletion and		Carrying
2003	Cost		Depreciation		Value
Oil and gas properties	$	175,631	$	8,916	$	166,715
Other		295		20		275
	$	175,926	$	8,936	$	166,990

			Accumulated
			Depletion and		Carrying
2002	Cost		Depreciation		Value
Other	$	526	$	503	$	23

     Unproved properties and seismic related to the W4M Properties amounting to $16,122,000 have been excluded from the depletion and depreciation calculation for 2003. No depletion and depreciation has been recorded on the Pointwest properties as they were acquired December 30, 2003. Future development costs on proven undeveloped reserves of $1,269,000 are included in the depletion and depreciation calculation.

     At December 31, 2003, the Company capitalized $564,000 of overhead directly related to exploration and development activities.

7. BANK LOAN

The Company has a $54 million extendible revolving term credit facility from a Canadian chartered bank. This facility bears interest at rates varying from Canadian prime rate or U.S. base rate of such bank to the Canadian prime rate or U.S. base rate plus 75 basis points, payable monthly in arrears. The Company may also borrow by way of bankers’ acceptances, which are subject to a stamping fee, or by way of LIBOR based loans which are subject to an interest rate spread payable to the bank. The loan is a revolving facility until June 30, 2004 with annual extension periods available at the bank’s discretion. After the revolving phase, the facility becomes a term facility payable in full one year from the date the revolving facility is terminated. This facility is subject to semi-annual review and re-determination of the Company’s borrowing base by the bank, with the next review to occur by March 31, 2004. So long as the loan remains revolving and the borrowing base supports the facility outstanding, there are no repayment requirements.

     The Company also has a $10 million non-revolving bridge facility from the same Canadian chartered bank. This bridge facility, available to the Company solely for the acquisition of Pointwest, was fully drawn upon as at December 31, 2003. The bridge facility bears interest at rates varying from Canadian prime rate plus 250 basis points, payable monthly in arrears. The Company may also borrow by way of bankers’ acceptances that are subject to a stamping fee payable to the bank. The bridge facility is repayable in full on or prior to September 30, 2004.

     While any amounts are outstanding under the bridge facility, the loan margins on both the extendible revolving term credit facility and the bridge facility will be increased by (i) 25 basis points effective May 1, 2004; (ii) 50 basis points effective June 1, 2004; (iii) 100 basis points effective July 1, 2004; (iv) 150 basis points effective August 1, 2004; and (v) 200 basis points effective September 1, 2004.

     Collateral pledged for the facilities consists of a first floating charge demand debenture in the amount of $150 million over all of the property of the Company.

     The effective interest rate on the amounts outstanding under the facility at December 31, 2003 was 5.25 percent.

     At December 31, 2003, irrevocable standby letters of credit which guarantee certain natural gas transportation arrangements had been issued for a total of $311,000.

8. ALBERTA HERITAGE FOUNDATION GRANT

Pursuant to the terms of a technology commercialization agreement pertaining to pharmaceutical drug development, the Company received a grant from the Alberta Heritage Foundation for Medical Research (“AHFMR”) during 1995. The Company was required to repay the amount advanced of $387,000 plus a royalty equivalent to the amount initially received. Any required repayment and royalty was based on gross sales of SYNSORB related products commencing January 1, 2000

- PAGE 40 -

with payments equal to the lesser of five percent of gross sales or $100,000 per annum commencing 90 days after January 1, 2001. Due to the conversion of the Company into an oil and gas enterprise and the nascent stage of the SYNSORB technology, the AHFMR accepted a royalty payment of $18,550 during 2003 in exchange for a full release of Hawker from the terms of the technology commercialization agreement.

9. SHARE CAPITAL

(a) Authorized:

Unlimited number of voting common shares without par value.
Unlimited number of non-voting class A common shares without par value.
Unlimited number of preferred shares to be issued in series.

(b) Common Shares Issued

	2003					2002
	Number					Number
	of Shares		Amount			of Shares		Amount
Balance, beginning of year		4,959,937	$	12,741			4,959,937	$	84,271
Reduction of stated capital		–		–			–		(59,896	)
Issued for cash		28,461,000		105,633			–		–
Share issue costs		–		(6,826	)		–		–
Issued on debenture and warrant conversion		2,152,465		1,302			–		–
Issued for services received		148,798		90			–		–
Issued for cash on exercise of options		275,000		192			–		–
Tax benefits renounced		–		(5,271	)		–		–
Return of capital on distribution of Oncolytics shares		–		–			–		(11,646	)
Issuance of stock options for services		–		–			–		12
Balance, end of year		35,997,200	$	107,861			4,959,937	$	12,741

(c) Class A Common Shares Issued

	2003				2002
	Number				Number
	of Shares		Amount		of Shares		Amount
Balance, beginning of year		–	$	–		–	$	–
Issued on debenture and warrant conversion		3,874,437		2,343		–		–
Balance, end of year		3,874,437	$	2,343		–	$	–

(d) Contributed Surplus

	2003
Balance, beginning of year	$	–
Stock based compensation		132
Balance, end of year	$	132

(e) Issue of Debentures and Warrants

Pursuant to various financing agreements entered into April 3, 2003, the Company raised $3,645,000 through the issue of 430,493 Series A Debentures for $3,616,000, 430,493 Series A Warrants for $12,000, 2,152,465 voting preferred shares for $6,000 and 3,874,437 non-voting preferred shares for $11,000.

     Each Series A Warrant entitled the holder thereof to purchase five common shares and nine Class A common shares on the concurrent surrender of the warrant, five voting preferred shares, nine non-voting preferred shares, and one Series A Debenture. On May 29, 2003, immediately after the issue of a receipt for the prospectus offering common shares for sale

- PAGE 41 -

and issue, the Series A Warrants were exercised and the Company issued 2,152,465 common shares and 3,874,437 Class A common shares upon the surrender of the voting and non-voting preferred shares and Series A Debentures.

(f) Share Consolidation

On May 7, 2002, the shareholders of the Company approved the consolidation of the common shares on the basis of one new common share being issued for every eight previously issued and outstanding common shares. All outstanding share and option numbers reflect the one for eight consolidation. The consolidated shares began trading on May 16, 2002. Simultaneously with the share consolidation was the distribution of the 4,000,235 shares in Oncolytics to the shareholders of the Company. This distribution was accounted for as a capital transaction and accordingly, the stated capital of the common shares was reduced by $11,646,000.

(g) Reduction of Stated Capital

Pursuant to the Plan of Arrangement ratified by shareholders of the Company at the May 7, 2002 Annual and Special Meeting, the stated capital of SYNSORB shares was reduced to the net realizable value of the Company’s assets as at May 7, 2002.

(h) Flow-Through Shares

During 2003, the Company issued common shares on a flow-through basis for gross proceeds of $15,225,000 to finance certain oil and gas expenditures to be incurred in 2004. The renouncement of these expenditures was made to the purchasers of these shares effective December 31, 2003 and accordingly, share capital has been reduced by the amount of the tax benefits associated with these expenditures. The corresponding future tax liability has also been recognized in the current year.

(i) Stock Options

The Company has a stock option plan that provides for the issuance of options to its directors, officers, employees and non-employees to acquire up to 1,181,513 common shares. The dates on which options vest are set by the board of directors at the time of grant. The exercise price of an option granted is the closing price of the Company’s stock on the last trading date prior to the grant date. The dates on which options expire are also set by the board of directors at the time of grant and cannot exceed ten years. The Company has issued stock options to acquire common shares through its stock option plan of which the following are outstanding at December 31, 2003:

	2003					2002
	Number of			Weighted average		Number of			Weighted average
	options			exercise price $		options			exercise price $
Outstanding at beginning of the year		330,565			9.80		244,440			40.88
Granted		428,000			3.66		275,000			0.70
Exercised		(275,000	)		0.70		–			–
Expired		(12,500	)		87.20		(6,250	)		68.00
Forfeited		(27,064	)		52.20		(182,625	)		35.76
Outstanding at year end		444,001			4.74		330,565			9.80
Options exercisable at end of year		15,751			34.27		329,065			9.80

The following table summarizes information about the stock options outstanding at December 31, 2003:

			Weighted
	Number		average		Weighted		Number		Weighted
	outstanding		remaining		average		exercisable		average
	December 31,		contractual		exercise		December 31,		exercise
Range of exercise prices	2003		life (years)		price		2003		price
$3.00 to $4.00		365,000		4.44	$	3.57		–		–
$4.01 to $5.00		60,000		4.89	$	4.08		–		–
$5.01 to $9.00		3,000		4.67	$	5.20		–		–
$9.01 to $30.00		8,188		2.33	$	20.06		7,938	$	20.42
$30.01 to $90.00		7,813		4.30	$	48.33		7,813	$	48.33
		444,001		4.46	$	4.74		15,751	$	34.27

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     For the year ended December 31, 2003, no stock options were granted to non-employees. The Company has undertaken to facilitate the surrender of out-of-the-money options that were issued in previous years when the Company conducted pharmaceutical drug development. Subsequent to December 31, 2003, the Company granted options to purchase 64,600 common shares at a weighted average price of $5.48, which expire during the first quarter of 2009. Also subsequent to December 31, 2003, options to purchase 15,000 common shares at $3.45 were forfeited.

(j) Per Share Amounts

The weighted average number of common shares and Class A common shares outstanding during the year ended December 31, 2003 of 17,123,542 (2002: 4,959,937) were used to calculate net earnings per common share. For the year ended December 31, 2003, the exercise price of the outstanding stock options exceeded the average market price of the common shares making the options anti-dilutive. For the year ended December 31, 2002, the respective exercise price of the stock options and warrants exceeded the average market price of the common shares making the options and warrants anti-dilutive.

10. STOCK BASED COMPENSATION

Options granted after January 1, 2003 are accounted for using the fair value method. The fair value of common share options granted in 2003 is estimated to be $789,000 as at the date of grant using the Black-Scholes option pricing model and the following weighted average assumptions:

	2003
Risk-free interest rate (%)		3.79
Expected life (years)		4.00
Expected volatility (%)		54.59
Expected dividend yield (%)		0

     The estimated fair value of the options is amortized to expense over the options’ vesting period on a straight-line basis. For the year ended December 31, 2003, stock based compensation expense of $132,000 was included in general and administrative expenses.

     Had the fair value based method of accounting for stock based compensation been used for options granted in 2002, the Company’s net earnings and net earnings per share for the year ended December 31, 2002 would have been reduced to the pro forma amounts indicated below:

	2002
Net earnings
As reported	$	3,766
Pro forma	$	3,646
Basic and diluted net earnings per common share
As reported ($/share)	$	0.76
Pro forma ($/share)	$	0.74

     The pro forma amounts shown above do not include the compensation costs associated with stock options granted prior to January 1, 2002. The fair value of common share options granted in 2002 was estimated to be $120,000 as at the date of grant using the Black-Scholes option pricing model and the following assumptions:

	2002
Risk-free interest rate (%)		2.89
Expected life (years)		1.00
Expected volatility (%)		1.97
Expected dividend yield (%)		0

     All stock options issued in 2002 were exercised in 2003.

- PAGE 43 -

11. INCOME TAXES

The provision for income taxes recorded in the financial statements differs from the amount which would be obtained by applying the statutory income tax rate to the net earnings (loss) before tax as follows:

	2003			2002
Earnings (loss) before tax	$	(2,612	)	$	3,766
Statutory Canadian corporate tax rate		40.74	%		39.24	%
Anticipated tax expense (recovery)		(1,064	)		1,478
Non-deductible Crown payments		945			–
Resource allowance		(878	)		–
Recognition of loss carryforward previously unrecognized		(5,271	)		–
Effect of tax rate change		519			–
Non-taxable portion of capital gain		–			(2,536	)
Non-deductible portion of equity loss		–			92
Non-deductible expenses		–			3
Future tax assets valuation allowance		478			963
Future income tax recovery	$	(5,271	)	$	–

     Future income taxes reflect the net tax effects of temporary differences between the carrying amounts of assets and liabilities for financial reporting purposes and the amounts used for income tax purposes. The components of the Company’s future income tax assets and liabilities are as follows:

	2003			2002
Future tax liabilities
Net book value of capital assets in excess of tax pools	$	(10,726	)	$	–
Future tax assets
Tax pools in excess of net book value of capital assets		–			6,422
Non-capital loss carryforwards		6,243			11,984
Scientific research and development pools		7,784			7,896
Share issue costs		2,006			400
Attributed Canadian royalty income		268			–
Asset retirement obligation		1,212			–
Net future tax assets		6,787			26,702
Valuation allowance		(6,787	)		(26,702	)
Net future taxes	$	–		$	–

     The Company has non-capital losses for income tax purposes of approximately $18,035,000 which are available for application against future taxable income and which expire in the following years:

2006	$	1,448
2007		5,103
2008		11,484
	$	18,035

     The income tax benefit of these losses has not been recognized in the financial statements, as reflected in the valuation allowance. The Company also has approximately $5,700,000 of unclaimed investment tax credits available to reduce future years’ income taxes payable.

- PAGE 44 -

12. RELATED PARTY TRANSACTIONS

A director of the Company is a partner of a law firm that was paid $2,150,000 for legal services for the period from the date elected as a director, April 3, 2003, to December 31, 2003. The fees charged were based on standard rates and time spent on company matters.

13. FINANCIAL INSTRUMENTS

(a) Fair Value

The Company has financial instruments consisting of accounts receivable, investments, accounts payable and bank loans. The carrying value of these instruments approximates fair value unless otherwise stated.

     Pursuant to the exercise of the option to purchase the W4M Properties (Note 4), the Company acquired an interest in forward sales contracts and financial hedging contracts with respect to production from the purchased properties as follows:

Transaction Type	Volume (GJ/D)			Contract Price (GJ/D)			Expiry
Costless Collar		4,830			$6.36 – $7.15		March 31, 2004
Fixed		1,610			$6.76		March 31, 2004
Cogeneration Fuel Supply		263			$1.959 – $2.217		October 31, 2008
Daily Declining Profile		841	(1)		Netback	(2)	October 31, 2011
Reserve Based		101			Netback	(3)	Life of reserves

     Based on dealer quotes, had these contracts been closed on December 31, 2003, a loss of $1,467,000 would have been realized.

Notes:

⁽¹⁾ The Company’s obligations under this contract will, on November 1 of each succeeding year, decline to the following:

Date	Obligation (GJ/D)
November 1, 2004		724
November 1, 2005		623
November 1, 2006 and thereafter		568

⁽²⁾ TransCanada Pipelines Limited netback pricing.

⁽³⁾ Progas Limited netback pricing.

     The following financial hedging contracts were entered into subsequent to December 31, 2003:

Transaction Type	Volume (GJ/D)		AECO Price (GJ/D)		Term
Collar		5,000	$	5.50 – $6.35	April 1, 2004 to October 31, 2004
Collar		8,000	$	5.50 – $6.40	April 1, 2004 to October 31, 2004
Collar		5,000	$	5.50 – $6.36	April 1, 2004 to October 31, 2004
Fixed Price Swap		5,000		$5.745	April 1, 2004 to June 30, 2004
Fixed Price Swap		5,000		$5.745	August 1, 2004 to October 31, 2004
Fixed Price Swap		5,000		$5.7725	April 1, 2004 to October 31, 2004

(b) Credit Risk

A substantial portion of the Company’s accounts receivable are with entities in the oil and gas industry. The Company generally extends unsecured credit to these companies, and therefore, the collection of accounts receivable may be affected by changes in economic or other conditions and may accordingly impact the Company’s overall credit risk. Management believes the risk is mitigated by the size, reputation and diversified nature of the companies to which they extend credit. The Company has not previously experienced any material credit losses on the collection of receivables.

- PAGE 45 -

(c) Interest Rate Risk

The Company is exposed to interest rate risk in relation to interest expense on its revolving credit facility and non-revolving bridge facility.

14. SUPPLEMENTAL DISCLOSURE OF CASH FLOW INFORMATION

     Changes in non-cash working capital were comprised of the following:

	2003			2002
Accounts receivable	$	(11,550	)	$	35
Prepaids and other current assets		(1,669	)		(23	)
Investments		(2,500	)		–
Accounts payable and accrued liabilities		23,670			(4,791	)
Less working capital deficiency on acquisitions		(1,513	)		–
Net change	$	6,438		$	(4,779	)
Net change by activity:
Operating	$	5,660		$	(4,779	)
Investing		806			–
Financing		(28	)		–
Net change	$	6,438		$	(4,779	)

     Additional information:

	2003		2002
Cash interest paid		495		71
Cash taxes paid		–		10

15. CONTINGENCIES

The Company, in the normal course of operations, is subject to a variety of legal and other claims against the Company. Management and the Company’s legal counsel evaluate all claims on their apparent merits, and accrue management’s best estimate of the likely costs to satisfy such claims. Management believes that the outcome of legal and other claims filed against the Company will not have a significant impact on the Company’s financial position, operations or cash flows.

     The Company indemnifies its directors and officers against any and all claims or losses reasonably incurred in the performance of their service to the Company to the extent permitted by law. The Company has acquired and maintains liability insurance for its directors and officers.

16. COMMITMENTS

The Company has committed to purchase seismic data in the amount $225,000 during the first six months of 2004.

     The Company is committed to payments under operating leases for office space as follows:

2004	$	611
2005		718
2006		413
2007		385
2008		385
	$	2,512

17. SUBSEQUENT EVENTS

On March 17, 2004, the Company acquired 100 percent of the shares of Zorin Exploration Ltd. for aggregate consideration of $7.4 million, comprising $1.5 million of cash and $5.9 million of equity representing 1,150,000 common shares.

- PAGE 46 -

EX-4

Exhibit 4

THE EVOLUTION
OF A
MODERN ENERGY
COMPANY

Hawker Resources Inc.

Hawker, a new company initially formed from a failed public biotech company and through a series of complex transactions, is positioned with a substantial operating land base, producing wells and significant infrastructure in the east central area of Alberta, and more recently, in northeast British Columbia. The Company has developed positive tax attributes which give it a competitive advantage, and attracted an experienced management team with which to pursue an active acquisition program, to complement its exploration and development activities. Hawker began operating as an exploration and production company on June 30, 2003.

TABLE OF CONTENTS

PAGE FIVE

PAGE SIX

PAGE EIGHT

PAGE TWELVE

PAGE SEVENTEEN

PAGE NINETEEN

PAGE TWENTY FOUR

PAGE TWENTY FIVE

PAGE THIRTY ONE

PAGE THIRTY TWO

PAGE THIRTY FIVE

IBC

ASSEMBLE EXPERT
MANAGEMENT TEAM

Mergers and acquisitions of oil and gas companies, big and small, have re-invented the junior energy sector. Management teams from other organizations of various sizes have joined together to bring strong managerial experience to lead emerging junior companies. Each team has developed its own strategy and vision – some based on a longer-term view, while others, who thrive on building up a company then starting again, may look to the shorter-term. Both are strategies that require tremendous leadership strength and execution expertise.

- PAGE 1 -

DEVELOP
GROWTH STRATEGY

By learning through past experiences, management of these new emerging energy producers have developed strategies for profitable growth, with the ability to apply their previous successes to new and promising exploration, exploitation and acquisition ventures.

- PAGE 2 -

GATHER
FINANCIAL SUPPORT

Having developed a reputation for successful leadership and a proven ability to execute a strategic plan, these emerging organizations are able to tap into strong financial resources from both private and public investment sources.

- PAGE 3 -

ACQUIRE
ASSET BASE

Unlike larger organizations gradually developing a strong asset position, the new juniors are staking their claims more rapidly. In recent months, acquisition activity in this sector of the oil and gas industry has been dramatic, demonstrating the focus of this new group of companies on accelerating the growth of production and shareholder value.

- PAGE 4 -

Building Hawker

- PAGE 5 -

Financial and Operational Highlights

- PAGE 6 -

AS AT DECEMBER 31	2003
(in thousands of dollars, except per share amounts)
FINANCIAL
Production revenue	$	17,582
Cash flow from operations	$	5,985
Per share, diluted	$	0.35
Net earnings	$	2,314
Per share, diluted	$	0.14
Shareholders’ equity	$	103,457
Total assets	$	185,102
Long-term debt	$	44,149
Capital expenditures, including acquisitions	$	154,567
Common and Class A shares outstanding at year-end
Basic		39,871,637
Diluted		40,315,638
OPERATIONS
Average daily production (mmcf/d) (100% natural gas)		16,346	*
Proved plus probable reserves
Crude oil and natural gas liquids (mmbbl)		492
Natural gas (mmcf)		50,619
Total proved plus probable reserves (mboe)		8,929
Land holdings
Undeveloped net acres		184,929

* Average daily production has been calculated from the commencement of operations, July 1, 2003. The production in 2003 does not include the Pointwest properties.

DIVERSIFIED AND
WELL FINANCED

Hawker has made significant progress in its first year of operation. It has developed an oil and gas asset base which extends from northeast British Columbia south east to the Alberta prairies. The Company has raised over $100 million in new equity from a diverse group of shareholders and secured a $54 million line of credit with a major Canadian bank. It has put that equity to work and created an enterprise value of close to $265 million by the end of the year.

- PAGE 7 -

President’s Message

ALL THINGS ARE FILLED FULL
OF SIGNS AND IT IS A WISE
MAN WHO CAN LEARN ABOUT
ONE THING FROM ANOTHER.

Plotinus, 250 AD

Ours is a very dynamic industry. No two years are the same, just as no two companies can be replicas of each other. The people and companies that strive to succeed in our industry are faced with constantly shifting fundamentals, starting with the prices we receive for our production, through to the costs we pay for the input costs of doing business. This constantly shifting environment can be both a challenge and an opportunity. The opportunities are particularly apparent, in my opinion, when a company can bring together an experienced management team that has seen the ups and downs, the challenges and the outcomes that our industry offers.

     Hawker is a company that has the benefit of an experienced management team that is acutely aware of both the opportunities and challenges presented by the current industry fundamentals. The genesis of Hawker was in January 2003 when a group of us recapitalized a failed publicly traded company with significant tax attributes. Our strategy was to build a company that from the outset had the competitive advantage derived from tax attributes combined with an experienced team of professionals. The subsequent acquisition of Southward Energy Ltd. gave us an initial land and production platform and provided Hawker the momentum to add to our technical team, and the resources to take advantage

- PAGE 8 -

of other opportunities such as Pointwest, and more recently Zorin.

     The Hawker strategy of using the advantage generated through our tax attributes and the skills of an experienced management and technical team to rapidly build an asset base is working. The other more important leg of our strategy is to use our base of assets to create and support an exploration and exploitation program capable of meaningful production growth through the drill bit, and to create value in the assets we acquired. We were fortunate in being able to attract a team with the strong credentials and similarity in values that would form the foundation of the Hawker team.

     In order to carry out our strategy we focused on a series of acquisitions of companies and properties that were targeted to meet certain specific criteria. We focused on natural gas opportunities as we felt that commodity has very clear fundamentals underpinning a strong long-term price, driven by the North American economy. The combination of strong demand factors and the increasingly elusive supply in North America reinforced our views, but also adds to the competitive nature of natural gas acquisition targets.

     At this early stage of our evolution, we wanted to maintain a balanced portfolio of risk that would allow us to allocate some 90 percent of our capital to low and medium risk projects, and up to 10 percent to high risk prospects. Over time we can increase the higher risk component of our capital program, but as a small emerging company we now need to be able to grow production in a predictable manner through a disciplined low/medium-risk drilling program.

     Because we were confident that our strategy would prove successful, we also wanted to limit the number of new shares we added to our capital structure to pay for our acquisitions. We believe that we can add value to acquired assets through our operational and exploration capability. The value we create will result in an appreciating share price for our shareholders, and will ultimately result in fewer shares being needed to raise similar amounts of capital. To contain or limit the amount of equity we issue today, we decided to keep debt as a percentage of cash flow or equity at a reasonable high level.

     From June 2003 to January 2004 the Hawker team has executed two major acquisitions and is in the midst of a third. We spent $154 million or an average of $26,600 per flowing barrel of oil equivalent. The sequence of planning, acquisition and operation was completed smoothly and, while we are still in the assimilation phase of our latest acquisition, which will be effective in March 2004, we are extremely pleased with the program and the results.

- PAGE 9 -

PRESIDENT’S MESSAGE

     Hawker today has a significant land base stretching from southern Alberta to northeast British Columbia and following some of the major natural gas trends in the basin. From a standing start with no production and no prospects, we ended 2003 with production of over 5,800 barrels of oil equivalent per day and an undeveloped land base totaling some 185,000 net undeveloped acres. Our geotechnical team has identified a multi-year inventory of opportunities and drilling prospects on these lands. In 2004 we expect to spend approximately $56 million on this asset base and expect to drill over 100 wells within our planned capital program. While we have not allocated a specific capital budget to acquisitions, we will continue to pursue opportunities that meet our criteria.

     I look forward to 2004 as a year in which we can demonstrate our ability to profitably exploit our existing assets, to showcase the strong foundation that has been developed through our acquisition strategy and to continue our growth with both organic operations and further opportunistic acquisitions. Our rate of growth has been substantial and we now need to demonstrate what this asset base is capable of, in terms of production and further potential. We need, in other words, to let our shareholders and investors catch up with what we have become and what we are capable of becoming.

     The evolution of Hawker has been rapid, but is not unique. In my experience, few companies have grown from essentially zero to an enterprise value of close to $265 million in only eight months, yet the success is not ours alone. We are one of a group of new, emerging energy companies that over the recent past have followed a similar path. We intend to continue to chart a course of profitable growth, with the goal of building a vibrant, healthy, profitable and successful organization where our employees have fun while they join with our shareholders in the financial rewards of our success.

On behalf of the Board of Directors,

DAVID TUER
President and Chief Executive Officer
March 17, 2004

- PAGE 10 -

TERRY SCHMIDTKE	DAVID TUER	BARRY HERRING
Chief Operating Officer	President and Chief Executive Officer	Chief Financial Officer
Mr. Schmidtke has more than 24 years of experience in the Canadian oil patch, most recently as a senior executive with EnCana Resources. Before this, he held key operating roles with PanCanadian Energy Corporation, where he led the development of its shallow gas program, growing total gas production to more than one billion cubic feet of natural gas per day.	Mr. Tuer is former President and CEO of PanCanadian Energy Corporation. Currently he is Chairman of the Boards of the Calgary Health Region, AltaLink Management Ltd. and Mount Royal College, and serves on the Board of Directors for Canadian Natural Resources Limited and Rockwater Capital Corporation. Mr. Tuer has served as Alberta’s Assistant Deputy Minister of Energy.	Mr. Herring is a Chartered Accountant and brings 22 years of accounting and oil and gas experience to Hawker. He has held senior finance positions at UMC Resources, Ocean Energy and Calpine Canada. Most recently, he was Chief Financial Officer with Southward Energy Ltd.

Operations Review

HAWKER BECAME AN
OPERATING OIL AND GAS
COMPANY ON JUNE 30, 2003.

Hawker became an operating oil and gas company on June 30, 2003 when it completed the acquisition of producing natural gas properties in the Lavoy and Cold Lake areas of central Alberta. These two areas dominated Hawker’s engineering and production activity in 2003, while exploration activity focused on identifying and proving the potential of future properties. Land was acquired for exploration in several Alberta locations, namely Chigwell, Purple Springs, Wild River and Gold Creek.

     On December 30, 2003, Hawker finalized the acquisition of Pointwest Energy, a private exploration and production company also based in Calgary, Alberta. Pointwest was identified as an attractive acquisition target for its high quality land base, extensive seismic coverage as well as underutilized infrastructure. This transaction makes Hawker operator of two additional properties: North Boundary and Valhalla. North Boundary is a natural gas property located in northeast British Columbia. Valhalla, located in northwest Alberta, is also a high quality natural gas property in an area dominated by several large industry players.

     The table below identifies the key assets acquired through the Pointwest Energy acquisition:

			North
	Total		Boundary		Valhalla
Proved reserves acquired (mboe)		3,572		2,777		332
Net undeveloped land (thousands of acres)		27		26		1
Seismic acquired 2D (km)		363		295		0
Seismic acquired 3D (km2)		144		40		93

- PAGE 12 -

LAVOY

The Lavoy area is located approximately 100 kilometres east of Edmonton in a well-developed natural gas-prone portion of the Western Canada Sedimentary Basin. Hawker does not operate the property, but Hawker owns a 45 percent average working interest in this property’s land, facilities and production which from July 1 to December 31, 2003 averaged 14.4 million cubic feet per day (mmcf/d). Hawker has ownership of a large undeveloped land base totaling approximately 142,000 net acres. Geologically, the property is characterized by 14 multi-stacked prospective horizons where hydrocarbons have been proven to exist. Hawker also has a working interest position in 10 processing facilities in the area with gross cumulative capacity of 40 mmcf/d.

     In 2003, Hawker increased its net land position at Lavoy by purchasing approximately 3,500 net undeveloped acres through Crown land sales. During the year, Hawker participated in the drilling of 31 wells of which 23 were cased. Twelve of these wells have been connected to facilities in December 2003 with initial production expected in the first part of 2004.

Lavoy

     Hawker and its partner negotiated a farm–in on additional lands with a major operator in the Lavoy region. Drilling success on these lands will increase Hawker’s land position in 2004.

     With a large undeveloped land base, geologically multi-stacked prospective horizons, access to processing facilities and compression, Lavoy is Hawker’s largest core area and one where the Company intends to grow its base production and expand operations.

COLD LAKE/BONNYVILLE

The Cold Lake/Bonnyville property is located approximately 80 kilometres south of the Cold Lake Air Weapons Range in north central Alberta. It falls outside of the restrictive gas over bitumen area ordered by the Alberta Energy Utilities Board (EUB). While drilling operations have not been affected by the order, tie-in and production delays have been experienced.

     Hawker assumed operatorship of this property in September 2003 and operates an average of 8 mmcf/d of natural gas production. Net production in 2003 was

- PAGE 13 -

OPERATIONS REVIEW

Cold Lake/Bonnyville

2 mmcf/d which reflects Hawker’s average 25 percent working interest in Cold Lake/Bonnyville. Hawker has a solid land position in the area totaling some 12,840 net acres including 4,320 undeveloped net acres. The property consists of 29 well sites and one production facility. Similar to the Lavoy area, Cold Lake’s geology is multi-stacked with five prospective hydrocarbon-bearing horizons.

     Two natural gas wells were drilled and connected to processing facilities in late 2003. The wells will begin producing in the first half of 2004 after receiving regulatory approval. Since assuming operatorship, Hawker spent the remainder of 2003 reviewing all aspects of this area in detail: facility capacity, geologic potential, mineral rights availability, as well as possible competition from third-party operators. Hawker is encouraged by the gas exploitation upside of the Cold Lake/Bonnyville area and its contribution to the Company’s future growth.

NORTH BOUNDARY

The North Boundary project is located 55 kilometres northeast of Fort St. John in British Columbia. Hawker acquired this property through its acquisition of Pointwest Energy on December 30, 2003. The assets in this region fit well within Hawker’s identified area of interest. The development of the project is in its infancy and it offers Hawker a base for future low-risk expansion as well as exploration potential. The Company will be focused on exploiting production from this core region for the next several years. Hawker has an average 85 percent working interest in the 42,000-acre land block, which comprises 25,993 net acres of undeveloped land. Production at year-end was approximately 3,100 barrels of oil equivalent per day (boe/d), comprising 17 mmcf/d of natural gas and 240 barrels per day of oil and natural gas liquids. Hawker operates 22 natural gas producing wells, and has a 100 percent working interest in the North Boundary gas processing facility, which has a capacity of 28 mmcf/d of sour gas, 6 mmcf/d of sweet gas and 600 barrels per day of oil and natural gas liquids. At North Boundary, hydrocarbons are produced from eight prospective horizons to a depth of approximately 1,300 metres.

North Boundary

- PAGE 14 -

OPERATIONS REVIEW

     As of year-end, more than 25 prospective locations for exploration or development drilling were identified. With current 3D seismic coverage over the majority of the property, and more seismic to be added in 2004, Hawker expects to expand its presence and production in the area. Hawker believes North Boundary will be a key asset in fuelling the Company’s growth in 2004.

VALHALLA

The Valhalla property is located 160 kilometres northwest of Grande Prairie, in north central Alberta. Its multiple cretaceous, geological targets are found at a depth of approximately 1,800 metres. Hawker currently has a working interest in 1,940 gross acres with a rolling option farm-in on an additional 4,160 gross acres granted by a major resource company.

     Three producing wells have been drilled on Hawker’s acreage. The wells have been connected to third party processing facilities in the area. Production at year-end was 220 barrels per day, comprising 1 mmcf/d of natural gas and 55 barrels per day of oil and natural gas liquids. Two standing wells which have been drilled but are not yet tied into pipelines are expected to be brought on production in 2004. Several re-completion opportunities have also been identified and will be started in 2004.

     The surrounding area is dominated by several large oil and gas companies, and offers Hawker limited opportunities for growth beyond 2004. As a result the Company will evaluate future plans for this property, including a possible exchange or sale.

CHIGWELL

Chigwell is a grassroots exploration prospect that was developed by Hawker in the second half of 2003. Hawker has reviewed more than 100 existing well data sets to identify the Chigwell opportunity. Hawker acquired its land position at Chigwell in the third quarter of 2003, with two exploration wells subsequently drilled and cased. Both of these wells tested at commercial flow rates of natural gas from the Basal Quartz/Ellerslie horizon.

     This area is well developed in terms of infrastructure, and Hawker has initiated discussions with third party facility operators regarding access to available processing and gathering capacity. Hawker plans to drill two follow-up well locations in early 2004 in conjunction with additional land and seismic data acquisitions.

     The Chigwell area is viewed as an emerging focus area for Hawker. The project exemplifies Hawker’s ability to identify drilling opportunities and exploit them quickly.

Chigwell

- PAGE 15 -

OPERATIONS REVIEW

Purple Springs

PURPLE SPRINGS

At Purple Springs in southern Alberta, Hawker farmed-in on 6,400 gross acres of land where the Company plans to drill and tie in 15 wells to earn a 50 percent working interest position. The program will capitalize on Hawker’s significant technical experience in developing shallow Medicine Hat gas sands throughout southern Alberta. Future opportunities for the block and offsetting lands involve infill drilling, and gathering and processing of third party natural gas through the facilities Hawker will develop in this area. Exploration prospects for deeper targets in the Viking, Sunburst, and Sawtooth formations may be evaluated as part of the 2004 drilling program.

WILD RIVER PROSPECT

The Wild River prospect is non-operated and constitutes a significant part of Hawker’s 2004 high risk exploration portfolio. Hawker has a 20 percent working interest in five sections of land as well as the associated seismic coverage. The Wild River prospect is a Nisku pinnacle reef on trend with existing pinnacle reef production to the south. The feature was identified by seismic reprocessing and as mapped could have significant gas-in-place relative to the analogous pinnacles in the area. The well located at 8-14-57-23 W5M was spudded in December and at year-end was drilling forward. Subsequent to year-end the well was cased and is currently being evaluated by Hawker and its partners.

OTHER

In conjunction with Hawker’s acquisition of Southward Energy on April 30, 2003, the Company acquired access to a large seismic database covering northeast British Columbia and extending southeast to the southern Alberta prairies. The database included some 1,250 km of 2D seismic data and 2,750 square km of 3D seismic information. Hawker’s exploration team has extensively reviewed and re-processed certain data to develop an inventory of potential exploration prospects. Land acquisition strategies have been developed for these prospects and in some cases land has been acquired. Hawker expects to drill two of these prospects in early 2004, and will continue evaluation and land acquisition of the others.

     In addition to North Boundary and Valhalla, 10 minor properties were acquired as part of the Pointwest acquisition. The properties are all non-operated with an average working interest of 30 percent. Production at year-end from the combined properties was 1.8 mmcf/d of natural gas and 22 barrels per day of oil and liquids. Subsequent to year-end and following an evaluation of the properties’ exploitation potential, the Company reached an agreement to sell these properties with the closing expected at the end of the first quarter.

- PAGE 16 -

Reserves

RESERVES AND RESERVE REPLACEMENTS

Hawker retains independent petroleum engineering consultants, McDaniel & Associates Consultants Ltd. (McDaniel) and Gilbert Laustsen Jung Associates Ltd. (GLJ), to evaluate the Company’s proved and probable oil and natural gas reserves and prepare the Evaluation Reports on the Company’s total reserves. For the year ended December 31, 2003, the independent evaluators’ reports incorporated 100 percent of the Company’s reserve value. The Board of Directors of the Company has an independent Reserves Committee, which met with the evaluators to carry out independent due diligence procedures as to the Company’s reserves.

     During 2003, Hawker established a proved plus probable reserve base that equals approximately 4.4 years of equivalent production (includes the 2003 Pointwest acquisition). Proved reserves represent 77 percent of the Company’s total proved plus probable reserves.

     The Company’s strategy of exploitation coupled with exploration and opportunistic acquisitions is a proven successful model, and should result in an increase in reserves per common share on an annual basis.

     In their evaluation, the evaluators booked two percent of the Company’s proved barrels of oil equivalent as proved undeveloped. The evaluators assigned 12.1 percent of Hawker’s proved crude oil and NGL reserves as proved undeveloped. The evaluators assigned two percent of the Company’s proved natural gas reserves as proved undeveloped, of which a portion is associated with secondary natural gas.

RESERVES BEFORE ROYALTIES*

	Proved		Proved Non-		Proved		Proved
DECEMBER 31, 2003	Producing		Producing		Undeveloped		Total		Probable		Total
Light/medium oil (mbbls)		164.5		13.3		42.5		220.3		69.6		289.9
Natural gas (mmcf)		30,947.4		7,249.2		885.7		39,082.3		11,536.3		50,618.6
Natural gas liquids (mbbls)		135.0		23.4		3.5		161.9		40.4		202.3
Total reserves (mboe)		5,457.4		1,244.9		193.6		6,895.9		2,032.7		8,928.6
Present value of reserves ($ millions)
10% discount		86,945.4		19,352.8		1,261.1		107,559.2		21,737.1		129,296.4
15% discount		79,218.7		17,816.1		997.8		98,031.6		17,971.4		116,004.0

Barrels of oil equivalent are converted from natural gas at a 6:1 conversion ratio

* excludes abandonment costs; based on forecast prices

- PAGE 17 -

- PAGE 18 -

Corporate Governance

THE BOARD IS RESPONSIBLE
FOR APPOINTING AND
MONITORING THE COMPANY’S
SENIOR OFFICERS.

Hawker Resources Inc.’s Board of Directors is responsible for establishing the Company’s general strategic direction and overseeing management’s business conduct. The Board of Directors, management and employees work together to meet corporate goals and foster a culture of integrity throughout the Company.

     The Board is responsible for appointing and monitoring the Company’s senior officers. The Board also participates in strategic planning by actively reviewing the plans developed and proposed by senior management. Included in this analysis is the consideration and management of the principal risks associated with the Company’s business. The Board reviews the Company’s communications with the public as well as the integrity of the Company’s internal control and management information systems.

     To ensure proper governance of the Company and supervision of management, the Board has appointed the Audit Committee, the Reserves Committee, the Compensation Committee and the Governance Committee. Acting directly and through these committees the Board is responsible for the overall stewardship of the Company.

     The Board currently has six Directors, five of which are “unrelated”, non-executive Directors, and one related, executive Director, David Tuer, who is a member of management.

     The Company’s Board of Directors continually evaluates the corporate governance policies and procedures of the Company. Regulatory changes that have occurred as a result of the enactment of the Sarbanes-Oxley Act 2002, proposed listing standards of the New York Stock Exchange and proposed changes to the TSX Corporate Governance Guidelines are continually monitored by the Company’s Board of Directors and the Board will take appropriate action as regulatory changes occur. In the following table, the Company’s corporate governance procedures are compared with the current TSX guidelines on corporate governance.

- PAGE 19 -

CORPORATE GOVERNANCE

			HAWKER
TSX GUIDELINE			ALIGNMENT	COMMENTARY
1.	The board of directors of every corporation should explicitly assume responsibility for the stewardship of the corporation and, as part of the overall stewardship responsibility, should assume responsibility for the following matters:		YES	The Board of Directors acknowledges its responsibility for the stewardship of the Company in overseeing the business and affairs of the Company. In particular, the Board:
	(a)	adoption of a strategic planning process;	YES	(a)	ensures the Company has appropriate short and long-term goals and has implemented a strategic planning process;
	(b)	the identification of the principal risks of the corporation’s business and ensuring the implementation of appropriate systems to manage these risks;	YES	(b)	identifies the principal business risks and ensures proper systems are in place to manage these risks and protect shareholder value;
	(c)	succession planning, including appointing, training and monitoring senior management;	YES	(c)	ensures that senior management is of the highest caliber and that adequate systems are in place for the appointment, development and monitoring of senior management to facilitate the orderly succession of senior management;
	(d)	a communication policy for the corporation;	YES	(d)	ensures the Company’s communication policy enables it to effectively communicate with shareholders, other stakeholders and the public generally, including the capital markets;
	(e)	the integrity of the corporation’s internal control and management information systems.	YES	(e)	ensures the Company has in place adequate internal controls and management information systems.
2.	The board of directors of every corporation should be constituted with a majority of individuals who qualify as unrelated directors as defined by the TSX.		YES	The Board of Directors is comprised of six members, all of whom have extensive and varied business experience. The majority of the Directors are non-management “unrelated Directors”, as defined in the Report of The Toronto Stock Exchange Committee on Corporate Governance in Canada. The Company does not have a significant shareholder with the ability to exercise a majority of the votes for the election of Directors.

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CORPORATE GOVERNANCE

		HAWKER
TSX GUIDELINE		ALIGNMENT	COMMENTARY
3.	The application of the definition of “unrelated director” to each director should be the responsibility of the board and the analysis of the application of the principles supporting the conclusions of the Board should be disclosed on an annual basis.	YES	All of the members of the Board of Directors of the Company are non-management, “unrelated directors” with the exception of Mr. D.A. Tuer, President and Chief Executive Officer. All other members of the Board of Directors are free from any interest and any business or other relationship that could reasonably be perceived to materially interfere with the Director’s ability to act with a view to the best interests of the Company.
4.	The board of directors of every corporation should appoint a committee of directors composed exclusively of outside, i.e., non-management directors, a majority of whom are unrelated directors, with the responsibility of proposing to the full board new nominees to the board and for assessing directors on an ongoing basis.	YES	The Board created the Corporate Governance Committee comprised exclusively of non- management, “unrelated directors” who are Messrs. R.P. Mathison and M.A. Lambert, which is responsible for the identification and recommendation to the Board of individuals qualified to become Board members and for the ongoing assessment of Directors.
5.	Every board of directors should implement a process to be carried out by the nominating committee or other appropriate committee for assessing the effectiveness of the board as a whole, the committees of the board and the contribution of individual directors.	YES	The Corporate Governance Committee is responsible for assessing the effectiveness of the Board as a whole, the Committees of the Board and the contribution of individual Directors. The assessment is ongoing and includes an annual questionnaire that each Director must complete. The Committee reviews the submitted questionnaires and the results constitute part of the report to the full Board.
6.	Every corporation, as an integral element of the process for appointing new directors, should provide an orientation and education program for new recruits to the board.	YES	The Company has an informal orientation and education program, which allows unrestricted direct access by any Board member to any member of senior management and their staff.
7.	Every board of directors should examine its size and with a view to determining the impact of the number upon effectiveness, undertake where appropriate, a program to reduce the number of directors to a number, which facilitates more effective decision-making.	YES	The Company’s Articles of Incorporation restrict the size of the Board to a maximum of 11 members. The Board continually monitors its decision-making effectiveness and where appropriate will make the necessary changes to establish a board size to facilitate effective decision-making.

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CORPORATE GOVERNANCE

		HAWKER
TSX GUIDELINE		ALIGNMENT	COMMENTARY
8.	The board of directors should review the adequacy and form of the compensation of directors and ensure compensation realistically reflects the responsibilities and risk involved in being an effective director.	YES	The Compensation Committee comprising Messrs. K.T. Smith and M.A. Lambert, reviews the adequacy and structure of Directors’ compensation and makes recommendations designed to ensure the Directors’ compensation realistically reflects the responsibilities of the Board of Directors. The Compensation Committee is presently reviewing Directors’ compensation levels with a view to making appropriate adjustments to Directors’ compensation for the 2004 year to reflect the increased governance responsibilities being placed on the Directors by the Company.
9.	Committees of the board of directors should generally be composed of outside directors, a majority of whom are unrelated directors, although some board committees, such as the executive committee, may include one or more inside directors.	YES	The Board has established four committees: (i) the Audit Committee; as described in paragraph 13, (ii) the Compensation Committee as described in paragraph 8; (iii) the Corporate Governance Committee as described in paragraphs 4, 5 and 10; and, (iv) the Reserves Committee comprising a majority of non-management, “unrelated Directors” who are Messrs. R.P. Mathison, S.G.P. Grad and K.T. Smith. The Reserves Committee communicates directly with the Company’s external independent engineering firm to review the qualifications of and procedures used by the independent engineers in determining the estimate of the Company’s quantities and value of petroleum and natural gas reserves remaining.
10.	Every board of directors should expressly assume responsibility for, or assign to a committee of directors the general responsibility for, developing the corporation’s approach to governance issues. This committee would, amongst other things, be responsible for the corporation’s response to these governance guidelines.	YES	The Corporate Governance Committee is expressly charged with the responsibility for developing the Company’s approach to governance issues and is responsible for the Company’s response to these governance guidelines.
11.	The board of directors, together with the CEO, should develop position descriptions for the board and for the CEO, including the definition of the limits to management’s responsibilities. In addition, the board should approve or develop the corporate objectives, which the CEO is responsible for meeting.	YES	The Corporate Governance Committee is preparing the Company’s corporate governance guidelines for consideration by the full Board. The Board is responsible for the stewardship of the Company. Any responsibility that is not delegated to senior management or a Board committee remains with the full Board. In addition, the Board in conjunction with senior management determines the limits of management’s responsibilities and establishes annual corporate objectives which management is responsible for meeting.

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CORPORATE GOVERNANCE

		HAWKER
TSX GUIDELINE		ALIGNMENT	COMMENTARY
12.	Every board of directors should have in place appropriate structures and procedures to ensure that the board can function independently of management.	YES	The Board of Directors functions independently of management and appoints the Chairman. At least once during each year, immediately following the termination of a regularly scheduled Board meeting, the non-management, “unrelated Directors” meet in executive session without the presence of management to discuss whatever topics are appropriate. These meetings are chaired by the Chairman of the Corporate Governance Committee. Additional executive sessions may be scheduled from time to time as determined by a majority of the non-management “unrelated Directors” in consultation with the Chairman of the Board and Chairman of the Corporate Governance Committee.
13.	The audit committee of every board of directors should be composed only of outside directors. The roles and responsibilities of the audit committee should be specifically defined so as to provide appropriate guidance to audit committee members as to their duties. The audit committee should have direct communication channels with the internal and external auditors to discuss and review specific issues as appropriate. The audit committee duties should include oversight responsibility for management reporting on internal control.	YES	The Board created the Audit Committee comprised of Messrs. B.J. Kenway, R.P. Mathison and M.A. Lambert who are all non-management, “unrelated Directors”. The Audit Committee is responsible for selecting and recommending the appointment of the Company’s independent auditors by the shareholders, pre-approving all audit and non-audit services to be provided to the Company and establishing the fees to be paid to the independent auditors. The Committee meets directly with the Company’s independent auditors both with management and independent of management and is responsible for monitoring the preparation and audit of the Company’s financial statements and the establishment of appropriate internal controls. In addition the Committee provides an avenue for communication between each of the independent auditors, financial and senior management and the Board.
14.	The board of directors should implement a system, which enables an individual director to engage an outside adviser at the expense of the company in appropriate circumstances. The engagement of the outside advisor should be subject to the approval of an appropriate committee of the board.	YES	The full Board or any member of the Board can engage outside advisors at the expense of the Company in appropriate circumstances.

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Health, Safety and Environment

HAWKER LOOKS FOR
OPPORTUNITIES TO
WORK TOGETHER
WITH COMMUNITY AND
INDUSTRY GROUPS.

Hawker believes that ethical, socially-responsible operations and environmental stewardship are integral to long-term success. Hawker complies with or exceeds all regulatory standards and guidelines and operates within its licenses and regulatory approvals. In 2003, Hawker implemented a Health, Safety and Environment (HS&E) process to monitor and steward its related programs. This process is based on industry best practices, and was developed based on the Company’s management team’s extensive experience in the energy sector.

     Furthermore, Hawker completes internal safety and compliance audits of its facilities and well sites on a regular basis. All new production facilities that were acquired in 2003 were audited to ensure they will provide safe and healthy working environments for Hawker’s employees and contract staff. These accomplishments provide an excellent foundation for continuous improvement in health, safety, environment and community performance.

     Hawker takes a proactive approach to its work in order to reduce its environmental footprint. Protecting the environment is a fundamental value in the Company. Accordingly, Hawker looks for opportunities to work together with community and industry groups to create a better, sustainable energy industry. In its first year of operations, Hawker was recognized for its contributions to effective environmental, health and safety stewardship with the Canadian Association of Petroleum Producers (CAPP) Bronze Level.

BUILDING POSITIVE COMMUNITY RELATIONSHIPS

Hawker works cooperatively with the communities in which it operates by interacting on a regular basis with stakeholder groups and individuals, government agencies and industry committees. Hawker believes that these relationships are crucial to the Company’s success and as it grows, will continuously focus on making local residents and stakeholder groups aware of its activities through open communication.

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Exhibit 2

Management’s Discussion and Analysis

Management’s discussion and analysis of the financial and operating results for the Company should be read in conjunction with the Company’s audited financial statements and related notes for the years ended December 31, 2003 and 2002. This discussion contains forward-looking statements that are not historical in nature and involves risks and uncertainties. Forward-looking statements are not guarantees as to the Company’s future results since there are inherent difficulties in predicting future results. Accordingly, actual results could differ materially from those expressed or implied in the forward-looking statements.

     At the Annual and Special Meeting of SYNSORB Biotech Inc. (“SYNSORB”) shareholders held April 3, 2003, shareholders approved the planned conversion of the company into an oil and gas enterprise and changed the company’s name to Hawker Resources Inc. (“Hawker” or “the Company”). Prior to 2002, SYNSORB conducted pharmaceutical drug research and development. On December 10, 2001 SYNSORB terminated its drug development activities.

     On June 30, 2003, the conversion of the Company to an oil and gas enterprise was completed when Hawker acquired natural gas properties located in the Lavoy and Cold Lake areas. Hawker’s 2003 operating results reflect the costs of converting Hawker into an oil and gas enterprise and the results of its first six months of oil and gas operations. Accordingly, the 2003 operating results are not directly comparable to the 2002 operating results when the Company was winding down its biotech operations and seeking strategic alternatives.

REVENUE

Production revenue for the year ended December 31, 2003 was $17,582,000. The second half of 2003 marked the commencement of oil and gas operations for the Company and accordingly, there were no production revenues for the year ended December 31, 2002.

     All of the Company’s production was natural gas. Natural gas sales volumes for the six months ended December 31, 2003 averaged 16,346 mcf/d and the average price received was $5.84 per mcf. Hawker’s production was from the Lavoy area and the Cold Lake/Bonnyville area.

     The majority of the Company’s natural gas production is sold to aggregators and the Company receives AECO spot or AECO month index prices. The Company has entered into commodity price contracts to reduce the volatility of commodity prices and to ensure that funds are available to support planned capital expenditures. The financial and physical contracts currently in place are summarized in the table on page 26.

     Interest income for the year ended December 31, 2003 was $78,000 versus $32,000 for the year ended December 31, 2002. The increases were due to higher cash balances on hand during the first half of 2003 when the Company did not have bank debt, as compared to 2002.

FINANCIAL HIGHLIGHTS

YEAR ENDED DECEMBER 31	2003		2002
(in thousands of dollars, except per share amounts)
Revenue	$	17,582	$	—
Cash flow from operations (1)		5,985		(1,759	)
Per common share — basic and diluted		0.35		(0.35	)
Net earnings		2,314		3,766
Per common share — basic and diluted		0.14		0.76

⁽¹⁾ Cash flow from operations is a non-GAAP term that represents net earnings adjusted for non-cash items including depletion and depreciation, accretion, future income tax recovery, stock-based compensation, asset write-downs and gains (losses) on sale of assets. Cash flow per share is calculated by dividing cash flow from operations as previously described by the weighted average number of common shares outstanding during the year. The Company evaluates its performance based on earnings and cash flow from operations. The Company considers cash flow from operations a key measure as it demonstrates the Company’s ability to generate the cash flow necessary to fund future growth through capital investment and to repay debt.

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CONTRACT	TERM	VOLUME	AVERAGE PRICE		INDEX
Collar	Jan 2004 - Mar 2004	4,830 GJ/D	$	6.36 - $7.15	AECO
Collar	Apr 2004 - Oct 2004	18,000 GJ/D	$	5.50 - $6.37	AECO
Fixed Price	Jan 2004 - Mar 2004	1,610 GJ/D	$	6.76	AECO
Fixed Price	Apr 2004 - Oct 2004	10,000 GJ/D	$	5.76	AECO

     Other revenue received by the Company during 2003 primarily related to an exclusive license agreement of certain of its patents regarding toxin-binding sugars. Pursuant to this license agreement, the Company received net proceeds of $375,000. The Company also received a milestone payment of $105,000 with respect to the previous sale of its INH Technologies Inc. subsidiary. Other revenue of $107,000 received during the year ended December 31, 2002 also related to a milestone payment received by the Company with respect to the previous sale of its INH Technologies Inc. subsidiary. The Company cannot predict the likelihood, timing or amount of any further milestone or licensing receipts.

ROYALTY EXPENSE

Royalty expense for the year ended December 31, 2003 was $4,205,000, or 24 percent of production revenue. There was no royalty expense for 2002 as the Company did not have oil and gas operations.

PRODUCTION EXPENSE

Production expense for 2003 was $2,028,000 or $0.67 per mcf, including accretion expense of $100,000. There was no production expense for 2002 as the Company did not have oil and gas operations.

OPERATING NETBACKS

($/mcf)	2003
Revenues		5.84
Royalties		(1.40	)
Operating expenses		(0.67	)
Operating netbacks		3.77

GENERAL AND ADMINISTRATIVE EXPENSE

Net general and administrative expense for the year ended December 31, 2003 was $4,590,000, an increase of 183 percent from the $1,621,000 for the year ended December 31, 2002. The increase in general and administrative expenses was attributable to the addition of staff, use of consultants and increased general administrative costs associated with the Company becoming a fully operational oil and gas entity. General and administrative expenses totaling $564,000 were capitalized for the year ended December 31, 2003.

INTEREST EXPENSE

Interest expense for the year ended December 31, 2003 was $679,000 as compared with $71,000 for the year ended December 31, 2002. The increase in interest expense was a result of using the credit facility as an operating line of credit and to fund asset acquisitions.

DEPLETION AND DEPRECIATION

Depletion and depreciation expense for the year ended December 31, 2003 was $8,933,000 as compared with $26,000 for the year ended December 31, 2002. On a unit of production basis, depletion and depreciation expense on oil and gas assets was $17.79 per boe for the year ended December 31, 2003. Depletion and depreciation associated with oil and gas assets accounted for the large increase in depletion and depreciation expense for 2003 as compared with 2002. Depreciation expense for 2002 related solely to computer equipment and office furniture and equipment.

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ASSET RETIREMENT OBLIGATIONS

In 2003, the Company retroactively adopted the recommendations of the Canadian Institute of Chartered Accountants on accounting for asset retirement obligations. The new pronouncement requires the Company to recognize the fair value of a liability for an asset retirement obligation in the period in which it is incurred and a corresponding increase in the carrying value of the related long-lived asset. The liability is subsequently adjusted due to the passage of time, and is recognized as an accretion expense in the statement of earnings. The liability is also adjusted due to revisions in either the timing or the amount of the original estimated cash flows associated with the liability. The increase in the carrying value of the capital asset is amortized using the unit of production method based on estimated gross proven reserves as determined by independent engineers.

     The Company did not have long-lived assets subject to retirement obligations as at December 31, 2002 and therefore this change in accounting policy had no impact on the December 31, 2002 financial statements. The effect of this change on the December 31, 2003 balance sheet was an increase in capital assets of $3,191,000 and the recognition of an asset retirement obligation of $3,499,000. The change in accounting for asset retirement obligations as compared to the site restoration approach resulted in an increase in net earnings of $217,000 for the year ended December 31, 2003 ($0.01 per share).

STOCK-BASED COMPENSATION

Effective January 1, 2003, the Company adopted the recommendations of the Canadian Institute of Chartered Accountants on accounting for stock based compensation. Under this new pronouncement, stock based compensation expense is recorded for all stock options granted on or after January 1, 2003. For the year ended December 31, 2003, the impact of the adoption of this standard on the financial statements as at December 31, 2003 was a decrease in net earnings of $132,000 ($0.01 per share) and a corresponding increase in contributed surplus.

LEASE ABANDONMENT EXPENSE

During the third quarter of 2003, the Company consolidated its office space. A provision of $322,000 was made during the third quarter for residual lease costs on office space no longer occupied by the Company. This provision was increased by $180,000 to a total of $502,000 during the fourth quarter when sublease arrangements were modified. There was no lease abandonment expense for 2002.

OPERATING COSTS AND WRITE-DOWNS ASSOCIATED WITH ASSETS HELD FOR SALE

Assets held for sale are comprised of the pharmaceutical manufacturing facility and related manufacturing equipment associated with the former biotech operations of the Company. For the year ended December 31, 2003, operating costs and write-downs associated with assets held for sale were $190,000 as compared with $7,408,000 for the year ended December 31, 2002. During 2003, the Company wrote-down the carrying value of assets held for sale by $145,000 to the estimated net realizable value. During 2002, assets held for sale were written down by a total of $7,097,000.

INCOME TAXES

The Company’s current income tax expense was solely comprised of the Large Corporations Tax, and for the year ended December 31, 2003, totaled $345,000. There was no tax expense for the year ended December 31, 2002. The increase is due to the higher capital base of the Company attributable to the debt and equity financings completed during 2003.

     On December 5, 2003, the Company issued 2,900,000 flow-through shares for $15,225,000. In accordance with the agreements between the Company and the flow-through shareholders, the Company renounced $15,225,000 of Canadian Cumulative Exploration Expense as of December 31, 2003. This renunciation gave rise to a future tax liability of

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$5,271,000. The tax pools of the Company are sufficient to offset this liability and accordingly, a future tax recovery was recognized in an equal amount.

     Currently, the Company has tax pools that would provide for a $6,787,000 future tax benefit. This benefit has not been recognized due to the uncertainty of the future use of all of the tax pools.

LIQUIDITY AND CAPITAL RESOURCES

Pursuant to various financing agreements entered into April 3, 2003, the Company raised $3,645,000 through the issue of 430,493 Series A Debentures for $3,616,000, 430,493 Series A Warrants for $12,000, 2,152,465 voting preferred shares for $6,000 and 3,874,437 non-voting preferred shares for $11,000.

     Each Series A Warrant entitled the holder thereof to purchase five common shares and nine Class A common shares on the concurrent surrender of the warrant, five voting preferred shares, nine non-voting preferred shares, and one Series A Debenture. On May 29, 2003, immediately after the issue of a receipt for the prospectus offering common shares for sale and issue, the Series A Warrants were exercised and the Company issued 2,152,465 common shares and 3,874,437 Class A common shares upon the surrender of the voting and non-voting preferred shares and Series A Debentures.

     On May 29, 2003, the Company issued a fully marketed prospectus offering 14,286,000 common shares to the public priced at $3.15 per share. The issuance was fully subscribed and the public offering was completed on June 12, 2003. The Company received $42,301,000, net of underwriting fees.

     On December 5, 2003, the Company issued through a private placement, 2,900,000 common shares on a flow-through basis at a price of $5.25 per share. The Company received $14,514,000, net of underwriting fees.

     On December 30, 2003, the Company issued, pursuant to a prospectus offering, 11,200,000 common shares at a price of $4.05 per share. The Company received $43,092,000, net of underwriting fees.

     On March 31, 2003 the Company acquired all of the shares of 1022971 Alberta Ltd. (“1022971”) for a nominal amount and the Company was assigned an option to purchase up to a 49 percent interest in certain oil and gas properties west of the fourth meridian (“W4M Properties”) owned by Southward Energy Ltd. (“Southward”). On April 30, 2003, 1022971 acquired all of the shares of Southward. Immediately thereafter, Southward sold its oil and gas properties, excluding a one percent undivided interest in the W4M Properties and a 100 percent interest in seismic data, to an independent third party.

     On June 30, 2003, the Company exercised its option to purchase the W4M Properties. Further on June 30, 2003, the Company purchased the one percent undivided interest in the W4M Properties of Southward and the non-cash working capital of Southward was conveyed to the Company. Also on June 30, 2003, all of the shares of 1022971, which included Southward and all of its subsidiaries, were sold for nominal consideration to an independent third party. The total purchase price of the 50 percent interest in the W4M Properties and non-cash working capital of $71,337,000 was funded by the net proceeds of the prospectus offering and bank debt.

     On August 14, 2003, the Company acquired all of the shares of 1053638 Alberta Ltd. and 1053639 Alberta Ltd., seismic data companies. On August 19, 2003, the Company sold all of the shares of 1053638 Alberta Ltd. The net cash consideration paid was $1,200,000. On December 31, 2003, 1053639 Alberta Ltd. was amalgamated with Hawker.

     On December 30, 2003, Hawker acquired all of the shares of Pointwest Energy Inc., a privately held oil and gas company with operations in Alberta and B.C., for total consideration of $67,247,000, funded by bank debt and the net proceeds of the December 30, 2003 share issue. Pointwest Energy Inc. was amalgamated with Hawker on December 30, 2003. Upon completion of the review of the minor properties of Pointwest, the Company has

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agreed to sell those properties for approximately $6 million. The Company is also seeking offers on the Valhalla property due to its limited future potential.

     During the year ended December 31, 2003, the Company spent $14,783,000 on capital asset additions, excluding property acquisitions. There were no capital expenditures during 2002, reflecting the wind-down of the biotech operations of the Company.

CAPITAL EXPENDITURES

YEAR ENDED DECEMBER 31	2003
(in thousands of dollars)
Exploration and Development Expenditures
Lease acquisition and retention	$	1,916
Geological and geophysical		4,674
Drilling and completion		5,439
Facilities and equipment		2,475
Total Exploration and Development Expenditures		14,504
Other capital assets		279
Total Capital Expenditures	$	14,783

     During the second half of 2003, the Company participated in the drilling of 35 gross (17.6 net) wells. This resulted in 27 gross (13.6 net) wells and 8 gross (4.0 net) dry holes. As at December 31, 2003, only 12 of these wells had been connected into processing facilities and/or pipelines. The Company and the Lavoy operator are taking steps to accelerate the tie-in process.

     For the year ended December 31, 2003, proceeds of $1,173,000 were received on assets held for sale as compared with $44,000 for the year ended December 31, 2002. The assets held for sale relate to the pharmaceutical manufacturing facility and related manufacturing equipment associated with the former biotech operations of the Company.

     During the 2003, the Company received proceeds of $192,000 from the exercise of stock options under the stock option plan. The options exercised were granted while the Company was operating as a biotech firm.

     The Company has a $54 million extendible revolving term credit facility and a $10 million non-revolving bridge facility. As at December 31, 2003, $9.9 million of the extendible revolving term facility remained unutilized while the $10 million non-revolving bridge facility was fully utilized. The Company plans to use proceeds from oil and gas property sales to fund the repayment of the non-revolving bridge facility. The capacity of the extendible revolving term credit facility, combined with cash flow from operations, is expected to be sufficient to support the Company’s 2004 capital program.

     As at December 31, 2003, the Company’s working capital deficiency was $17,828,000, including the bridge financing of $10,000,000, compared to working capital of $412,000 as at December 31, 2002, reflecting the business acquisitions and year end activity level of the Company.

     Pursuant to the terms of a technology commercialization agreement pertaining to pharmaceutical drug development, the Company received a grant from the Alberta Heritage Foundation for Medical Research (“AHFMR”) in 1995. The Company was required to repay the amount advanced of $387,000 plus a royalty equivalent to the amount initially received. Any required repayment and royalty was based on gross sales of SYNSORB related products commencing January 1, 2000 with payments equal to the lesser of five percent of gross sales or $100,000 per annum commencing 90 days after January 1, 2001. Due to the conversion of the Company into an oil and gas enterprise and the nascent stage of the SYNSORB technology, the AHFMR accepted a royalty payment of $18,550 during the third quarter of 2003 in exchange for a full release of Hawker from the terms of the technology commercialization agreement.

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RISKS AND UNCERTAINTIES

The Company is engaged in the exploration, development, production and acquisition of crude oil and natural gas. This business is inherently risky and there is no assurance that hydrocarbon reserves will be discovered and economically produced. Financial risks associated with the petroleum industry include fluctuations in commodity prices, interest rates, and currency exchange rates along with the credit risk of the Company’s industry partners. Operational risks include reservoir performance uncertainties, the reliance on operators of our non-operated properties, competition, environmental and safety issues, and a complex and changing regulatory environment.

Hawker is taking steps to reduce its business risks by increasing the number of core areas it has and increasing the number of areas it operates. This will spread the operational risks over several areas, reducing the potential impact on Hawker of unfavourable operational issues that may occur at any one area. It will also enable Hawker to control the timing, direction and costs related to exploration and development activities. Environmental and safety risks are mitigated through compliance with provincial and federal environmental and safety regulations, by maintaining adequate insurance, and by adopting appropriate emergency response and safety procedures.

The Company manages commodity pricing uncertainties with a risk management program that encompasses a variety of financial instruments. These include forward sales contracts on natural gas production and financial sales contracts.

RECENT ACCOUNTING DEVELOPMENTS

The Canadian Institute of Chartered Accountants has issued a new accounting guideline related to full cost accounting for oil and gas. The recommendations contained in the guideline are to be implemented effective January 1, 2004 and it is expected adoption will not materially impact results.

OUTLOOK

At the start of 2003, the Company was a failed biotech firm seeking strategic alternatives. During the first half of 2003, the Company successfully transformed into an oil and gas enterprise and, at June 30, 2003, had a 50 percent working interest in two properties: the non-operated Lavoy area and the Cold Lake/Bonnyville area, which is operated by Hawker.

With the acquisition of Pointwest, the Company also has an average 85 percent working interest in the Boundary Lake area and a 100 percent working interest in the Valhalla property, both operated by Hawker, along with some minor non-operated properties. In the six short months since becoming an oil and gas enterprise, Hawker has also developed and drilled two successful gas wells on one of its own internally generated prospects at Chigwell, an emerging core area in that it provides the Company with the opportunity to add value to the property in the future. The Company has also assembled an exploration team and land outside its producing areas, including Purple Springs and Wild River, that will enable it to develop new core areas in 2004.

For fiscal 2004, the Company has budgeted $55.8 million of capital expenditures for exploration and exploitation opportunities. Hawker anticipates achieving an average production level in excess of 7,000 boe/d for 2004.

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Exhibit 3

Management’s Report and
Auditors’ Report to Shareholders

MANAGEMENT’S REPORT

The financial statements of Hawker Resources Inc. were prepared by management in accordance with Canadian generally accepted accounting principles. The financial and operating information presented in this annual report is consistent with that shown in the financial statements.

Management has designed and maintains a system of internal controls to provide reasonable assurance that all assets are safeguarded and to facilitate the preparation of financial statements for reporting purposes. Timely release of financial information sometimes necessitates the use of estimates when transactions affecting the current accounting period cannot be finalized until future periods. Such estimates are based on careful judgments made by management.

External auditors appointed by the shareholders have conducted an independent examination of the Company’s accounting records in order to express their opinion on the financial statements.

The Board of Directors is responsible for ensuring that management fulfils its responsibilities for financial and internal control. The Board exercises this responsibility through its Audit Committee. The Audit Committee, which consists of non-management members, has met with the external auditors and management in order to determine that management has fulfilled its responsibilities in the preparation of the financial statements. The Audit Committee has reported its findings to the Board of Directors who have approved the financial statements.

DAVID A. TUER
President and Chief Executive Officer

BARRY HERRING
Senior Vice President and Chief Financial Officer
Calgary, Canada
March 17, 2004

TO THE SHAREHOLDERS OF HAWKER RESOURCES INC.

We have audited the balance sheets of Hawker Resources Inc. as at December 31, 2003 and 2002 and the statements of earnings and deficit and cash flows for the years then ended. These financial statements are the responsibility of the Company’s management. Our responsibility is to express an opinion on these financial statements based on our audits.

We conducted our audits in accordance with Canadian generally accepted auditing standards. Those standards require that we plan and perform an audit to obtain reasonable assurance whether the financial statements are free of material misstatement. An audit includes examining, on a test basis, evidence supporting the amounts and disclosures in the financial statements. An audit also includes assessing the accounting principles used and significant estimates made by management, as well as evaluating the overall financial statement presentation.

In our opinion, these financial statements present fairly, in all material respects, the financial position of the Company as at December 31, 2003 and 2002 and the results of its operations and its cash flows for the years then ended in accordance with Canadian generally accepted accounting principles.

CHARTERED ACCOUNTANTS
Calgary, Canada
March 10, 2004
(except for note 17 which is as of March 17, 2004)

- PAGE 31 -

Balance Sheets

AS AT DECEMBER 31	2003			2002
(in thousands of dollars)
ASSETS
Current
Cash	$	–		$	289
Accounts receivable		11,577			27
Investments		2,500			–
Prepaids and other current assets		1,845			176
		15,922			492
Assets held for sale (Note 5)		2,190			3,500
Capital assets (Notes 4, 6 and 7)		166,990			23
	$	185,102		$	4,015
LIABILITIES AND SHAREHOLDERS’ EQUITY
Current
Accounts payable and accrued liabilities	$	23,750		$	80
Bank loan (Note 7)		10,000			–
		33,750			80
Bank loan (Note 7)		44,149			–
Leasehold inducements		247			–
Alberta Heritage Foundation grant (Note 8)		–			387
Asset retirement obligations (Note 3)		3,499			–
Commitments and contingencies (Notes 4, 15 and 16)
Shareholders’ Equity (Note 9)
Share capital		110,204			12,741
Contributed surplus		132			–
Deficit		(6,879	)		(9,193	)
		103,457			3,548
	$	185,102		$	4,015

See accompanying notes to the financial statements

On behalf of the Board:
DIRECTOR	DIRECTOR

- PAGE 32 -

Statements of Earnings and Deficit

FOR THE YEARS ENDED DECEMBER 31	2003			2002
(in thousands of dollars, except per share amounts)
				Restated
				(Note 4 (d))
Revenue
Production revenue	$	17,582		$	–
Royalties		(4,205	)		–
		13,377			–
Interest income		78			32
Other		487			107
		13,942			139
Expenses
Production		2,028			–
General and administrative (Note 10)		4,590			1,621
Interest on long-term debt		679			71
Depletion and depreciation		8,933			26
		16,230			1,718
Loss before the following		(2,288	)		(1,579	)
Lease abandonment expense		(502	)		–
Operating costs and write-downs associated with assets held for sale		(190	)		(7,408	)
Gain on the sale and distribution of Oncolytics shares		–			13,067
Share of loss from equity investment in Oncolytics		–			(314	)
Alberta Heritage Foundation grant settlement (Note 8)		368			–
Earnings (loss) before taxes		(2,612	)		3,766
Taxes
Future income tax recovery (Note 11)		(5,271	)		–
Capital taxes		345			–
		(4,926	)		–
Net earnings		2,314			3,766
Deficit, beginning of year		(9,193	)		(72,855	)
Reduction of stated capital (Note 9)		–			59,896
Deficit, end of year	$	(6,879	)	$	(9,193	)
Basic and diluted net earnings per common share (Note 9)	$	0.14		$	0.76

See accompanying notes to the financial statements

- PAGE 33 -

Statements of Cash Flows

YEARS ENDED DECEMBER 31	2003			2002
(in thousands of dollars)
				Restated
				(Note 4 (d))
OPERATING ACTIVITIES
Net earnings	$	2,314		$	3,766
Add (deduct) non-cash items:
Depletion, depreciation and asset write-downs		9,078			7,216
Accretion expense		100			–
Alberta Heritage Foundation grant settlement (Note 8)		(368	)		–
Future income tax recovery		(5,271	)		–
Stock-based compensation (Note 10)		132			–
Share of loss from equity investment in Oncolytics		–			314
Gain on sale and distribution of Oncolytics shares		–			(13,067	)
Issuance of stock options for services		–			12
		5,985			(1,759	)
Net change in non-cash working capital (Note 14)		5,660			(4,779	)
		11,645			(6,538	)
INVESTING ACTIVITIES
Proceeds from sale of capital assets		1,173			44
Acquisition of oil and gas properties (Note 4)		(139,784	)		–
Additions to oil and gas properties		(14,504	)		–
Additions to other capital assets		(279	)		–
Leasehold inducements received		247			–
Proceeds from sale of Oncolytics shares		–			6,898
Net change in non-cash working capital (Note 14)		806			–
		(152,341	)		6,942
FINANCING ACTIVITIES
Common shares issued on exercise of options		192			–
Common shares issued for cash		105,633			–
Issue of debentures and warrants		3,645			–
Increase in bank loan		37,720			–
Share issue costs		(6,736	)		–
Costs of distribution of shares in Oncolytics		–			(46	)
Repayment of bank debt		–			(5,910	)
Alberta Heritage Foundation royalty payment (Note 8)		(19	)		–
Net change in non-cash working capital (Note 14)		(28	)		–
		140,407			(5,956	)
Decrease in cash		(289	)		(5,552	)
Cash, beginning of year		289			5,841
Cash, end of year	$	–		$	289

Supplemental disclosure of cash flow information (Note 14)

See accompanying notes to the financial statements

- PAGE 34 -

Notes to Financial Statements

Years ended December 31, 2003 and 2002
(Tabular amounts in thousands of dollars, unless otherwise noted)

1. NATURE OF OPERATIONS

Prior to 2002, SYNSORB Biotech Inc. (“SYNSORB”) conducted pharmaceutical drug research and development. On December 10, 2001 SYNSORB terminated its drug development activities. At the Annual and Special Meeting of SYNSORB shareholders held April 3, 2003, shareholders approved the planned conversion of the company into an oil and gas enterprise and changed the company’s name to Hawker Resources Inc.

2. SUMMARY OF SIGNIFICANT ACCOUNTING POLICIES

The financial statements of Hawker Resources Inc. (the “Company” or “Hawker”) have been prepared in accordance with Canadian generally accepted accounting principles. The timely preparation of financial statements requires that management makes estimates and assumptions, and use judgement regarding assets, liabilities, revenues and expenses. Such estimates primarily relate to unsettled transactions and events as of the date of the financial statements. Accordingly, actual results may differ from estimated amounts. In the opinion of management, these financial statements have been properly prepared within reasonable limits of materiality and within the framework of the significant accounting policies summarized below.

(a) Capital Assets

Cost

The Company follows the full cost method of accounting whereby all costs relating to the acquisition of, exploration for and development of oil and gas reserves are capitalized in a single Canadian cost center. Such costs include lease acquisition, lease rentals on undeveloped properties, geological and geophysical, drilling both productive and non-productive wells, production equipment and overhead charges directly related to acquisition, exploration and development activities.

     Gains or losses are not recognized upon the disposition of oil and gas properties unless such a disposition would change the depletion rate by 20 percent or more. Gains and losses are recognized upon the disposition of other assets.

     Other capital assets are recorded at cost.

Depletion, depreciation and amortization

All costs of acquisition, exploration and development of oil and gas reserves, associated tangible plant and equipment costs (net of salvage value), and estimated costs of future development of proven undeveloped reserves are depleted and depreciated by the unit of production method based on estimated gross proven reserves as determined by independent engineers.

     Costs of unproved properties and seismic costs on undeveloped land are initially excluded from oil and gas properties for the purpose of calculating depletion. When proven reserves are assigned or the property is considered to be impaired, the cost of the property or the amount of the impairment is added to costs subject to depletion.

     The relative volumes of oil and natural gas reserves and production are converted to equivalent barrels of oil based on the relative energy content of each product on a 6 to 1 basis.

     Depreciation of capital assets not related to oil and gas properties is provided using the declining balance method at rates between 20 and 30 percent. Leasehold improvements are amortized on a straight-line basis over the term of the lease.

Impairment

The Company applies a ceiling test to the capitalized costs of its oil and gas properties, net of future income taxes and asset retirement obligations, to ensure that the net carrying value does not exceed the estimated value of future net revenues from production of gross proven reserves plus undeveloped properties less future production-related general and administrative expenses, financing costs, site restoration and abandonment costs and income taxes. Any reduction in the net carrying value of oil and gas properties as a result of the ceiling test is charged to operations.

     The calculation of future net revenues is based on sales prices, costs and regulations in effect at period end.

     The carrying value of undeveloped properties (land and seismic data) is reviewed periodically and written down to net realizable value if impairment is determined.

- PAGE 35 -

(b) Asset Retirement Obligations

The Company recognizes the fair value of a liability for an asset retirement obligation in the period in which it is incurred and records a corresponding increase in the carrying value of the related long-lived asset. The fair value is determined through a review of engineering studies, industry guidelines, and management’s estimate on a site by site basis. The liability is subsequently adjusted for the passage of time, and is recognized as an accretion expense in the statement of earnings under asset retirement obligations. The liability is also adjusted due to revisions in either the timing or the amount of the original estimated cash flows associated with the liability. The increase in the carrying value of the asset is amortized using the unit of production method based on estimated gross proven reserves as determined by independent engineers.

(c) Leasehold Inducements

Leasehold inducements are accounted for as a reduction of rental expense over the term of the related lease.

(d) Revenue Recognition

Oil and natural gas sales are recognized as revenue when the commodities are delivered to purchasers.

     Revenue from milestone payments and royalties is recognized when received.

(e) Hedging and Forward Sales Contracts

In certain circumstances, fixed price commodity contracts or commodity derivative contracts are used to reduce the Company’s exposure to adverse fluctuations in commodity prices to protect future cash flow used to finance the Company’s capital expenditure program. Gains and losses relating to commodity derivative contracts which settle via net cash payment and that meet hedge criteria are recognized as part of natural gas sales concurrently with the hedged transaction. The Company does not enter into financial instruments for trading or speculative purposes.

     The Company believes the derivative financial instruments are effective as hedges, both at inception and over the term of the instrument, as the term to maturity, the notional amount and the commodity price basis in the instruments all match the terms of the future revenue stream being hedged.

     Realized and unrealized gains and losses associated with commodity derivative contracts which have been terminated or cease to be effective prior to maturity, are deferred as other current, or non-current, assets or liabilities on the balance sheet, as appropriate, and recognized in earnings in the period in which the underlying hedged transaction is recognized. In the event a designated hedged item is sold, extinguished or matures prior to the termination of the related derivative instrument, any realized or unrealized gain or loss on such derivative instrument is recognized in earnings.

(f) Joint Ventures

Substantially all of the Company’s exploration, development and production activities are conducted jointly with others and, accordingly, these financial statements reflect only the Company’s proportionate interest in such activities.

(g) Stock Based Compensation

Under the Company’s stock option plan, options to purchase common shares are granted to directors, officers, employees and consultants at current market prices. Options issued by the Company in 2003 are accounted for in accordance with the fair value method of accounting for stock-based compensation, and as such the cost of the option is charged to earnings with an offsetting amount recorded to contributed surplus, based on an estimate of the fair value determined using a Black-Scholes options pricing model. No compensation expense has been recorded on options issued in 2002 (see Note 10).

(h) Investments

Investments in marketable securities are recorded at the lower of cost and market value. At December 31, 2003, the investments had a quoted market value of $3,012,000.

- PAGE 36 -

(i) Future Income Taxes

The Company follows the liability method of accounting for income taxes. Under this method, future tax assets and liabilities are determined based on differences between financial reporting and tax bases of assets and liabilities and are measured using substantially enacted tax rates and laws that will be in effect when the differences are expected to reverse. Income tax expense for the period is the tax payable for the period and any change during the period in future income tax assets and liabilities. A valuation allowance is recorded to the extent that there is uncertainty regarding utilization of future tax assets.

(j) Per Common Share Amounts

The Company uses the treasury stock method to determine the dilutive effect of stock options. This method assumes that proceeds from the exercise of stock options would be used to purchase common shares at the average market price during the year.

(k) Measurement Uncertainty

The amount recorded for depletion and depreciation of petroleum and natural gas properties, the provision for asset retirement obligation costs and the ceiling test calculation are based on estimates of gross proven reserves, production rates, commodity prices, future costs and other relevant assumptions. By their nature, these estimates are subject to measurement uncertainty and the effect on the financial statements of changes in such estimates in future years could be significant.

(l) Flow-through Common Shares

Resource expenditure deductions for income tax purposes related to exploration and development activities funded by flow-through share arrangements are renounced to investors in accordance with income tax legislation. The estimated tax benefits transferred to shareholders are recorded as future income taxes and a reduction to share capital when the expenditures are renounced.

(m) Comparative Figures

Certain figures provided for 2002 have been reclassified to conform to the presentation adopted in 2003.

3. CHANGES IN ACCOUNTING POLICIES

(a) Asset Retirement Obligations

In 2003, the Company retroactively adopted the recommendations of the Canadian Institute of Chartered Accountants on accounting for asset retirement obligations. These recommendations replace the existing policy on future site restoration, and as a result, have been treated as a change in accounting policy.

     The new pronouncement requires the Company to recognize the fair value of a liability for an asset retirement obligation in the period in which it is incurred and a corresponding increase in the carrying value of the related long-lived asset. This fair value is determined through a review of engineering studies, industry guidelines, and management’s estimate on a site by site basis. The liability is subsequently adjusted due to the passage of time, and is recognized as an accretion expense in the statement of earnings. The liability is also adjusted due to revisions in either the timing or the amount of the original estimated cash flows associated with the liability. The increase in the carrying value of the capital asset is amortized using the unit of production method based on estimated gross proven reserves as determined by independent engineers.

     The Company estimates the undiscounted cash flows related to asset retirement obligations, adjusted for inflation, to be incurred over the estimated reserve life of the underlying assets will total approximately $4,972,000. The fair value at December 31, 2003 is $3,499,000 using a discount rate of six percent and an inflation rate of two percent. As at December 31, 2003, no funds have been set aside to settle this obligation.

     As the Company did not have long-lived assets subject to retirement obligations as at December 31, 2002, this change in accounting policy had no impact on the December 31, 2002 financial statements. The effect of this change on the December 31, 2003 balance sheet was an increase in capital assets of $3,191,000, and the recognition of an asset retirement obligation of $3,499,000. Accretion expense of $100,000 was included in production expense for the year ended December 31, 2003. The change in accounting for asset retirement obligations as compared to the site restoration approach resulted in an increase in net earnings of $217,000 for the year ended December 31, 2003 ($0.01 per share).

- PAGE 37 -

(b) Stock Based Compensation

Effective January 1, 2003, the Company adopted the recommendations of the Canadian Institute of Chartered Accountants on accounting for stock based compensation. Under this new pronouncement, stock based compensation expense is recorded for all stock options granted on or after January 1, 2003. As permitted by the standard, the Company applied the change prospectively. The pro forma earnings impact of the stock based compensation expense for stock options granted prior to January 1, 2003 is disclosed in Note 10.

     For the year ended December 31, 2003, the impact of the adoption of this standard on the financial statements as at December 31, 2003 was a decrease in net earnings of $132,000 ($0.01 per share) and a corresponding increase in contributed surplus.

4. BUSINESS ACQUISITIONS AND DISPOSITIONS

(a) 1022971 Alberta Ltd.

On March 31, 2003 the Company acquired all of the shares of 1022971 Alberta Ltd. (“1022971”) for a nominal amount and the Company was assigned an option to purchase up to a 49 percent interest in certain oil and gas properties west of the 4th meridian (“W4M Properties”) owned by Southward Energy Ltd. (“Southward”). On April 30, 2003, 1022971 acquired all of the shares of Southward. Immediately thereafter, Southward sold its oil and gas properties, excluding a one percent undivided interest in the W4M Properties and a 100 percent interest in seismic data, to an independent third party.

     On June 30, 2003, the Company exercised its option to purchase a 49 percent interest in the W4M Properties. Further on June 30, 2003, the Company purchased the one percent undivided interest in the W4M Properties of Southward and the non-cash working capital of Southward was conveyed to the Company. Also on June 30, 2003, all of the shares of 1022971, which included Southward and all of its subsidiaries, were sold for nominal consideration to an independent third party.

     The resultant acquisition of a 50 percent interest in the W4M Properties on June 30, 2003 has been accounted for using the purchase method of accounting. The results of operations for the W4M Properties have been included in the financial statements since June 30, 2003.

     The following table summarizes the estimated fair value of the assets and liabilities assumed at the date of acquisition:

Capital assets	$	70,514
Asset retirement obligations		(2,833	)
Non-cash working capital		3,656
Cash cost	$	71,337

     The Company has agreed to indemnify the purchaser of Southward for income tax and legal expenses to a maximum amount of $1 million for matters arising prior to the April 30, 2003 acquisition of Southward.

(b) 1053638 Alberta Ltd. and 1053639 Alberta Ltd.

On August 14, 2003, the Company acquired all of the shares of 1053638 Alberta Ltd. and 1053639 Alberta Ltd., seismic data companies. On August 19, 2003, the Company sold all of the shares of 1053638 Alberta Ltd. The net acquisitions were accounted for by the purchase method and the purchase price was allocated as follows:

     Allocation of purchase price:

Capital assets	$	1,200
Cash cost	$	1,200

     The disposition of 1053638 Alberta Ltd. did not result in any gain or loss to the Company. On December 31, 2003, 1053639 Alberta Ltd. was amalgamated with the Company.

- PAGE 38 -

(c) Pointwest Energy Inc.

On December 30, 2003 the Company acquired all of the shares of Pointwest Energy Inc. (“Pointwest”), a privately held oil and gas company. The acquisition was accounted for by the purchase method and the purchase price was allocated as follows:

     Allocation of purchase price:

Capital assets	$	89,363
Bank debt		(16,429	)
Asset retirement obligations		(518	)
Non-cash working capital		(5,169	)
Cash cost	$	67,247

     On December 30, 2003, Pointwest was amalgamated with the Company.

(d) Oncolytics Biotech Inc.

As at December 31, 2001, the Company held 6,255,800 common shares of Oncolytics Biotech Inc. (“Oncolytics”). On May 7, 2002 approval was received from both the shareholders of the Company and the shareholders of Oncolytics for the distribution of not less then 4,000,000 Oncolytics shares to the shareholders of the Company on a pro rata basis. On May 8, 2002 the Company received approval from the Court of the Queen’s Bench of Alberta to distribute these Oncolytics shares and the distribution of 4,000,235 Oncolytics shares was made effective May 15, 2002. The deemed value of these shares on the date of distribution, net of legal fees with respect to the transaction, was $11,600,000 resulting in a gain on distribution of $8,325,000. The transaction was marked to market and accounted for as a return of capital (see Note 9). As part of this transaction the Company’s holding of 1,500,000 million shares in BCY Life Sciences Inc. was transferred to Oncolytics. No value had been assigned to these shares in the accounts of the Company and no gain or loss was recorded as a result of the transaction. The market value of the BCY shares on May 15, 2002 was $300,000.

     The Company had used the equity method of accounting for its investment in Oncolytics Biotech Inc. (“Oncolytics”) up until the distribution of the majority of its holding in Oncolytics on May 15, 2002. Under this method of accounting, the Company included in its net earnings its share of the net earnings or losses of Oncolytics. Upon further review of the facts surrounding the distribution of the Oncolytics shares, the Company has concluded that it should have ceased to equity account for Oncolytics at the end of the first quarter of 2002 when it no longer exerted significant influence over Oncolytics. If the Company had ceased equity accounting for its investment in Oncolytics at that time, Hawker would not have recorded the portion of Oncolytics’ second quarter loss included in its statements. To reflect this correction, the Company has restated its financial statements for the year ended December 31, 2002 by decreasing the share of loss from equity investment in Oncolytics and decreasing the gain on the subsequent sale and distribution of Oncolytics shares by $157,000 resulting in no change to reported net earnings for the year. The balance sheet and cash flows for 2002 were not affected by this change.

     During the year ended December 31, 2002, the Company sold 2,255,565 common shares in Oncolytics for net proceeds of $6,898,000 resulting in a gain on sale of $4,742,000. As at December 31, 2002 the Company did not hold any common shares of Oncolytics.

5. ASSETS HELD FOR SALE

Assets held for sale are comprised of the pharmaceutical manufacturing facility and related manufacturing equipment associated with the former biotech operations of the Company. During 2003, manufacturing equipment with a carrying value of $940,000 was sold and the Company wrote down the carrying value of the remaining assets held for sale by $145,000. The assets held for sale are recorded at the lower of carrying value and market value. Market value was based on estimated value as determined by independent realty advisors.

- PAGE 39 -

6. CAPITAL ASSETS

			Accumulated
			Depletion and		Carrying
2003	Cost		Depreciation		Value
Oil and gas properties	$	175,631	$	8,916	$	166,715
Other		295		20		275
	$	175,926	$	8,936	$	166,990

			Accumulated
			Depletion and		Carrying
2002	Cost		Depreciation		Value
Other	$	526	$	503	$	23

     Unproved properties and seismic related to the W4M Properties amounting to $16,122,000 have been excluded from the depletion and depreciation calculation for 2003. No depletion and depreciation has been recorded on the Pointwest properties as they were acquired December 30, 2003. Future development costs on proven undeveloped reserves of $1,269,000 are included in the depletion and depreciation calculation.

     At December 31, 2003, the Company capitalized $564,000 of overhead directly related to exploration and development activities.

7. BANK LOAN

The Company has a $54 million extendible revolving term credit facility from a Canadian chartered bank. This facility bears interest at rates varying from Canadian prime rate or U.S. base rate of such bank to the Canadian prime rate or U.S. base rate plus 75 basis points, payable monthly in arrears. The Company may also borrow by way of bankers’ acceptances, which are subject to a stamping fee, or by way of LIBOR based loans which are subject to an interest rate spread payable to the bank. The loan is a revolving facility until June 30, 2004 with annual extension periods available at the bank’s discretion. After the revolving phase, the facility becomes a term facility payable in full one year from the date the revolving facility is terminated. This facility is subject to semi-annual review and re-determination of the Company’s borrowing base by the bank, with the next review to occur by March 31, 2004. So long as the loan remains revolving and the borrowing base supports the facility outstanding, there are no repayment requirements.

     The Company also has a $10 million non-revolving bridge facility from the same Canadian chartered bank. This bridge facility, available to the Company solely for the acquisition of Pointwest, was fully drawn upon as at December 31, 2003. The bridge facility bears interest at rates varying from Canadian prime rate plus 250 basis points, payable monthly in arrears. The Company may also borrow by way of bankers’ acceptances that are subject to a stamping fee payable to the bank. The bridge facility is repayable in full on or prior to September 30, 2004.

     While any amounts are outstanding under the bridge facility, the loan margins on both the extendible revolving term credit facility and the bridge facility will be increased by (i) 25 basis points effective May 1, 2004; (ii) 50 basis points effective June 1, 2004; (iii) 100 basis points effective July 1, 2004; (iv) 150 basis points effective August 1, 2004; and (v) 200 basis points effective September 1, 2004.

     Collateral pledged for the facilities consists of a first floating charge demand debenture in the amount of $150 million over all of the property of the Company.

     The effective interest rate on the amounts outstanding under the facility at December 31, 2003 was 5.25 percent.

     At December 31, 2003, irrevocable standby letters of credit which guarantee certain natural gas transportation arrangements had been issued for a total of $311,000.

8. ALBERTA HERITAGE FOUNDATION GRANT

Pursuant to the terms of a technology commercialization agreement pertaining to pharmaceutical drug development, the Company received a grant from the Alberta Heritage Foundation for Medical Research (“AHFMR”) during 1995. The Company was required to repay the amount advanced of $387,000 plus a royalty equivalent to the amount initially received. Any required repayment and royalty was based on gross sales of SYNSORB related products commencing January 1, 2000

- PAGE 40 -

with payments equal to the lesser of five percent of gross sales or $100,000 per annum commencing 90 days after January 1, 2001. Due to the conversion of the Company into an oil and gas enterprise and the nascent stage of the SYNSORB technology, the AHFMR accepted a royalty payment of $18,550 during 2003 in exchange for a full release of Hawker from the terms of the technology commercialization agreement.

9. SHARE CAPITAL

(a) Authorized:

Unlimited number of voting common shares without par value.
Unlimited number of non-voting class A common shares without par value.
Unlimited number of preferred shares to be issued in series.

(b) Common Shares Issued

	2003					2002
	Number					Number
	of Shares		Amount			of Shares		Amount
Balance, beginning of year		4,959,937	$	12,741			4,959,937	$	84,271
Reduction of stated capital		–		–			–		(59,896	)
Issued for cash		28,461,000		105,633			–		–
Share issue costs		–		(6,826	)		–		–
Issued on debenture and warrant conversion		2,152,465		1,302			–		–
Issued for services received		148,798		90			–		–
Issued for cash on exercise of options		275,000		192			–		–
Tax benefits renounced		–		(5,271	)		–		–
Return of capital on distribution of Oncolytics shares		–		–			–		(11,646	)
Issuance of stock options for services		–		–			–		12
Balance, end of year		35,997,200	$	107,861			4,959,937	$	12,741

(c) Class A Common Shares Issued

	2003				2002
	Number				Number
	of Shares		Amount		of Shares		Amount
Balance, beginning of year		–	$	–		–	$	–
Issued on debenture and warrant conversion		3,874,437		2,343		–		–
Balance, end of year		3,874,437	$	2,343		–	$	–

(d) Contributed Surplus

	2003
Balance, beginning of year	$	–
Stock based compensation		132
Balance, end of year	$	132

(e) Issue of Debentures and Warrants

Pursuant to various financing agreements entered into April 3, 2003, the Company raised $3,645,000 through the issue of 430,493 Series A Debentures for $3,616,000, 430,493 Series A Warrants for $12,000, 2,152,465 voting preferred shares for $6,000 and 3,874,437 non-voting preferred shares for $11,000.

     Each Series A Warrant entitled the holder thereof to purchase five common shares and nine Class A common shares on the concurrent surrender of the warrant, five voting preferred shares, nine non-voting preferred shares, and one Series A Debenture. On May 29, 2003, immediately after the issue of a receipt for the prospectus offering common shares for sale

- PAGE 41 -

and issue, the Series A Warrants were exercised and the Company issued 2,152,465 common shares and 3,874,437 Class A common shares upon the surrender of the voting and non-voting preferred shares and Series A Debentures.

(f) Share Consolidation

On May 7, 2002, the shareholders of the Company approved the consolidation of the common shares on the basis of one new common share being issued for every eight previously issued and outstanding common shares. All outstanding share and option numbers reflect the one for eight consolidation. The consolidated shares began trading on May 16, 2002. Simultaneously with the share consolidation was the distribution of the 4,000,235 shares in Oncolytics to the shareholders of the Company. This distribution was accounted for as a capital transaction and accordingly, the stated capital of the common shares was reduced by $11,646,000.

(g) Reduction of Stated Capital

Pursuant to the Plan of Arrangement ratified by shareholders of the Company at the May 7, 2002 Annual and Special Meeting, the stated capital of SYNSORB shares was reduced to the net realizable value of the Company’s assets as at May 7, 2002.

(h) Flow-Through Shares

During 2003, the Company issued common shares on a flow-through basis for gross proceeds of $15,225,000 to finance certain oil and gas expenditures to be incurred in 2004. The renouncement of these expenditures was made to the purchasers of these shares effective December 31, 2003 and accordingly, share capital has been reduced by the amount of the tax benefits associated with these expenditures. The corresponding future tax liability has also been recognized in the current year.

(i) Stock Options

The Company has a stock option plan that provides for the issuance of options to its directors, officers, employees and non-employees to acquire up to 1,181,513 common shares. The dates on which options vest are set by the board of directors at the time of grant. The exercise price of an option granted is the closing price of the Company’s stock on the last trading date prior to the grant date. The dates on which options expire are also set by the board of directors at the time of grant and cannot exceed ten years. The Company has issued stock options to acquire common shares through its stock option plan of which the following are outstanding at December 31, 2003:

	2003					2002
	Number of			Weighted average		Number of			Weighted average
	options			exercise price $		options			exercise price $
Outstanding at beginning of the year		330,565			9.80		244,440			40.88
Granted		428,000			3.66		275,000			0.70
Exercised		(275,000	)		0.70		–			–
Expired		(12,500	)		87.20		(6,250	)		68.00
Forfeited		(27,064	)		52.20		(182,625	)		35.76
Outstanding at year end		444,001			4.74		330,565			9.80
Options exercisable at end of year		15,751			34.27		329,065			9.80

The following table summarizes information about the stock options outstanding at December 31, 2003:

			Weighted
	Number		average		Weighted		Number		Weighted
	outstanding		remaining		average		exercisable		average
	December 31,		contractual		exercise		December 31,		exercise
Range of exercise prices	2003		life (years)		price		2003		price
$3.00 to $4.00		365,000		4.44	$	3.57		–		–
$4.01 to $5.00		60,000		4.89	$	4.08		–		–
$5.01 to $9.00		3,000		4.67	$	5.20		–		–
$9.01 to $30.00		8,188		2.33	$	20.06		7,938	$	20.42
$30.01 to $90.00		7,813		4.30	$	48.33		7,813	$	48.33
		444,001		4.46	$	4.74		15,751	$	34.27

- PAGE 42 -

     For the year ended December 31, 2003, no stock options were granted to non-employees. The Company has undertaken to facilitate the surrender of out-of-the-money options that were issued in previous years when the Company conducted pharmaceutical drug development. Subsequent to December 31, 2003, the Company granted options to purchase 64,600 common shares at a weighted average price of $5.48, which expire during the first quarter of 2009. Also subsequent to December 31, 2003, options to purchase 15,000 common shares at $3.45 were forfeited.

(j) Per Share Amounts

The weighted average number of common shares and Class A common shares outstanding during the year ended December 31, 2003 of 17,123,542 (2002: 4,959,937) were used to calculate net earnings per common share. For the year ended December 31, 2003, the exercise price of the outstanding stock options exceeded the average market price of the common shares making the options anti-dilutive. For the year ended December 31, 2002, the respective exercise price of the stock options and warrants exceeded the average market price of the common shares making the options and warrants anti-dilutive.

10. STOCK BASED COMPENSATION

Options granted after January 1, 2003 are accounted for using the fair value method. The fair value of common share options granted in 2003 is estimated to be $789,000 as at the date of grant using the Black-Scholes option pricing model and the following weighted average assumptions:

	2003
Risk-free interest rate (%)		3.79
Expected life (years)		4.00
Expected volatility (%)		54.59
Expected dividend yield (%)		0

     The estimated fair value of the options is amortized to expense over the options’ vesting period on a straight-line basis. For the year ended December 31, 2003, stock based compensation expense of $132,000 was included in general and administrative expenses.

     Had the fair value based method of accounting for stock based compensation been used for options granted in 2002, the Company’s net earnings and net earnings per share for the year ended December 31, 2002 would have been reduced to the pro forma amounts indicated below:

	2002
Net earnings
As reported	$	3,766
Pro forma	$	3,646
Basic and diluted net earnings per common share
As reported ($/share)	$	0.76
Pro forma ($/share)	$	0.74

     The pro forma amounts shown above do not include the compensation costs associated with stock options granted prior to January 1, 2002. The fair value of common share options granted in 2002 was estimated to be $120,000 as at the date of grant using the Black-Scholes option pricing model and the following assumptions:

	2002
Risk-free interest rate (%)		2.89
Expected life (years)		1.00
Expected volatility (%)		1.97
Expected dividend yield (%)		0

     All stock options issued in 2002 were exercised in 2003.

- PAGE 43 -

11. INCOME TAXES

The provision for income taxes recorded in the financial statements differs from the amount which would be obtained by applying the statutory income tax rate to the net earnings (loss) before tax as follows:

	2003			2002
Earnings (loss) before tax	$	(2,612	)	$	3,766
Statutory Canadian corporate tax rate		40.74	%		39.24	%
Anticipated tax expense (recovery)		(1,064	)		1,478
Non-deductible Crown payments		945			–
Resource allowance		(878	)		–
Recognition of loss carryforward previously unrecognized		(5,271	)		–
Effect of tax rate change		519			–
Non-taxable portion of capital gain		–			(2,536	)
Non-deductible portion of equity loss		–			92
Non-deductible expenses		–			3
Future tax assets valuation allowance		478			963
Future income tax recovery	$	(5,271	)	$	–

     Future income taxes reflect the net tax effects of temporary differences between the carrying amounts of assets and liabilities for financial reporting purposes and the amounts used for income tax purposes. The components of the Company’s future income tax assets and liabilities are as follows:

	2003			2002
Future tax liabilities
Net book value of capital assets in excess of tax pools	$	(10,726	)	$	–
Future tax assets
Tax pools in excess of net book value of capital assets		–			6,422
Non-capital loss carryforwards		6,243			11,984
Scientific research and development pools		7,784			7,896
Share issue costs		2,006			400
Attributed Canadian royalty income		268			–
Asset retirement obligation		1,212			–
Net future tax assets		6,787			26,702
Valuation allowance		(6,787	)		(26,702	)
Net future taxes	$	–		$	–

     The Company has non-capital losses for income tax purposes of approximately $18,035,000 which are available for application against future taxable income and which expire in the following years:

2006	$	1,448
2007		5,103
2008		11,484
	$	18,035

     The income tax benefit of these losses has not been recognized in the financial statements, as reflected in the valuation allowance. The Company also has approximately $5,700,000 of unclaimed investment tax credits available to reduce future years’ income taxes payable.

- PAGE 44 -

12. RELATED PARTY TRANSACTIONS

A director of the Company is a partner of a law firm that was paid $2,150,000 for legal services for the period from the date elected as a director, April 3, 2003, to December 31, 2003. The fees charged were based on standard rates and time spent on company matters.

13. FINANCIAL INSTRUMENTS

(a) Fair Value

The Company has financial instruments consisting of accounts receivable, investments, accounts payable and bank loans. The carrying value of these instruments approximates fair value unless otherwise stated.

     Pursuant to the exercise of the option to purchase the W4M Properties (Note 4), the Company acquired an interest in forward sales contracts and financial hedging contracts with respect to production from the purchased properties as follows:

Transaction Type	Volume (GJ/D)			Contract Price (GJ/D)			Expiry
Costless Collar		4,830			$6.36 – $7.15		March 31, 2004
Fixed		1,610			$6.76		March 31, 2004
Cogeneration Fuel Supply		263			$1.959 – $2.217		October 31, 2008
Daily Declining Profile		841	(1)		Netback	(2)	October 31, 2011
Reserve Based		101			Netback	(3)	Life of reserves

     Based on dealer quotes, had these contracts been closed on December 31, 2003, a loss of $1,467,000 would have been realized.

Notes:

⁽¹⁾ The Company’s obligations under this contract will, on November 1 of each succeeding year, decline to the following:

Date	Obligation (GJ/D)
November 1, 2004		724
November 1, 2005		623
November 1, 2006 and thereafter		568

⁽²⁾ TransCanada Pipelines Limited netback pricing.

⁽³⁾ Progas Limited netback pricing.

     The following financial hedging contracts were entered into subsequent to December 31, 2003:

Transaction Type	Volume (GJ/D)		AECO Price (GJ/D)		Term
Collar		5,000	$	5.50 – $6.35	April 1, 2004 to October 31, 2004
Collar		8,000	$	5.50 – $6.40	April 1, 2004 to October 31, 2004
Collar		5,000	$	5.50 – $6.36	April 1, 2004 to October 31, 2004
Fixed Price Swap		5,000		$5.745	April 1, 2004 to June 30, 2004
Fixed Price Swap		5,000		$5.745	August 1, 2004 to October 31, 2004
Fixed Price Swap		5,000		$5.7725	April 1, 2004 to October 31, 2004

(b) Credit Risk

A substantial portion of the Company’s accounts receivable are with entities in the oil and gas industry. The Company generally extends unsecured credit to these companies, and therefore, the collection of accounts receivable may be affected by changes in economic or other conditions and may accordingly impact the Company’s overall credit risk. Management believes the risk is mitigated by the size, reputation and diversified nature of the companies to which they extend credit. The Company has not previously experienced any material credit losses on the collection of receivables.

- PAGE 45 -

(c) Interest Rate Risk

The Company is exposed to interest rate risk in relation to interest expense on its revolving credit facility and non-revolving bridge facility.

14. SUPPLEMENTAL DISCLOSURE OF CASH FLOW INFORMATION

     Changes in non-cash working capital were comprised of the following:

	2003			2002
Accounts receivable	$	(11,550	)	$	35
Prepaids and other current assets		(1,669	)		(23	)
Investments		(2,500	)		–
Accounts payable and accrued liabilities		23,670			(4,791	)
Less working capital deficiency on acquisitions		(1,513	)		–
Net change	$	6,438		$	(4,779	)
Net change by activity:
Operating	$	5,660		$	(4,779	)
Investing		806			–
Financing		(28	)		–
Net change	$	6,438		$	(4,779	)

     Additional information:

	2003		2002
Cash interest paid		495		71
Cash taxes paid		–		10

15. CONTINGENCIES

The Company, in the normal course of operations, is subject to a variety of legal and other claims against the Company. Management and the Company’s legal counsel evaluate all claims on their apparent merits, and accrue management’s best estimate of the likely costs to satisfy such claims. Management believes that the outcome of legal and other claims filed against the Company will not have a significant impact on the Company’s financial position, operations or cash flows.

     The Company indemnifies its directors and officers against any and all claims or losses reasonably incurred in the performance of their service to the Company to the extent permitted by law. The Company has acquired and maintains liability insurance for its directors and officers.

16. COMMITMENTS

The Company has committed to purchase seismic data in the amount $225,000 during the first six months of 2004.

     The Company is committed to payments under operating leases for office space as follows:

2004	$	611
2005		718
2006		413
2007		385
2008		385
	$	2,512

17. SUBSEQUENT EVENTS

On March 17, 2004, the Company acquired 100 percent of the shares of Zorin Exploration Ltd. for aggregate consideration of $7.4 million, comprising $1.5 million of cash and $5.9 million of equity representing 1,150,000 common shares.

- PAGE 46 -

Corporate Information

OFFICERS
David Tuer
President and Chief Executive Officer

Terry Schmidtke
Senior Vice President and Chief Operating Officer

Barry Herring
Senior Vice President and Chief Financial Officer

Laureen Little
Vice President, Engineering and Operations

Joe Straka
Director, Exploration

Lesley Miller
Controller

DIRECTORS
Ronald Mathison
Chairman of the Board
President and CEO, Matco Investments Ltd.

Martin Lambert
Partner, Bennett Jones LLP

Stan Grad
Chairman of the Reserves Committee
Former President and CEO,
Grad & Walker Energy Corporation

Bruce Kenway
Chairman of the Audit Committee
Founding Member,
Kenway Mack Slusarchuk Stewart LLP

Keith Smith
President and CEO, zed.i Solutions

David Tuer
President and CEO, Hawker Resources Inc.

ENGINEERING CONSULTANTS
McDaniel & Associates Consultants Ltd.
Calgary, Alberta

Gilbert Laustsen Jung Associates Ltd.
Calgary, Alberta

LEGAL COUNSEL
Bennett Jones LLP
Calgary, Alberta

AUDITORS
Ernst & Young LLP
Chartered Accountants
Calgary, Alberta

BANKER
Canadian Imperial Bank of Commerce
Calgary, Alberta

REGISTRAR AND TRANSFER AGENT
Computershare Trust Company of Canada
Calgary, Alberta

STOCK EXCHANGE LISTING
The Toronto Stock Exchange
Trading Symbol “HKR”

HEAD OFFICE
700, 700 – 2nd Street SW
Calgary, Alberta T2P 2W1
Telephone: (403) 261-6883
Facsimile: (403) 266-1814
E-mail: info@hawkerinc.com
Website: www.hawkerinc.com

FOR FURTHER INFORMATION CONTACT:
David Tuer
President and Chief Executive Officer
Telephone: (403) 290-4873

Barry Herring
Senior Vice President and Chief Financial Officer
Telephone: (403) 290-4856

ANNUAL MEETING
The Annual and Special Meeting of Shareholders will
be held at 10:00 a.m. on Wednesday, April 28, 2004,
in the Conference Centre of First Canadian Centre,
350 – 7th Avenue SW, Calgary, Alberta. All shareholders
are cordially invited and encouraged to attend.

Designed and Produced by Result Inc.
Printed in Canada

EX-5

Exhibit 5

RESOURCES INC.

ANNUAL INFORMATION FORM

March 17, 2004

HAWKER RESOURCES INC.
ANNUAL INFORMATION FORM

TABLE OF CONTENTS

GLOSSARY OF TERMS		1
ABBREVIATIONS		2
CONVERSION		2
FORWARD-LOOKING STATEMENTS		2
HAWKER RESOURCES INC		4
	Organization and Structure	4
GENERAL DEVELOPMENT		4
	Business of the Corporation	4
	History	4
	Significant Acquisitions and Dispositions	7
	Business Strategy	7
PRINCIPAL PROPERTIES		7
	Summary of Properties	7
	Drilling Activity	10
	Location of Wells	11
	Land Holdings	11
	Production	11
	Selected Reserve Information	12
	Reconciliation of Reserves	17
	Additional Information Relating to Reserves Data	17
	Other Oil And Gas Information	18
BORROWINGS		21
INDUSTRY CONDITIONS		21
	Canadian Government Regulation	21
	Pricing and Marketing — Oil	22
	Price and Marketing — Natural Gas	22
	The North American Free Trade Agreement	22
	Royalties and Incentives	22
	Land Tenure	23
	Environmental Regulation	24
RISK FACTORS		24
	Exploration, Development and Production Risks	24
	Insurance	24
	Prices, Markets and Marketing of Crude Oil and Natural Gas	25
	Substantial Capital Requirements; Liquidity	25
	Competition	25
	Environmental Risks	26
	Reserves Replacement	26
	Reliance on Operators and Key Employees	26
	Corporate Matters	26
	Permits and Licenses	27
	Additional Funding Requirements	27
	Issuance of Debt	27
	Availability of Drilling Equipment and Access Restrictions	27
	Title Defects	27
	Uncertainty of Reserve Information	27
	Kyoto Protocol	28
	Government Regulation and Taxation	28
SELECTED FINANCIAL INFORMATION		28
	Financial Results	28
	Average Prices	29
MANAGEMENT’S DISCUSSION AND ANALYSIS		29
MARKET FOR SECURITIES		29
DIRECTORS AND EXECUTIVE OFFICERS		30
CONFLICTS OF INTEREST		31
ADDITIONAL INFORMATION		31
APPENDIX A — FORMS 51-101F2 REPORT ON RESERVES DATA BY INDEPENDENT QUALIFIED RESERVES EVALUATORS		A-1
APPENDIX B — FORM 51-101F3 REPORT OF MANAGEMENT AND DIRECTORS ON OIL AND GAS DISCLOSURE		B-1

- i -

GLOSSARY OF TERMS

Capitalized terms in this Annual Information Form have the meanings set forth below:

“Annual Report” means the Annual Report of the Corporation for the year ended December 31, 2003;

“COGE Handbook” means the “Canadian Oil and Gas Evaluation Handbook”;

“Common Share” means a common share in the capital of the Corporation;

“GLJ” means Gilbert Laustsen Jung Associates Limited, independent petroleum engineers, Calgary, Alberta;

“GLJ Report” means the report prepared by GLJ dated March 8, 2004, setting forth certain information relating to certain of the oil and gas reserves of the Corporation’s properties and the present value of the estimated future net reserves associated with such reserves;

“Hawker” or “the Corporation” means Hawker Resources Inc., a corporation governed by the Business Corporations Act (Alberta);

“LIBOR” means London Interbank Offer Rate;

“McDaniel” means McDaniel and Associates Consultants Ltd., independent petroleum engineers, Calgary, Alberta;

“McDaniel Report” means the report prepared by McDaniel dated March 12, 2004, setting forth certain information relating to certain of the oil and gas reserves of the Corporation’s properties and the present value of the estimated future net reserves associated with such reserves;

“NGLs” means natural gas liquids;

“NI 51-101” means National Instrument 51-101 — Standards of Disclosure for Oil and Gas Activities;

“Oncolytics” means Oncolytics Biotech Inc.;

“Pointwest” means Pointwest Energy Inc., a corporation incorporated under the Business Corporations Act (Alberta);

“Purchase Option” means the option in favour of the Corporation to purchase an undivided interest of up to 49% in the Southward Properties at a purchase price based on an ascribed price, as at May 1, 2003 and subject to adjustment, of $136,900,000 for a 100% interest in the Southward Properties;

“Southward” means Southward Energy Ltd., a corporation incorporated under the Business Corporations Act (Alberta);

“Southward Properties” means all of the petroleum and natural gas rights and related assets of Southward other than those which are both west of the fifth meridian and in the Province of Alberta, which properties are located east of Edmonton in the Lavoy and Cold Lake/Bonnyville areas of Alberta and are described under the heading “Principal Properties — Summary of Properties — Lavoy and Cold Lake/Bonnyville”;

“Synsorb” means Synsorb Biotech Inc., as Hawker was named before it changed the focus of its business to oil and gas exploration and development;

“TSX” means The Toronto Stock Exchange;

“working interest” means the interest in a lease that carries with it the rights and obligations to develop and operate an oil or natural gas property;

“Year” means a calendar year; and

“Zorin” means Zorin Exploration Ltd., a corporation incorporated under the Business Corporations Act (Alberta);

Unless otherwise indicated, references herein to “$” or “dollars” are to Canadian dollars.

ABBREVIATIONS

Crude Oil and Natural Gas Liquids		Natural Gas
bbls	barrels	mcf	thousand cubic feet
bbls/d	barrels per day	mmcf	million cubic feet
mbbls	thousand barrels	bcf	billion cubic feet
boe boe/d	barrels of oil equivalent of natural gas and crude oil on the basis of 1 bbl of crude oil for 6 mcf of natural gas barrels of oil equivalent per day	mcf/d mmcf/d GJ GJ/d	thousand cubic feet per day million cubic feet per day gigajoules gigajoules per day
mboe	thousand boe
NGLs	natural gas liquids
mmbtu	million British thermal units
stb	standard stock tank barrel

CONVERSION

     In this Annual Information Form, certain measurements may be given in Standard Imperial or Metric Units only. The following table sets forth certain standard conversions:

To Convert From	To	Multiply By
mcf	cubic metres		28.174
cubic metres	cubic feet		35.494
barrels	cubic metres		0.159
cubic metres	barrels		6.293
feet	metres		0.305
metres	feet		3.281
miles	kilometers		1.609
kilometers	miles		0.621
acres	hectares		0.405
hectares	acres		2.471

FORWARD-LOOKING STATEMENTS

Certain statements contained in this Annual Information Form and in certain documents incorporated by reference into this Annual Information Form, constitute forward-looking statements. These statements relate to future events or the Corporation’s future performance. All statements other than statements of historical fact may be forward-looking statements. Forward-looking statements are often, but not always, identified by the use of words such as “seek”, “anticipate”, “plan”, “continue”, “estimate”, “expect, “may”, “will”, “project”, “predict”, “potential”, “targeting”, “intend”, “could”, “might”, “should”, “believe” and similar expressions. These statements involve known and unknown risks, uncertainties and other factors that may cause actual results or events to differ materially from those anticipated in such forward-looking statements. The Corporation believes that the expectations reflected in those forward looking statements are reasonable but no assurance can be given that these expectations will prove to be correct and such forward-looking statements included in, or incorporated by reference into, this Annual Information Form should not be unduly relied upon. These statements speak only as of the date of this Annual Information Form or as of the date specified in the documents incorporated by reference into this Annual Information Form, as the case may be. The Corporation does not intend, and does not assume any obligation, to update these forward-looking statements.

- 2 -

In particular, this Annual Information Form and the documents incorporated by reference contain forward-looking statements pertaining to the following:

• the quantity of reserves;

• oil and natural gas production levels;

• capital expenditure programs;

• projections of market prices and costs;

• supply and demand for oil and natural gas;

• expectations regarding the Corporation’s ability to raise capital and to continually add to reserves through acquisitions and development; and

• treatment under governmental regulatory and taxation regimes.

The Corporation’s actual results could differ materially from those anticipated in these forward-looking statements as a result of the risk factors set forth below and elsewhere in this Annual Information Form:

• volatility in market prices for oil and natural gas;

• liabilities and risks inherent in oil and natural gas operations;

• uncertainties associated with estimating reserves;

• competition for, among other things, capital, acquisitions of reserves, undeveloped lands and skilled personnel;

• incorrect assessments of the value of acquisitions; and

• geological, technical, drilling and processing problems.

- 3 -

HAWKER RESOURCES INC.

Organization and Structure

The Corporation was incorporated as 599386 Alberta Ltd. under the Business Corporations Act (Alberta) on February 14, 1994 and changed its name to SYNSORB Biotech Inc. on March 31, 1994. Effective May 8, 2002: (i) each former holder of common shares of the Corporation received one new common share for each eight cancelled common shares previously held by such holder, (ii) the stated capital of the Corporation was reduced in respect of the common shares of the Corporation by $59,896,000, and (iii) 4,000,235 common shares of Oncolytics Biotech Inc. held by the Corporation were distributed to its shareholders. By articles of amendment filed on April 3, 2003, the name of the Corporation was changed to Hawker Resources Inc. and a new class of non-voting equity shares was created. On December 30, 2003, each of Pointwest and its wholly-owned subsidiary, Myriad Corporation, and the Corporation amalgamated pursuant to the provisions of the Business Corporations Act (Alberta) under the name Hawker Resources Inc. On December 31, 2003, 1053639 Alberta Ltd., a wholly-owned subsidiary of the Corporation, and the Corporation amalgamated pursuant to the provisions of the Business Corporations Act (Alberta) under the name Hawker Resources Inc.

The head office of the Corporation is located at 700, 700 – 2nd Street S.W., Calgary, Alberta, T2P 2W1, and the registered office is located at 4500, 855 – 2nd Street S.W., Calgary, Alberta, T2P 4K7.

GENERAL DEVELOPMENT

Business of the Corporation

Hawker is an Alberta based corporation engaged in the business of exploring for and developing oil and natural gas reserves in western Canada and acquiring oil and natural gas properties. Hawker currently owns approximately 184,929 net acres of undeveloped land focused in six core areas in Alberta and British Columbia, and as of December 31, 2003 had approximately 5,800 to 6,000 boe/d of production.

Hawker intends to build an asset base within a target area covering northeastern British Columbia and extending southeast to the southern Alberta prairies by means of acquisition and land purchase opportunities. Consistent with this strategy, on March 17, 2004, the Corporation acquired all the issued and outstanding shares of Zorin by way of a formal take-over bid. See “History — Acquisition of Zorin Exploration Ltd.”

As at December 31, 2003, the Corporation employed 15 people, none of which are unionized.

History

     Acquisition of Zorin Exploration Ltd.

On March 17, 2004, Hawker acquired all of the issued and outstanding common shares of Zorin for an aggregate purchase price of a cash payment of approximately $1.5 million and the issuance by Hawker of 1,150,000 Common Shares. Prior to such acquisition, Zorin was a publicly-traded junior oil and natural gas exploration company based in Calgary, Alberta with activities in Alberta, Saskatchewan, Ontario and Ohio. Zorin’s average production for 2003 was approximately 218 bbls/d of oil and NGLs and 924 mcf/d of natural gas. The majority of the production from the properties in which Zorin has an interest are operated by Zorin.

The Corporation currently intends to continue the business carried on by Zorin in the Granlea, Alberta area and vigorously exploit and develop this property and properties adjacent to Granlea in which Hawker has a working interest. The Corporation may, however, determine to sell all or any portion of remaining properties in which Zorin has an interest and may also choose to operate and exploit such properties in a manner different from that of Zorin. Hawker also intends to amalgamate Zorin into the Corporation pursuant to the provisions of the Business Corporations Act (Alberta).

- 4 -

     Acquisition of Pointwest Energy Inc. and Prospectus Offering

On December 30, 2003, Hawker acquired all of the issued and outstanding common shares of Pointwest for an aggregate purchase price of approximately $88 million, inclusive of debt. Prior to such acquisition, Pointwest was an oil and natural gas exploration and production company based in Calgary, Alberta with an asset base within an area primarily in northeastern British Columbia. See “Principal Properties — Summary of Properties — North Boundary and Valhalla.”

Concurrent with the completion of the acquisition of Pointwest, the Corporation closed a short form prospectus equity financing of 11,200,000 Common Shares at a price of $4.05 per share for gross proceeds of $43,360,000. The net proceeds from this equity financing were used to partially finance the Corporation’s acquisition of all of the shares of Pointwest. The balance of the funds required to complete the acquisition were advanced to the Corporation under an expanded credit facility with the Canadian Imperial Bank of Commerce. Effective December 30, 2003, each of Pointwest and Myriad Corporation, its wholly-owned subsidiary, was amalgamated into the Corporation pursuant to the provisions of the Business Corporations Act (Alberta).

     Completion of Private Placement

On December 5, 2003, Hawker completed a private placement of 2,900,000 flow-through Common Shares at a price of $5.25 per share for gross proceeds of $15,225,000. Hawker agreed to renounce to subscribers under this private placement “Canadian Exploration Expense” as defined in the Income Tax Act (Canada) (the “Tax Act”) in the aggregate amount of $15,225,000 with an effective date, for income tax purposes, of on or before December 31, 2003.

     Acquisition of 1053638 Alberta Ltd. and 1053639 Alberta Ltd.

On August 14, 2003, the Corporation acquired all of the shares of 1053638 Alberta Ltd. and 1053639 Alberta Ltd., seismic data companies, for an aggregate consideration equal to $1,500,000. On August 19, 2003, the Corporation subsequently sold all of the shares of 1053638 Alberta Ltd. for $300,000.

     Acquisition of Southward and the Southward Properties and Equity Financing

In early March 2003, 1022971 Alberta Ltd. entered into an agreement with a third party which provided, as amended, that in the event that 1022971 Alberta Ltd. was successful in purchasing all of the common shares of Southward, the third party would purchase all of the petroleum and natural gas rights and related assets of Southward, except for a 1% interest in the Southward Properties and 100% of the seismic data relating to the Southward Properties, for a purchase price equal to $164,631,000, of which $135,531,000 was allocated for internal purposes to a 99% interest in the Southward Properties.

In mid-March 2003, Hawker was granted an option to purchase (the “Purchase Option”) an undivided interest of up to 49% in the Southward Properties at a purchase price, subject to adjustment, equal to $1,369,000 for each 1% undivided interest in the Southward Properties.

On March 16, 2003, 1022971 Alberta Ltd. entered into an arrangement agreement with Southward which contemplated that, subject to the terms and conditions of the agreement, 1022971 Alberta Ltd. and Southward would implement an arrangement (the “Arrangement”) in accordance with the Business Corporations Act (Alberta), whereby, amongst other things, shareholders of Southward would transfer all of the outstanding common shares to 1022971 Alberta Ltd. in consideration for $4.77 per share.

As a pre-condition to 1022971 Alberta Ltd. entering into the arrangement agreement, Southward agreed that, at the direction of 1022971 Alberta Ltd., it would enter into fixed price forward sales contracts in respect of up to 12,875 GJ/d of gas production from the Southward Properties. On March 17, 2003, Southward entered into forward sales contracts in respect of an aggregate of 12,880 GJ/d for the balance of 2003 and the first quarter of 2004.

- 5 -

On March 31, 2003, the Corporation acquired all of the shares of 1022971 Alberta Ltd. for an aggregate consideration of $1.00.

At the annual and special meeting of the shareholders of the Corporation held on April 3, 2003 a new board of directors was elected, including the appointment of David Tuer as the new President and Chief Executive Officer of the Corporation, and the shareholders approved, among other things: (i) the equity financing, (ii) the creation of class A shares, and (iii) the name change to Hawker Resources Inc.

On April 3, 2003, the Corporation completed an equity financing of 223,798 Common Shares and 430,493 units by way of a long form prospectus for aggregate proceeds of approximately $3.7 million. These units were converted into an aggregate of 6,026,902 Common Shares on May 29, 2003. During the period of March 13, 2003 to April 3, 2003, all outstanding in-the-money stock options were exercised, resulting in the issuance of an additional 275,000 Common Shares for aggregate proceeds of $192,000.

On April 28, 2003 the Arrangement was approved by the shareholders and optionholders of Southward and also by the Court of Queen’s Bench of Alberta. On April 30, 2003, 1022971 Alberta Ltd. acquired all of the shares of Southward in accordance with the provisions of the Arrangement. Immediately thereafter, Southward sold its oil and gas properties, excluding a 1% undivided interest in the Southward Properties and a 100% interest in seismic data, to an independent third party, for consideration equal to $164,631,000.

On June 30, 2003, the Corporation exercised the Purchase Option and, accordingly, acquired a 49% interest in the Southward Properties, and also purchased the 1% undivided interest in the Southward Properties. At this time, the non-cash working capital of Southward was conveyed to the Corporation.

All of the shares of 1022971 Alberta Ltd (including its wholly-owned subsidiary, Southward, and all other subsidiaries) were sold for nominal consideration by the Corporation to an independent third party on June 30, 2003.

     Prior Business: Biotechnology

Prior to December 10, 2001, the Corporation was a biotechnology company focusing primarily on the discovery and development of pharmaceutical products for gastroenteric diseases or conditions which could benefit from new or additional therapies. On that date, the Corporation announced that it was terminating the clinical trials of its remaining product and would consider future strategic alternatives. In the following months, the Corporation reduced its expenditure rate, laid off executives and staff and reviewed alternatives for maximizing shareholder value.

Over the course of the fiscal year ended December 31, 2002, the Corporation divested itself of its position in Oncolytics by distributing 4,000,235 of such shares to its shareholders and by selling 2,255,565 of such shares through the TSX for aggregate gross proceeds of $6,898,000. During that period, the Corporation completed staff reductions and the winding-down of its clinical trials and continued to evaluate strategic alternatives. The Corporation held discussions with several industry parties in an attempt to reach a transaction with another pharmaceutical entity that would make use of the Corporation’s technology and its specialized manufacturing plant and equipment. These discussions did not lead to the Corporation receiving any acceptable proposals for such a transaction.

On October 30, 2002, the Corporation retained Network Capital Inc. as its financial advisor to seek a transaction to maximize value for shareholders, including pursuing transactions that would substantially reorganize the business of the Corporation.

In the fall of 2002, the Corporation determined to dispose of its pharmaceutical manufacturing equipment and to list its manufacturing plant for sale as commercial premises. In January 2003, the Corporation sold its equipment for approximately $940,000 in net proceeds and, in February 2003, the Corporation granted a third party an exclusive license to certain of its patents relating to toxin binding sugars for net proceeds of U.S. $240,000.

- 6 -

Significant Acquisitions and Dispositions

Each of the significant acquisitions and dispositions of the Corporation are disclosed above under “General Development — History”.

Business Strategy

Vision.    The Corporation’s primary ongoing business objective is to become a full cycle oil and gas company with a dual focus on exploration and development activities and on an active acquisition strategy, with a particular emphasis on natural gas opportunities.

Drilling Program.    Management intends to employ an active exploration program to seek out additional areas to add to the Corporation’s production and opportunity inventory.

Responsible Fiscal Management.    Approximately 50% of the Corporation’s anticipated cash flow will be directed towards the replacement of existing reserves, leaving a significant amount of cash flow available for a focused exploration program or to pay down debt. The Corporation strives to add value through its drilling and exploration activities and carefully manages its costs, thereby positioning itself to add to its inventory of opportunities and undeveloped land holdings.

Prudent Use of Equity.    Management recognizes that, at this early stage of development, equity must be used sparingly, and it intends to rely heavily on operational revenues and debt financing to satisfy liquidity requirements. The Corporation will attempt to minimize the dilution that would be caused to existing shareholders if large amounts of equity were issued.

PRINCIPAL PROPERTIES

Summary of Properties

The following is a description of the Corporation’s six principal properties on production or under development.

     Lavoy

The Lavoy area is located approximately 100 kilometres east of Edmonton in a well-developed natural gas-prone portion of the Western Canada Sedimentary Basin. Hawker does not operate the property, but owns a 45% average working interest in this property’s land, facilities, and production which from July 1 to December 31, 2003 averaged 14.4 mmcf/d. Hawker has ownership of a large undeveloped land base totaling 142,043 net acres (290,169 gross acres). Geologically, the property is characterized by 14 multi-stacked prospective horizons where hydrocarbons have been proven to exist. Hawker also has a working interest position in 10 processing facilities in the area with gross cumulative capacity of 40 mmcf/d.

In 2003, Hawker increased its net land position at Lavoy by purchasing approximately 3,500 net undeveloped acres through Crown land sales. During the year, Hawker participated in the drilling of 31 natural gas wells of which 23 were cased. As at December 31, 2003, only 12 of these wells had been connected into processing facilities and/or pipelines. The Corporation and the Lavoy operator are taking steps to accelerate the tie-in process.

Hawker and its partner negotiated a farm-in on additional lands with a major operator in the Lavoy region. Drilling success on these lands will increase Hawker’s land position in 2004.

With a large undeveloped land base, geologically multi-stacked prospective horizons, access to processing facilities and compression, Lavoy is Hawker’s largest core area and one where the Corporation intends to grow its base production and expand operations.

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     Cold Lake/Bonnyville

The Cold Lake/Bonnyville property is located approximately 80 kilometres south of the Cold Lake Air Weapons Range in North Central Alberta. The Cold Lake/Bonnyville property falls outside of the restrictive gas over bitumen area ordered by the Alberta Energy Utilities Board (“EUB”). While Hawker’s drilling operations on the property have not been affected by the order, tie-in and production delays have been experienced.

Hawker assumed operatorship of this property in September 2003 and operates an average of 8 mmcf/d of natural gas production. Net production in 2003 was 2.0 mmcf/d which reflects Hawker’s average 25% working interest in Cold Lake/Bonnyville. Hawker has a solid land position in the area totaling some 12,840 net acres including 4,320 undeveloped net acres (10,240 gross acres). The property consists of 29 well sites and one production facility. Similar to the Lavoy area, Cold Lake’s geology is multi-stacked with five prospective hydrocarbon-bearing horizons.

Two natural gas wells were drilled and connected to processing facilities in late 2003. The wells will begin producing in the first half of 2004 after receiving regulatory approval. Since assuming operatorship, Hawker spent the remainder of 2003 reviewing all aspects of this area in detail: facility capacity, geologic potential, mineral rights availability, as well as possible competition from third-party operators. Hawker is encouraged by the gas exploitation upside of the Cold Lake/Bonnyville area and its potential for contribution to the Corporation’s future growth.

     North Boundary

The North Boundary project is located 55 kilometres northeast of Fort St. John in British Columbia. Hawker acquired this property through its acquisition of Pointwest on December 30, 2003. The assets in this region fit well within Hawker’s identified area of interest. The development of the project is in its infancy and it offers Hawker a base for future low risk expansion as well as exploration potential. The Corporation will be focused on exploiting production from this core region for the next several years. Hawker has an average 85% working interest in the 42,000 acre land block, which comprises 25,993 net acres of undeveloped land. Production at December 31, 2003 was approximately 3,100 boe/d, comprising 17 mmcf/d of natural gas and 240 bbls/d of oil and NGLs. Hawker operates 22 natural gas producing wells, and has a 100% working interest in the North Boundary gas processing facility, which has a capacity of 28 mmcf/d of sour gas, 6 mmcf/d of sweet gas and 600 barrels per day of oil and NGLs. At North Boundary, hydrocarbons are produced from eight prospective horizons to a depth of approximately 1,300 metres.

As of year-end, more than 25 prospective locations for exploration or development drilling were identified. With current 3D seismic coverage over the majority of the property, and more seismic to be added in 2004, Hawker expects to expand its presence and production in the area. Hawker believes North Boundary will be a key asset in fuelling the Corporation’s growth in 2004.

The Corporation is currently in the process of transferring the permits registered in the name of Pointwest to Hawker in respect of the North Boundary property

     Valhalla

The Valhalla property is located 160 kilometres northwest of Grande Prairie, in north central Alberta. Its multiple geological targets are found at a depth of approximately 1,800 metres in the Cretaceous formations common to Alberta production. Hawker currently has a working interest in 1,940 gross acres with a rolling option farmin on an additional 4,160 gross acres granted by a major resource company.

Three producing wells have been drilled on Hawker’s acreage. The wells have been connected to third party processing facilities in the area. Production at December 31, 2003 was 220 barrels per day, comprising 1 mmcf/d of natural gas and 55 boed/d of oil and NGLs. Two standing wells which have been drilled but are not yet tied into pipelines are expected to be brought on production in 2004. Several re-completion opportunities have also been identified and could be started in 2004.

- 8 -

The surrounding area is dominated by several large oil and gas companies, and offers Hawker limited opportunities for growth beyond 2004. As a result the Corporation will evaluate future plans for this property, including a possible exchange or sale.

     Chigwell

Chigwell is a grassroots exploration prospect that was developed by Hawker in the second half of 2003. Hawker has reviewed more than 100 existing well data sets to identify the Chigwell opportunity. Hawker acquired its land position at Chigwell in the third quarter of 2003, with two exploration wells subsequently drilled and cased. Both of these wells tested at commercial flow rates of natural gas from the Basal Quartz/Ellerslie horizon.

This area is well developed in terms of infrastructure, and Hawker has initiated discussions with third party facility operators regarding access to available processing and gathering capacity. Hawker plans to drill two follow-up well locations in early 2004 in conjunction with additional land and seismic data acquisitions.

The Chigwell area is viewed as an emerging focus area for Hawker. The project exemplifies Hawker’s ability to identify drilling opportunities and exploit them quickly.

     Purple Springs

At Purple Springs in southern Alberta, Hawker farmed in on 6,400 gross acres of land where the Corporation plans to drill and tie in 15 wells by June 30, 2004 to earn a 50% working interest position. The program will capitalize on Hawker’s significant technical experience in developing shallow Medicine Hat gas sands throughout southern Alberta. Future opportunities for the block and offsetting lands involve infill drilling, and gathering and processing of third party natural gas through the facilities Hawker will develop in this area. Exploration prospects for deeper targets in the Viking, Sunburst, and Sawtooth formations may be evaluated as part of the 2004 drilling program.

     Wild River Prospect

The Wild River project is non-operated and constitutes a significant part of Hawker’s 2004 high risk exploration portfolio. Hawker has a 20% working interest in five sections of land as well as the associated seismic coverage. The Wild River prospect is a Nisku pinnacle reef on trend with existing pinnacle reef production to the south. The feature was identified by seismic re-processing and as mapped could have significant gas-in-place relative to the analogous pinnacles in the area. The well located at 8-14-57-23 W5M was spudded in December 2003 and at year-end was drilling forward. Subsequent to year-end the well was cased and is currently being evaluated by Hawker and its partners.

     Other

In conjunction with Hawker’s acquisition of Southward on April 30, 2003, the Corporation acquired access to a large seismic database covering northeast British Columbia, and extending southeast to the southern Alberta prairies. The database included some 1,250 kilometres of 2D seismic data and 2,750 square kilometres of 3D seismic information. Hawker’s exploration teams have extensively reviewed and re-processed certain data to develop an inventory of potential exploration prospects. Land acquisition strategies have been developed for these prospects and in some cases land has been acquired. Hawker expects to drill two of these prospects in early 2004, and will continue evaluation and land acquisition of the others.

In addition to North Boundary and Valhalla, 10 minor properties were acquired as part of the Pointwest acquisition. The properties are all non-operated with an average working interest of 30%. Net production at December 31, 2003 from the combined properties was 1.8 mmcf/d of natural gas and 22 bbls/d of oil and NGLs. Subsequent to December 31, 2003 and following an evaluation of the properties’ exploitation potential, the Corporation reached an agreement to sell these properties, with the closing expected at the end of the first quarter of 2004.

- 9 -

Drilling Activity

The following table sets forth the number of gross and net exploratory and development wells in which the Corporation has participated during the periods indicated.

		Year Ended December 31(1)
		2003
		Gross Wells(2)		Net Wells(3)
Exploratory
	Natural Gas		5		3.0
	Crude Oil		—		—
	Dry and Abandoned(4)		1		0.5
Total Exploratory			6		3.5
Development
	Natural Gas		20		9.6
	Crude Oil		2		1.0
	Dry and Abandoned(4)		7		3.5
Total Development			29		14.1
Total Drilling Activity			35		17.6

Notes:

(1)	Prior to June 2003, the Corporation was not engaged in the exploration, development or production of oil or gas and did not hold any interests in any oil or gas properties.
(2)	“Gross wells” means the total number of wells in which the Corporation has an interest.
(3)	“Net wells” means the number of gross wells multiplied by the Corporation’s working interest therein.
(4)	“Dry well” means a well which is not a productive well or a service well. A productive well is a well which is capable of producing oil and gas in commercial quantities or in quantities considered by the operator to be sufficient to justify the costs required to complete, equip and produce the well. A service well means a well such as a water or gas-injection, water-source or water-disposal well. Such wells do not have marketable reserves of crude oil or natural gas attributed to them but are essential to the production of the crude oil and natural gas reserves.

- 10 -

Location of Wells

The following table sets forth the Corporation’s interest in producing wells and wells capable of producing as at December 31, 2003.

	Wells(1)
	Producing				Shut-in(4)
Property	Gross(2)		Net(3)		Gross(2)		Net(3)
Lavoy		170		76.5		24		10.8
North Boundary		23		16.1		—		—
Cold Lake/Bonnyville		25		9.3		12		4.8
Valhalla		4		3.2		1		0.7
Other		35		8.0		3		2.0
Total		257		113.1		40		18.3

Notes:

(1)	Prior to June 2003, the Corporation was not engaged in the exploration, development or production of oil or gas and did not hold any interests in any oil or gas properties.
(2)	“Gross wells” means the total number of wells in which the Corporation has an interest.
(3)	“Net wells” means the number of gross wells multiplied by the Corporation’s working interest therein.
(4)	“Shut-in Wells” are wells which are capable of economic production or which the Corporation considers capable of production but which, for a variety of reasons, including but not limited to lack of markets or development, are not currently on production.

Land Holdings

The following table summarizes the undeveloped land of the Corporation as at December 31, 2003.

Property	Gross Acres(1)		Net Acres(2)
Lavoy		290,169		142,043
Cold Lake/Bonnyville		10,240		4,320
North Boundary		28,710		25,993
Valhalla		640		640
Chigwell		960		960
Wild River		3,200		640
Other		16,464		10,333
Total		350,383		184,929

Notes:

(1)	“Gross Acres” means the total acres in which the Corporation has an interest.
(2)	“Net Acres” means the total acres in which the Corporation has an interest multiplied by the working interest therein.

Production

     Average Daily Production Volumes

Prior to June 2003, the Corporation was not engaged in the exploration, development or production of oil or gas and did not hold any interests in any oil or gas properties.

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The average daily production volumes for the Corporation for 2003 are set out below.

	2003
	3rd Quarter		4th Quarter		Annual Average
Natural Gas (mmcf/d)		16.7		16.2		16.3
Price ($/mcf)		5.81		5.88		5.84
Royalties		1.57		1.21		1.40
Production Costs		0.55		0.80		0.67
Netback		3.69		3.87		3.77

Selected Reserve Information

The following tables set forth certain information relating to the oil and natural gas reserves of the Corporation’s properties and the present value of the estimated future net cash flow associated with such reserves as at December 31, 2003. The information set forth below is derived from the McDaniel Report and the GLJ Report which have been prepared in accordance with the standards contained in the COGE Handbook and the reserves definitions contained in NI 51-101 and the COGE Handbook. All evaluations and reviews of future net cash flow are stated prior to any provision for interest costs or general and administrative costs and after the deduction of estimated future capital expenditures for wells to which reserves have been assigned. It should not be assumed that the estimated future net cash flow shown below is representative of the fair market value of the Corporation’s properties. There is no assurance that such price and cost assumptions will be attained and variances could be material. The recovery and reserve estimates of crude oil, NGLs and natural gas reserves provided herein are estimates only and there is no guarantee that the estimated reserves will be recovered. Actual crude oil, NGLs and natural gas reserves may be greater than or less than the estimates provided herein.

The Corporation has a reserves committee of independent board members which reviews the qualifications and appointment of the independent qualified reserves evaluators. The committee also reviews the procedures for providing information to the evaluators. All booked reserves are based upon annual evaluation and review by the independent qualified reserves evaluators.

In accordance with the requirements of NI 51-101, the Report on Reserves Data by Independent Qualified Reserves Evaluator in Form 51-101 F2 and the Report of Management and Directors on Oil and Gas Disclosure in Form 51-101 F3 are attached as Appendices A and B hereto, respectively.

SUMMARY OF OIL AND GAS RESERVES
AND NET PRESENT VALUES OF FUTURE NET REVENUE
as of December 31, 2003

CONSTANT PRICES AND COSTS

		RESERVES
		LIGHT AND				NATURAL				NATURAL GAS
		MEDIUM OIL				GAS				LIQUIDS
		Gross		Net		Gross		Net		Gross		Net
RESERVES CATEGORY		(mbbl)		(mbbl)		(mmcf)		(mmcf)		(mbbl)		(mbbl)
Proved
	Developed Producing		164.5		156.2		30,857.9		23,397.4		135.1		105.0
	Developed Non-Producing		13.3		13.0		7,255.8		5,490.3		23.3		17.3
	Undeveloped		42.5		31.4		885.1		619.3		3.5		2.1
Total Proved			220.3		200.6		38,998.8		29,507.0		161.9		124.4
Probable			68.9		64.9		11,540.5		8,742.7		40.3		30.8
Total Proved Plus Probable			289.2		265.5		50,539.3		38,249.7		202.2		155.2

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		NET PRESENT VALUES OF FUTURE NET REVENUE
		BEFORE INCOME TAXES DISCOUNTED AT										AFTER INCOME TAXES DISCOUNTED AT
		(%/year)										(%/year)
RESERVES		0		5		10		15		20		0		5		10		15		20
CATEGORY		(MM$)		(MM$)		(MM$)		(MM$)		(MM$)		(MM$)		(MM$)		(MM$)		(MM$)		(MM$)
PROVED
	Developed Producing		126,270		109,435		97,321		88,117		80,845		126,270		109,435		97,321		88,118		80,846
	Developed Non-Producing		26,674		24,004		21,868		20,118		18,656		26,675		24,004		21,868		20,118		18,656
	Undeveloped		2,859		2,250		1,794		1,449		1,183		2,858		2,250		1,794		1,449		1,183
Total proved			155,803		135,689		120,983		109,684		100,684		155,803		135,689		120,983		109,685		100,685
Probable			45,705		34,607		27,591		22,754		19,233		39,644		29,688		23,544		19,385		16,398
Total Proved Plus Probable			201,508		170,296		148,574		132,438		119,917		195,447		165,377		144,527		129,070		117,083

TOTAL FUTURE NET REVENUE
(UNDISCOUNTED)
as of December 31, 2003

CONSTANT PRICES AND COSTS

Future

Future

Net

Net

Revenue

Revenue

Well

Before

After

Operating

Development

Abandonment

Income

Income

Income

Reserves

Revenue

Royalties

Costs

Costs

Costs

Taxes

Taxes

Taxes

Category

(M$)

(M$)

(M$)

(M$)

(M$)

(M$)

(M$)

(M$)

Proved Reserves

249,009

56,310

28,198

3,575

5,123

155,803

0

155,803

Proved Plus Probable Reserves

322,286

72,641

36,227

6,696

5,214

201,508

6,061

195,447

FUTURE NET REVENUE
BY PRODUCTION GROUP
as of December 31, 2003

CONSTANT PRICES AND COSTS

		FUTURE NET REVENUE
		BEFORE INCOME TAXES & ARTC
RESERVES		(discounted at 10%/year)
CATEGORY	PRODUCTION GROUP	(M$)
Proved Reserves	Light and Medium Crude Oil (including solution gas and other by-products)		373
	Natural Gas (including by-products but excluding solution gas from oil wells)		108,193
Proved Plus Probable Reserves	Light and Medium Crude Oil (including solution gas and other by-products)		766
	Natural Gas (including by-products by excluding solution gas from oil wells)		132,820

- 13 -

SUMMARY OF OIL AND GAS RESERVES
AND NET PRESENT VALUES OF FUTURE NET REVENUE
as of December 31, 2003

FORECAST PRICES AND COSTS

		RESERVES
		LIGHT AND				NATURAL				NATURAL GAS
		MEDIUM OIL				GAS				LIQUIDS
		Gross		Net		Gross		Net		Gross		Net
Reserves Category		(mbbl)		(mbbl)		(mmcf)		(mmcf)		(mbbl)		(mbbl)
Proved
	Developed Producing		164.5		156.6		30,818.2		23,353.9		135.0		105.0
	Developed Non-Producing		13.3		13.0		7,249.8		5,482.3		23.4		17.3
	Undeveloped		42.5		32.3		885.1		620.3		3.5		2.1
Total proved			220.3		201.9		38,953.1		29,456.5		161.9		124.4
Probable			69.6		65.4		11,528.7		8,731.4		40.4		31.0
Total Proved Plus Probable			289.9		267.3		50,481.8		38,187.9		202.3		155.4

		NET PRESENT VALUES OF FUTURE NET REVENUE
		BEFORE INCOME TAXES DISCOUNTED AT										AFTER INCOME TAXES DISCOUNTED AT
		(%/year)										(%/year)
		0		5		10		15		20		0		5		10		15		20
Reserves Category		(MM$)		(MM$)		(MM$)		(MM$)		(MM$)		(MM$)		(MM$)		(MM$)		(MM$)		(MM$)
Proved
	Developed Producing		107,795		94,662		85,126		77,812		71,976		107,795		94,662		85,126		77,812		71,976
	Developed Non-Producing		22,300		20,323		18,706		17,358		16,214		22,300		20,323		18,706		17,358		16,214
	Undeveloped		1,867		1,472		1,159		917		728		1,867		1,473		1,159		917		728
Total proved			131,962		116,457		104,991		96,087		88,918		131,962		116,458		104,991		96,087		88,918
Probable			36,293		27,534		22,051		18,286		15,544		36,293		27,533		22,051		18,286		15,544
Total Proved Plus Probable			168,255		143,991		127,042		114,373		104,462		168,255		143,991		127,042		114,373		104,462

TOTAL FUTURE NET REVENUE
(UNDISCOUNTED)
as of December 31, 2003
 
FORECAST PRICES AND COSTS

Future

Future

Net

Net

Revenue

Revenue

Well

Before

After

Operating

Development

Abandonment

Income

Income

Income

Reserves

Revenue

Royalties

Costs

Costs

Costs

Taxes

Taxes

Taxes

Category

(M$)

(M$)

(M$)

(M$)

(M$)

(M$)

(M$)

(M$)

Proved Reserves

222,255

50,058

30,673

3,650

5,912

131,962

0

131,962

Proved Plus Probable Reserves

285,134

63,824

40,025

6,913

6,117

168,255

0

168,255

- 14 -

FUTURE NET REVENUE
BY PRODUCTION GROUP
as of December 31, 2003

FORECAST PRICES AND COSTS

		FUTURE NET REVENUE
		BEFORE INCOME TAXES & ARTC
		(discounted at 10%/year)
Reserves Category	PRODUCTION GROUP	(M$)
Proved Reserves	Light and Medium Crude Oil (including solution gas and other by-products)		310
	Natural Gas (including by-products but excluding solution gas from oil wells)		94,955
Proved Plus Probable Reserves	Light and Medium Crude Oil (including solution gas and other by-products)		602
	Natural Gas (including by-products by excluding solution gas from oil wells)		114,703

Notes:

(1)	“Gross Reserves” include working interest reserves before the deduction of royalties.
(2)	“Net Reserves” include working interest after royalty deductions plus royalty interest reserves.
(3)	The net cumulative cash flow forecasts are after direct lifting costs, freehold royalties, Crown mineral taxes and future investments. An allowance for future well abandonment costs for all working interest wells was included, however, no allowance was made for the abandonment of any facilities.
(4)	“Royalties” refers to royalties paid to others. The royalties deducted from the reserves are based on the percentage royalty calculated by applying the applicable royalty rate or formula. In the case of Crown sliding scale royalties which are dependent on selling prices, the price forecasts for the individual properties in question have been employed.
(5)	“Reserves” are estimated remaining quantities of oil and natural gas and related substances anticipated to be recoverable from known accumulations, from a given date forward, based on: analysis of drilling, geological, geophysical and engineering data; the use of established technology; and specified economic conditions, which are generally accepted as being reasonable, and shall be disclosed. Reserves are classified according to the degree of certainty associated with the estimates.
(6)	“Proved Reserves” are those reserves that can be estimated with a high degree of certainty to be recoverable. It is likely that the actual remaining quantities recovered will exceed the estimated proved reserves.
(7)	“Probable Reserves” are those additional reserves that are less certain to be recovered than proved reserves. It is equally likely that the actual remaining quantities recovered will be greater or less than the sum of the estimated proved plus probable reserves.
(8)	“Developed Reserves” are those reserves that are expected to be recovered from existing wells and installed facilities or, if facilities have not been installed, that would involve a low expenditure (for example, when compared to the cost of drilling a well) to put the reserves on production. The developed category may be subdivided into producing and non-producing.
(9)	“Developed Producing Reserves” are those reserves that are expected to be recovered from completion intervals open at the time of the estimate. These reserves may be currently producing or, if shut-in, they must have previously been on production, and the date of resumption of production must be known with reasonable certainty.
(10)	“Developed Non-Producing Reserves” are those reserves that either have not been on production, or have previously been on production, but are shut-in, and the date of resumption of production is unknown.
(11)	“Undeveloped Reserves” are those reserves expected to be recovered from known accumulations where a significant expenditure (for example, when compared to the cost of drilling a well) is required to render them capable of production. They must fully meet the requirements of the reserves classification (proved, probable, possible) to which they are assigned.
(12)	The pricing assumptions used in the McDaniel Report with respect to net cumulative cash flow as well as the inflation rates used for operating costs are set forth below.

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SUMMARY OF PRICING AND INFLATION RATE ASSUMPTIONS
as of December 31, 2003
 
FORECAST PRICES AND COSTS

	OIL
									NATURAL		Edmonton
			Edmonton		Hardisty		Cramer		GAS(1)		Cond. &		INFLATION		EXCHANGE
	WTI Cushing		Par Price		Heavy		Medium		AECO Gas		Natural		RATES		RATE
	Oklahoma		40° API		12° API		29.0° API		Price		Gasolines
Year	($US/bbl)		($Cdn/bbl)		($Cdn/bbl)		($Cdn/bbl)		($Cdn/GJ)		($CDn/bbl)		%/Year		($US/Cdn)
Historical
2000		30.31		44.72		27.80		40.10		5.32		46.25		2.7		0.674
2001		25.97		39.60		18.05		32.22		5.15		42.42		2.6		0.646
2002		26.10		39.95		27.60		34.93		3.86		40.65		2.2		0.637
2003		30.95		43.10		27.45		36.90		6.30		43.70		2.0		0.715
Forecast
2004		29.00		37.70		22.70		32.20		5.50		38.45		2.0		0.750
2005		26.50		34.30		21.55		29.71		5.19		35.07		2.0		0.750
2006		25.50		33.00		21.56		28.84		4.87		33.78		2.0		0.750
2007		25.00		32.30		20.63		28.06		4.68		33.10		2.0		0.750
2008		25.00		32.30		20.39		27.97		4.53		33.11		2.0		0.750
2009		25.50		32.90		20.76		28.48		4.57		33.73		2.0		0.750
2010		26.00		33.50		21.11		29.00		4.60		34.34		2.0		0.750
2011		26.50		34.20		21.56		29.61		4.69		35.06		2.0		0.750
2012		27.00		34.80		21.91		30.11		4.78		35.68		2.0		0.750
2013		27.50		35.50		22.35		30.72		4.87		36.40		2.0		0.750
2014		28.10		36.20		22.79		31.32		4.97		37.11		2.0		0.750
2015		28.70		37.00		23.32		32.03		5.08		37.93		2.0		0.750
2016		29.30		37.80		23.85		32.73		5.19		38.75		2.0		0.750
2017		29.90		38.60		24.37		33.43		5.29		39.57		2.0		0.750
2018		30.50		39.30		24.79		34.02		5.40		40.29		2.0		0.750
2019		31.10		40.10		25.30		34.72		5.51		41.11		2.0		0.750
2020		31.70		40.90		25.80		35.41		5.61		41.93		2.0		0.750
2021		32.30		41.70		26.30		36.10		5.72		42.75		2.0		0.750
2022		32.90		42.40		26.69		36.69		5.82		43.47		2.0		0.750
2023		33.60		43.30		27.28		37.47		5.95		44.39		2.0		0.750
Thereafter		33.60		43.30		27.28		37.47		5.95		44.39		0.0		0.750

(13)	Operating costs were escalated at a rate of 2.0% per year. The exchange rate used for the US/Canadian dollar for 2004 was 0.75, for 2005 was 0.75, for 2006 was 0.75, for 2007 was 0.75 and for 2008 and beyond was 0.75.
(14)	For the constant price evaluations, the McDaniel Report used product prices in effect as at December 31, 2003 of $39.76 (Edmonton Par Light) per bbl of oil and $5.87 (Alberta Average) per mmbtu of natural gas.
(15)	McDaniel and GLJ have estimated total capital costs of $6,913,000 and $6,696,000 (undiscounted) in order to achieve the future proved plus probable net revenues, of which $3,684,000 and $3,611,000 will be incurred in 2004 and $2,982,000 and $2,866,000 in 2005 based on Forecast and Constant prices respectively.
(16)	Total burdens include crown, freehold and overriding royalties as well as mineral taxes.

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								ASSOCIATED AND
		LIGHT AND MEDIUM OIL						NON-ASSOCIATED GAS								NATURAL GAS LIQUIDS
						Net							Net					Net
						Proved							Proved					Proved
		Net		Net		Plus		Net			Net		Plus			Net		Net		Plus
		Proved		Probable		Probable		Proved			Probable		Probable			Proved		Probable		Probable
Factors		(mbbl)		(mbbl)		(mbbl)		(mmcf)			(mmcf)		(mmcf)			(mbbl)		(mmbl)		(mbbl)
December 31, 2002
	Extensions		—		—		—		2,892.6			1,207.1		4,099.7			—		—		—
	Improved Recovery		—		—		—		—			—		—			—		—		—
	Technical Revisions		—		—		—		—			—		—			—		—		—
	Discoveries		—		—		—		—			—		—			—		—		—
	Acquisitions		201.9		64.5		267.3		29,571.5			7,524.3		37,095.8			124.4		31.0		155.4
	Dispositions		—		—		—		—			—		—			—		—		—
	Economic Factors		—		—		—		—			—		—			—		—		—
	Production		—		—		—		(3,007.6	)		—		(3,007.6	)		—		—		—
December 31, 2003			201.9		64.5		267.3		29,456.5			8,731.4		38,187.9			124.4		31.0		155.4

Reconciliation of Reserves

Prior to June 2003, the Corporation was not engaged in the exploration, development or production of oil or gas and did not hold any interests in any oil or gas properties. Accordingly, the Corporation did not have any reserves prior to June 2003.

Additional Information Relating to Reserves Data

Prior to June 2003, the Corporation was not engaged in the exploration, development or production of oil or gas and did not hold any interests in any oil or gas properties.

     Undeveloped Reserves

The following table summarizes the gross volumes of proved undeveloped reserves that were first attributed in each of the most recent financial years:

	2003
Product
Light and Medium Crude Oil(mbbls)		42.5
Natural Gas (mmcf)		885.1
Natural Gas Liquids (mbbls)		3.5
Total (mbbls)		193.5

The following table summarizes the gross volumes of probable reserves that were first attributed in each of the most recent financial years:

	2003
Product
Light and Medium Crude Oil (mbbls)		69.6
Natural Gas (mmcf)		11,528.7
Natural Gas Liquids (mbbls)		40.4
Total (mbbls)		2,031.5

Undeveloped reserves are those reserves expected to be recovered from known accumulations where a significant expenditure is required to render them capable of production.

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     Future Development Costs

The following table outlines development costs deducted in the estimation of future net revenue calculated using no discount.

	2004		2005		2006		2007		2008
	($ Thousands)		($ Thousands)		($ Thousands)		($ Thousands)		($ Thousands)
Reserve Category
Proved Reserves (Constant Prices and Costs)		3,412		150		—		—		12
Proved Reserves (Forecast Prices and Costs)		3,480		156		—		—		14
Proved & Probable Reserves: (Forecast Prices and Costs)		3,684		2,982		27		27		110

The Corporation has established a $56 million capital program to fund its exploration and development activities for the 2004 year. Such financing consists of internally generated cash flows and possible proceeds from minor divestitures of interests in non-principal properties acquired pursuant to the acquisitions of Pointwest and Zorin. The Corporation is currently evaluating the interests acquired pursuant to the acquisitions of Pointwest and Zorin. Any decision to divest any interest in such properties will only be contemplated once such evaluations are complete. The Corporation’s capital program does not include any corporate acquisition opportunities, which would likely be financed through debt or equity financings.

Other Oil And Gas Information

     Oil and Gas Properties and Wells

As at December 31, 2003, the Corporation had an interest in 257 gross (113.1 net) producing and 40 gross (18.3 net) non-producing oil and natural gas wells as follows:

		PRODUCING				NON-PRODUCING
		Gross(1)		Net(2)		Gross		Net
Wells
	Alberta		234		97.0		40		18.3
	British Columbia		23		16.1		—		—
TOTAL			257		113.1		40		18.3

Notes:

(1)	“Gross” wells means the number of wells in which the Corporation has a working interest or a royalty interest that may be convertible to a working interest.
(2)	“Net” wells means the aggregate number of wells obtained by multiplying each gross well by the Corporation’s percentage working interest therein.

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     Properties with No Attributed Reserves

The following table sets forth the gross and net acres of unproved properties held by the Corporation and the net area of unproved property for which the Corporation expects its rights to explore, develop and exploit to expire during the next year:

	UNPROVED PROPERTIES
	(acres)
LOCATION	Gross		Net		Net Area to Expire in 2004
Manitoba		80		18		0
Alberta		321,593		158,918		19,757
British Columbia		28,710		25,993		4,180
TOTAL		350,383		184,929		23,937

     Forward Contracts

Pursuant to the exercise of the option to purchase an undivided interest of up to 49% in the Southward Properties, the Corporation acquired an interest in forward sales contracts and financial hedging contracts with respect to production from the Southward Properties. Such contracts represent 7,645 GJ/d of natural gas as follows:

Transaction Type	Volume (GJ/d)		Contract Price (GJ/d)		Expiry
Costless Collar		4,830		$6.36 - $7.15	March 31, 2004
Fixed		1,610		$6.76	March 31, 2004
Cogeneration Fuel Supply		263		$1.959 - $2.217	October 31, 2008
Daily Declining Profile(1)		841	Netback(2)		October 31, 2011
Reserve Based		101	Netback(3)		Life of reserves

Notes:

(1) The Corporation’s obligation under this contract will, on November 1 of each succeeding year, decline to the following:

Date	Obligation (GJ/d)
November 1, 2004		724
November 1, 2005		623
November 1, 2006 and thereafter		568

(2)	TransCanada Pipelines Limited netback pricing.
(3)	Progas Limited netback pricing.

Following December 31, 2003, the Corporation entered into financial hedging contracts in respect of 28,000 GJ/d of natural gas as follows:

Transaction Type	Volume (GJ/d)		AECO Price (GJ/d)		Term
Collar		5,000		$5.50 - $6.35	April 1, 2004 to October 31, 2004
Collar		8,000		$5.50 - $6.40	April 1, 2004 to October 31, 2004
Collar		5,000		$5.50 - $6.36	April 1, 2004 to October 31, 2004
Fixed Price Swap		5,000		$5.745	April 1, 2004 to June 30, 2004
Fixed Price Swap		5,000		$5.745	August 1, 2004 to October 31, 2004
Fixed Price Swap		5,000		$5.7725	April 1, 2004 to October 31, 2004

The Corporation has sufficient production to meet these commitments.

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     Abandonment & Reclamation Costs

An allowance for future well abandonment costs was made for all of the Corporation’s working interest wells, however, no allowance was made for the reclamation of well sites or the abandonment and reclamation of any facilities.

     Costs Incurred

The following table outlines costs incurred during the financial year ended December 31, 2003.

Property Acquisitions, Dispositions and Capital Expenditures

Nature of cost		Amount ($M)
Property Acquisition Costs
	Proved		—
	Unproved		—
Exploration Costs			7,592
Development Costs			6,912
Total			14,504

     Exploration and Development Activities

The following table summarizes the results of exploration and development activities during the financial year ended December 31, 2003.

	Gross		Net
Development Wells
Gas		20		9.6
Oil		2		1.0
Service		—		—
Dry		7		3.5
Exploratory Wells
Gas		5		3.0
Oil		—		—
Service		—		—
Dry		1		0.5
Total Wells		35		17.6

The Corporation intends to continue to develop its principal properties as well as continue its grassroots exploration program to establish new core areas in Alberta and British Columbia. Hawker will continue to target natural gas properties with multiple horizons in the Western Canada Sedimentary Basin. These exploration and development activities will be financed through a $56 million capital program for the 2004 year, which financing consists of internally generated cash flow and proceeds from divestitures of interests in non-principal properties.

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     Production Estimates

The following tables summarize the volume of total proved production estimated for 2004 using constant and forecast prices and costs.

	ESTIMATED PRODUCTION
	Constant Prices and Costs		Forecast Prices and Costs
Light and Medium Crude Oil (boe/d)		123		123
Natural Gas (mcf/d)		30,250		30,250
Natural Gas Liquids (boe/d)		111		111

BORROWINGS

At December 31, 2003, the Corporation had total bank borrowings outstanding in the amount of $54,149,000.

The Corporation has a $54 million extendible revolving credit facility from a Canadian chartered bank. This facility bears interest at rates varying from Canadian prime rate or U.S. base rate of such bank to the Canadian prime rate or U.S. base rate plus 75 basis points, payable monthly in arrears. The Corporation may also borrow by way of bankers’ acceptances, which are subject to a stamping fee, or by way of LIBOR based loans which are subject to an interests rate spread payable to the bank. The loan is a revolving facility until June 30, 2004, with annual extension periods available at the bank’s discretion. After the revolving phase, the facility becomes a term facility payable in full one year from the date the revolving facility is terminated. The facility is subject to semi-annual reviews and re-determination of the Corporation’s borrowing base by the bank, with the next review to occur by March 31, 2004. So long as the loan remains revolving and the borrowing base supports the facility outstanding, there are no repayments required.

The Corporation also has a $10 million non-revolving bridge facility from the same Canadian chartered bank. This bridge facility, available to the Corporation solely for the acquisition of Pointwest, was fully drawn upon as at December 31, 2003. The bridge facility bears interest at rates varying from Canadian prime rate plus 250 basis points, payable monthly in arrears. The Corporation may also borrow by way of bankers’ acceptances that are subject to a stamping fee payable to the bank. The bridge facility is repayable in full on or prior to September 30, 2004.

While any amounts are outstanding under the bridge facility, the loan margins on both the extendible revolving term credit facility and the bridge facility will be increased by (i) 25 basis points effective May 1, 2004, (ii) 50 basis points effective June 1, 2004, (iii) 100 basis points effective July 1, 2004, (iv) 150 basis points effective August 1, 2003, and (v) 200 basis points effective September 1, 2004.

Collateral pledged for the facilities consists of a first floating charge demand debenture in the amount of $150 million over all of the property of the Corporation.

INDUSTRY CONDITIONS

Canadian Government Regulation

The oil and natural gas industry is subject to extensive controls and regulations imposed by various levels of government. It is not expected that any of these controls or regulations will affect the operations of Hawker in a manner materially different than they would affect other oil and gas companies of similar size. All current legislation is a matter of public record and Hawker is unable to predict what additional legislation or amendments may be enacted. Outlined below are some of the principal aspects of legislation, regulations and agreements governing the oil and gas industry.

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Pricing and Marketing — Oil

In Canada, the producers of oil are entitled to negotiate sales contracts directly with oil purchasers, with the result that the market determines the price of oil. The price depends in part on oil quality, prices of competing fuels, distance to market, the value of refined products and the balance between supply and demand. Oil exports may be made pursuant to export contracts with terms not exceeding one year in the case of light crude, and not exceeding two years in the case of heavy crude, provided that an order approving any such export has been obtained from the National Energy Board. Any oil export to be made pursuant to a contract of longer duration (to a maximum of 25 years) requires an exporter to obtain an export licence from the National Energy Board and the issue of such a licence requires the approval of the Governor in Council.

Price and Marketing — Natural Gas

In Canada, the price of natural gas sold in interprovincial and international trade is determined by negotiation between buyers and sellers. Natural gas exported from Canada is subject to regulation by the National Energy Board and the Government of Canada. Exporters are free to negotiate prices and other terms with purchasers, provided that the export contracts must continue to meet certain criteria prescribed by the National Energy Board and the Government of Canada. Natural gas exports for a term of less than two years or for a term of two to 20 years (in quantities of not more than 10,648 mmcf/d), must be made pursuant to an National Energy Board order. Any natural gas export to be made pursuant to a contract of longer duration (to a maximum of 25 years) or a larger quantity requires an exporter to obtain an export licence from the National Energy Board and the issue of such a licence requires the approval of the Governor in Council.

The governments of Alberta, British Columbia and Saskatchewan also regulate the volume of natural gas which may be removed from those provinces for consumption elsewhere based on such factors as reserve availability, transportation arrangements and market considerations.

The North American Free Trade Agreement

On January 1, 1994, the North American Free Trade Agreement (“NAFTA”) became effective among the governments of Canada, the United States of America and Mexico. NAFTA carries forward most of the material energy terms contained in the Canada-U.S. Free Trade Agreement. In the context of energy resources, Canada continues to remain free to determine whether exports to the United States or Mexico will be allowed provided that any export restrictions do not: (i) reduce the proportion of energy resource exported relative to domestic use (based upon the proportion prevailing in the most recent 36 month period), (ii) impose an export price higher than the domestic price, and (iii) disrupt normal channels of supply. All three countries are prohibited from imposing minimum export or import price requirements.

NAFTA also contemplates clearer disciplines on regulators to ensure fair implementation of any regulatory changes and to minimize disruption of contractual arrangements, which is important for Canadian natural gas exports.

Royalties and Incentives

In addition to federal regulation, each province has legislation and regulations which govern land tenure, royalties, production rates, sulphur, environmental protection and other matters. The royalty regime is a significant factor in the profitability of oil, NGLs, and natural gas production. Royalties payable on production from lands other than Crown lands are determined by negotiations between the mineral owner and the lessee, although production from such lands is subject to certain provincial taxes and royalties. Crown royalties are determined by government regulation and are generally calculated as a percentage of the value of the gross production. The rate of royalties payable generally depends in part on prescribed reference prices, well productivity, geographical location, field discovery date and the type or quality of the petroleum product produced.

From time to time the governments of Canada, Alberta, British Columbia and Saskatchewan have established incentive programs which have included royalty rate reductions, royalty holidays and tax credits for the purpose of encouraging oil and natural gas exploration or enhanced planning projects.

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Regulations made pursuant to the Mines and Minerals Act (Alberta) provide various incentives for exploring and developing oil reserves in Alberta. Oil produced from horizontal extensions commenced at least five years after the well was originally spudded may also qualify for a royalty reduction. A 24 month, 8,000 cubic metre exemption is available to production from a well that has not produced for a 12 month period, if resuming production after February 1, 1993. As well, oil production from eligible new field and new pool wildcat wells and deeper pool test wells spudded or deepened after September 30, 1992 is entitled to a 12 month royalty exemption (to a maximum of $1 million). Oil produced from low productivity wells, enhanced recovery schemes (such as injection wells) and experimental projects is also subject to royalty reductions.

The Alberta government has also introduced a third tier royalty with a base rate of 10% and a rate cap of 25% for oil pools discovered after September 30, 1992. The new oil royalty reserved to the Crown has a base rate of 10% and a rate cap of 30%. The old oil royalty reserved to the Crown has a base rate of 10% and a rate cap of 35%.

In the Province of Alberta, the royalty reserved to the Crown in respect of natural gas production, subject to various incentives, is between 15% and 30%, in the case of new gas, and between 15% and 35%, in the case of old gas, depending upon a prescribed or corporate average reference price. Natural gas produced from qualifying exploratory gas wells spudded or deepened after July 31, 1985 and before June 1, 1988 is eligible for a royalty exemption for a period of 12 months, up to a prescribed maximum amount. Natural gas produced from qualifying intervals in eligible gas wells spudded or deepened to a depth below 2,500 meters is also subject to a royalty exemption, the amount of which depends on the depth of the well.

In Alberta, a producer of oil or natural gas is entitled to a credit on qualified oil and gas production against the royalties payable to the Crown by virtue of the Alberta Royalty Tax Credit (“ARTC”) program. The ARTC program is based on a price sensitive formula and the ARTC rate varies between 25% and 75%. The ARTC rate is applied to a maximum of $2,000,000 of Alberta Crown royalties payable for each producer or associated group of producers. Crown royalties on production from producing properties acquired from corporations claiming maximum entitlement to ARTC will generally not be eligible for ARTC. The rate is established quarterly based on the average “par price”, as determined by the Alberta Department of Energy for the previous quarterly period.

Oil and natural gas royalty holidays and reductions for specific wells reduce the amount of Crown royalties that would otherwise be payable by the Corporation to the provincial governments. In Alberta, the ARTC program provides a rebate on Alberta Crown royalties paid in respect of eligible producing properties. Both of these incentives will have the effect of increasing the net income of the Corporation.

In British Columbia, the amount payable as a royalty in respect of oil depends on the vintage of the oil (whether it was produced from a pool discovered before or after October 31, 1975), the quantity of oil produced in a month and the value of the oil. Oil produced from newly discovered pools may be exempt from the payment of a royalty for the first 36 months of production. The royalty payable on natural gas is determined by a sliding scale based on a reference price which is the greater of the amount obtained by the producer and a prescribed minimum price. Natural gas produced in association with oil has a minimum royalty of 8% while the royalty in respect of other natural gas may not be less than 15%.

On May 30, 2003, the Minister of Energy and Mines for British Columbia announced an Oil and Gas Development Strategy for the Heartlands. The Strategy, which was updated in November 2003, is a comprehensive program to address road infrastructure, targeted royalties, and regulatory reduction and service-sector opportunities. Some of the financial incentives include: i) royalty credits of up to $30 million annually towards road infrastructure in support of resource development (Industry must make an equal contribution), ii) royalty credits for deep gas exploration, re-entry, and horizontal drilling, and iii) royalty credits for unconventional and new basins.

Land Tenure

Crude oil and natural gas located in the western provinces is owned predominantly by the respective provincial governments. Provincial governments grant rights to explore for and produce oil and natural gas pursuant to leases, licences and permits for varying terms from two years and on conditions set forth in provincial legislation including requirements to perform specific work or make payments. Oil and natural gas located in such provinces can also be

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privately owned and rights to explore for and produce such oil and natural gas are granted by lease on such terms and conditions as may be negotiated.

Environmental Regulation

The oil and natural gas industry is currently subject to environmental regulation pursuant to provincial and federal legislation. Environmental legislation provides for restrictions and prohibitions on releases or emissions of various substances produced or utilized in association with certain oil and gas industry operations. In addition, legislation requires that well and facility sites be abandoned and reclaimed to the satisfaction of provincial authorities. Compliance with such legislation can require significant expenditures and a breach of such requirements may result in suspension or revocation of necessary licenses and authorizations, civil liability for pollution damage and the imposition of material fines and penalties.

Environmental legislation in the Province of Alberta has been consolidated into the Alberta Environmental Protection and Enhancement Act, which came into force on September 1, 1993, and imposes stricter environmental standards, requires more stringent compliance, reporting and monitoring obligations and significantly increases the penalties that can be imposed.

RISK FACTORS

Exploration, Development and Production Risks

Oil and gas operations involve many risks which even a combination of experience and knowledge and careful evaluation may not be able to overcome. The long-term commercial success of the Corporation depends on its ability to find, acquire, develop and commercially produce oil and natural gas reserves. Without the continual addition of new reserves, any existing reserves the Corporation may have at any particular time and the production therefrom will decline over time as such reserves are exploited. A future increase in the Corporation’s reserves will depend not only upon the Corporation’s ability to explore and develop any properties it may have, but also on its ability to select and acquire suitable producing properties. No assurance can be given that the Corporation will be able to continue to locate satisfactory properties for acquisition or to participate in other ventures or be able to identify and reach agreement with suitable partners. Moreover, if such acquisitions or partners are identified, the Corporation may determine that current markets, terms of acquisition and participation or pricing conditions make any such opportunities uneconomic. There is no assurance that commercial quantities of oil and natural gas will be discovered or acquired by the Corporation.

Future oil and gas exploration may involve unprofitable efforts, not only from dry wells, but from wells that are productive but do not produce sufficient net revenues to return a profit after drilling, operating and other costs. Completion of a well does not assure a profit on the investment or recovery of drilling, completion and operating costs. In addition, drilling hazards or environmental damage could greatly increase the cost of operations, and various field operating conditions may adversely affect the production from successful wells. These conditions include delays in obtaining governmental approvals or consents, shut-ins of connected wells resulting from extreme weather conditions, insufficient storage or transportation capacity or other geological and mechanical conditions. While close well supervision and effective maintenance operations can contribute to maximizing production rates over time, production delays and declines from normal field operating conditions cannot be eliminated and can be expected to adversely affect revenue and cash flow levels to varying degrees.

In addition, oil and gas operations are subject to the risks of exploration, development and production of oil and natural gas properties, including encountering unexpected formations or pressures, premature declines of reservoirs, blow-outs, cratering, sour gas releases, fires and spills. Losses resulting from the occurrence of any of these risks could have a materially adverse effect on future results of operations, liquidity and financial condition.

Insurance

The Corporation’s involvement in the exploration for and development of oil and gas properties may result in the Corporation becoming subject to liability for pollution, blow-outs, property damage, personal injury or other

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hazards. Although prior to drilling the Corporation will obtain insurance in accordance with industry standards to address such risks, such insurance has limitations on liability that may not be sufficient to cover the full extent of such liabilities. In addition, such risks may not in all circumstances be insurable or, in certain circumstances, the Corporation may elect not to obtain insurance to deal with specific risks due to the high premiums associated with such insurance or other reasons. The payment of such uninsured liabilities would reduce the funds available to the Corporation. The occurrence of a significant event that the Corporation is not fully insured against, or the insolvency of the insurer of such event, could have a material adverse effect on the Corporation’s financial position, results of operations or prospects.

Prices, Markets and Marketing of Crude Oil and Natural Gas

Oil and natural gas are commodities whose prices are determined based on world demand, supply and other factors, all of which are beyond the control of the Corporation. World prices for oil and natural gas have fluctuated widely in recent years. Any material decline in prices could result in a reduction of net production revenue. Certain wells or other projects may become uneconomic as a result of a decline in world oil prices and natural gas prices, leading to a reduction in the volume of the Corporation’s oil and gas reserves. The Corporation might also elect not to produce from certain wells at lower prices. All of these factors could result in a material decrease in the Corporation’s future net production revenue, causing a reduction in its oil and gas acquisition and development activities. In addition, bank borrowings available to the Corporation are in part determined by the borrowing base of the Corporation. A sustained material decline in prices from historical average prices could limit or reduce the Corporation’s borrowing base, thereby reducing the debt financing available to the Corporation, and could require that a portion of any existing debt financing of the Corporation be repaid.

The marketability and price of oil and natural gas which may be acquired or discovered by the Corporation will be affected by numerous factors beyond its control. The Corporation may be affected by the differential between the price paid by refiners for light quality oil and the grades of oil produced by the Corporation. The ability of the Corporation to market its natural gas may depend upon its ability to acquire space on pipelines which deliver natural gas to commercial markets. The Corporation may also likely be affected by deliverability uncertainties related to the proximity of its reserves to pipelines and processing facilities and related to operational problems with such pipelines and facilities and extensive government regulation relating to price, taxes, royalties, land tenure, allowable production, the export of oil and natural gas and many other aspects of the oil and natural gas business.

Substantial Capital Requirements; Liquidity

The Corporation anticipates that it will make substantial capital expenditures for the acquisition, exploration, development and production of oil and natural gas reserves in the future. There can be no assurance that debt or equity financing or cash generated by operations will be available or sufficient to meet these requirements or for other corporate purposes or, if debt or equity financing is available, that it will be on terms acceptable to the Corporation. Moreover, future activities may require the Corporation to alter its capitalization significantly. The inability of the Corporation to access sufficient capital for its operations could have a material adverse effect on the Corporation’s financial condition, results of operations or prospects.

Competition

The Corporation competes for reserve acquisitions, exploration leases, licences and concessions and skilled industry personnel with a substantial number of other oil and gas companies, many of which have significantly greater financial resources than the Corporation. The Corporation’s competitors include major integrated oil and natural gas companies and numerous other independent oil and natural gas companies and individual producers and operators. The Corporation’s ability to increase reserves in the future will depend not only on its ability to explore and develop the properties to be acquired with the proceeds of this offering, but also on its ability to select and acquire suitable producing properties or prospects for exploratory drilling. Competitive factors in the distribution and marketing of oil and natural gas include price and methods and reliability of delivery.

The oil and gas industry is highly competitive. The Corporation’s competitors for the acquisition, exploration, production and development of oil and natural gas properties, and for capital to finance such activities, include companies that have greater financial and personnel resources available to them than the Corporation.

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The Corporation’s ability to successfully bid on and acquire additional property rights, to discover reserves, to participate in drilling opportunities and to identify and enter into commercial arrangements with customers will be dependent upon developing and maintaining close working relationships with its future industry partners and joint operators and its ability to select and evaluate suitable properties and to consummate transactions in a highly competitive environment.

Environmental Risks

All phases of the oil and natural gas business present environmental risks and hazards and are subject to environmental regulation pursuant to a variety of international conventions and state and municipal laws and regulations. Environmental legislation provides for, among other things, restrictions and prohibitions on spills, releases or emissions of various substances produced in association with oil and gas operations. The legislation also requires that wells and facility sites be operated, maintained, abandoned and reclaimed to the satisfaction of applicable regulatory authorities. Compliance with such legislation can require significant expenditures and a breach may result in the imposition of fines and penalties, some of which may be material. Environmental legislation is evolving in a manner expected to result in stricter standards and enforcement, larger fines and liability and potentially increased capital expenditures and operating costs. The discharge of oil, natural gas or other pollutants into the air, soil or water may give rise to liabilities to governments and third parties and may require the Corporation to incur costs to remedy such discharge. No assurance can be given that environmental laws will not result in a curtailment of production or a material increase in the costs of production, development or exploration activities or otherwise adversely affect the Corporation’s financial condition, results of operations or prospects (See “Industry Conditions — Environmental Regulation”).

Reserves Replacement

The Corporation’s future oil and natural gas reserves, production, and cash flows to be derived therefrom are highly dependent on the Corporation successfully acquiring or discovering new reserves. Without the continual addition of new reserves, any existing reserves the Corporation may have at any particular time and the production therefrom will decline over time as such existing reserves are exploited. A future increase in the Corporation’s reserves will depend not only on the Corporation’s ability to develop any properties it may have from time to time, but also on its ability to select and acquire suitable producing properties or prospects. There can be no assurance that the Corporation’s future exploration and development efforts will result in the discovery and development of additional commercial accumulations of oil and natural gas.

Reliance on Operators and Key Employees

To the extent the Corporation is not the operator of its oil and gas properties, the Corporation will be dependent on such operators for the timing of activities related to such properties and will largely be unable to direct or control the activities of the operators. In addition, the success of the Corporation will be largely dependent upon the performance of its management and key employees. The Corporation does not have any key man insurance policies, and therefore there is a risk that the death or departure of any member of management or any key employee could have a material adverse effect on the Corporation. In assessing the risk of an investment in the Common Shares, potential investors should recognize that they are relying on the ability and integrity of the management of Hawker.

Corporate Matters

To date, the Corporation has not paid any dividends on its outstanding Common Shares. However, the board of directors of the Corporation may make a determination to pay dividends in the future if circumstances permit. Any decision to pay dividends will be made by the board of directors of the Corporation on the basis of the Corporation’s earnings, financial requirements and other conditions existing at the time.

Certain of the directors and officers of the Corporation are also directors and officers of other oil and gas companies involved in natural resource exploration and development, and conflicts of interest may arise between their duties as officers and directors of the Corporation and as officers and directors of such other companies. Such conflicts must

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be disclosed in accordance with, and are subject to such other procedures and remedies as apply under, the Business Corporations Act (Alberta).

Permits and Licenses

The operations of the Corporation may require licenses and permits from various governmental authorities. There can be no assurance that the Corporation will be able to obtain all necessary licenses and permits that may be required to carry out exploration and development of its projects.

Additional Funding Requirements

The Corporation’s cash flow from its properties may not be sufficient to fund its ongoing activities and implement its business plan. From time to time, the Corporation may require additional financing in order to carry out its oil and gas acquisition, exploration and development activities. Failure to obtain such financing on a timely basis could cause the Corporation to forfeit its interest in certain properties, miss certain acquisition opportunities and reduce or terminate its operations. If the Corporation’s future revenues from its future reserves decrease as a result of lower oil and natural gas prices or otherwise, it will affect the Corporation’s ability to expend the necessary capital to replace its reserves or to maintain its production. If the Corporation’s cash flow from operations is not sufficient to satisfy its capital expenditure requirements, there can be no assurance that additional debt or equity financing will be available to meet these requirements or be available on favourable terms.

Issuance of Debt

The Corporation’s activities may be financed partially or wholly with debt, which may increase the Corporation’s debt levels above industry standards. Neither the Corporation’s articles nor its by-laws limit the amount of indebtedness that the Corporation may incur. The level of the Corporation’s indebtedness from time to time could impair the Corporation’s ability to obtain additional financing in the future on a timely basis to take advantage of business opportunities that may arise.

Availability of Drilling Equipment and Access Restrictions

Oil and natural gas exploration and development activities are dependent on the availability of drilling and related equipment in the particular areas where such activities will be conducted. Demand for such equipment or access restrictions may affect the availability of such equipment to the Corporation and may delay exploration and development activities.

Title Defects

Although title reviews will generally be conducted prior to the purchase of most oil and natural gas producing properties or the commencement of drilling wells, such reviews may not discover unforeseen title defects that could adversely affect Hawker’s title to the property or entitlement to revenue from the property.

Uncertainty of Reserve Information

There are numerous uncertainties inherent in estimating quantities of reserves and cash flows to be derived from exploration and production activities, including many factors that are beyond the control of the Corporation. The reserve and cash flow information set forth in this Annual Information Form represent estimates only. The reserves and estimated future net cash flow from the Corporation’s properties have been independently evaluated effective December 31, 2003 by McDaniel and GLJ. These evaluations include a number of assumptions relating to factors such as initial production rates, production decline rates, ultimate recovery of reserves, timing and amount of capital expenditures, marketability of production, future prices of oil and natural gas, operating costs and royalties and other government levies that may be imposed over the producing life of the reserves. These assumptions were based on price forecasts in use at the date the relevant evaluations were prepared and many of these assumptions are subject to change and are beyond the control of the Corporation. Actual production and cash flows derived therefrom will vary from these evaluations, and such variations could be material. The foregoing evaluations are based in part on

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the assumed success of activities intended to be undertaken in future years. The reserves and estimated cash flows to be derived therefrom contained in such evaluations will be reduced to the extent that such activities do not achieve the level of success assumed in the evaluations.

Kyoto Protocol

Canada is a signatory to the United Nations Framework Convention on Climate Change and has ratified the Kyoto Protocol established thereunder to set legally binding targets to reduce nation-wide emissions of carbon dioxide, methane, nitrous oxide and other so-called “greenhouse gases”. The Government of Canada has put forward a Climate Change Plan for Canada which suggests further legislation will set greenhouse gases emission reduction requirements for various industrial activities, including oil and gas exploration and production. Hawker’s exploration and production facilities and other operations will emit greenhouse gases which may subject Hawker to legislation regulating greenhouse gases. Future federal legislation, together with provincial emission reduction requirements, such as those proposed in Alberta’s Bill 32: Climate Change and Emissions Management Act, may require the reduction of emissions or emissions intensity from the Corporation’s operations and facilities. The direct and indirect costs of these regulations may adversely affect the business of the Corporation.

Government Regulation and Taxation

Oil and gas operations are subject to extensive Canadian federal, provincial and local laws and regulations governing exploration, development, transportation, production, exports, labour standards, occupational health, waste disposal, protection and redemption of the environment, mine safety, hazardous materials, toxic substances, taxation and other matters. It is believed that the Corporation is in substantial compliance with all applicable laws and regulations. Amendments to current laws and regulations governing oil and gas operations and the more stringent implementation thereof are actively considered form time to time and the implementation thereof could have a material adverse impact on the Corporation. In addition, taxation laws and regulations as well as the current administrative practices of both the federal and provincial tax authorities may be amended or construed in such a way that is detrimental to the Corporation or its activities.

SELECTED FINANCIAL INFORMATION

The following is a summary of selected financial information for the period indicated. The financial information for the period prior to June 30, 2003 reflects the Corporation’s operations as a pharmaceutical research company prior to its change of business into an oil and gas exploration and development company.

Financial Results

		Year ending		Year ending		Year ending
		December 31, 2003		December 31, 2002		December 31, 2001
		($000s except per share amounts)
Total Revenue, net of royalties			13,942		139		729
Net Income (Loss)			2,314		3,766		(22,988	)
	per share — basic		0.14		0.76		(4.64	)
	per share — fully diluted		0.14		0.76		(4.64	)
Total Assets			185,102		4,015		22,584
Long-Term Debt			44,149		—		—
Cash Dividends per share			—		—		—

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Average Prices

	2003
	1st		2nd		3rd		4th		Annual
	Quarter		Quarter		Quarter		Quarter		Average
Oil ($/bbl)		—		—		—		—		—
Natural gas ($/mcf)		—		—		5.81		5.87		5.84
NGLs ($/bbl)		—		—		—		—		—
Total ($/boe)		—		—		34.86		35.22		35.04

MANAGEMENT’S DISCUSSION AND ANALYSIS

The information contained in the Management’s Discussion and Analysis relating to the Corporation’s financial statements for the year ended December 31, 2003 is incorporated herein by reference and forms an integral part of this Annual Information Form.

MARKET FOR SECURITIES

The outstanding Common Shares of the Corporation are listed and posted for trading on the TSX under the symbol “HKR”.

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DIRECTORS AND EXECUTIVE OFFICERS

The name, municipality of residence, position with the Corporation and principal occupation of each of the directors and executive officers of the Corporation are as follows:

Name and Municipality	Position with the	Director or	Present Occupation and Positions Held
of Residence	Corporation	Officer Since	During the Last Five Years
David A. Tuer Calgary, Alberta	President and Chief Executive Officer and a Director	January 6, 2003	President and Chief Executive Officer and a Director of Hawker and Chairman, Calgary Health Region. Prior to October 2001, President, Chief Executive Officer and a Director of PanCanadian Energy Corporation
Ronald P. Mathison(1)(2) Calgary, Alberta	Chairman and a Director	April 3, 2003	President of Matco Investments Ltd. (a private investment company); prior to 1999, Principal, Peters & Co. Limited.
Stan G.P. Grad(3) Calgary, Alberta	Director	April 21, 2003	Independent Businessman
Bruce J. Kenway, C.A.(1) Calgary, Alberta	Director	March 31, 1994	Partner, Kenway Mack Slusarchuk Stewart LLP, Chartered Accountants
Martin A. Lambert(1)(2)(4) Calgary, Alberta	Director	April 3, 2003	Partner, Bennett Jones LLP
Keith T. Smith(3)(4) Calgary, Alberta	Director	April 3, 2003	President and Chief Executive Officer of zed.i solutions inc. from April 2001. Prior thereto, Vice President, Corporate Development with zed.i solutions inc. since April 2000 and Executive Vice President of Acanthus Resources Ltd., a private oil and gas company, from August 1998 to April 2000. Prior thereto, Executive Vice President of WestCastle Energy Corp., the Manager of WestCastle Energy Trust, and a Director of WestCastle Acquisition Corp., the operating company of WestCastle Energy Trust from February 1997 to August 1998
Barry R. Herring Calgary, Alberta	Senior Vice President, Finance and Chief Financial Officer	May 6, 2003	Senior Vice President, Finance and Chief Financial Officer of the Corporation since May 6, 2003. Prior thereto, Vice President, Finance and Chief Financial Officer of Southward Energy Ltd. from January 2002 to April 2003, Senior Vice President of Calpine Canada from June 2000 to September 2000, Vice President, Finance and Operations of Quintana Minerals Canada Corp. from May 1999 to June 2000 and Vice President, Finance and Operations of Ocean Energy Inc. from 1997 to 1999.

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Name and Municipality	Position with the	Director or	Present Occupation and Positions Held
of Residence	Corporation	Officer Since	During the Last Five Years
Terry C. Schmidtke Calgary, Alberta	Senior Vice President, Operations and Chief Operating Officer	April 21, 2003	Senior Vice President, Operations and Chief Operating Officer of the Corporation since April 21, 2003. Prior thereto, Senior Vice President, Central Plains Region for EnCana Corporation from April 2002 to March 2003, and General Manager of various business units of PanCanadian Energy Corporation since 1994.

Notes:

(1)	Member of Audit Committee.
(2)	Member of Corporate Governance Committee.
(3)	Member of Reserves Committee.
(4)	Member of Compensation Committee.

At the date of this Annual Information Form, there are six directors of the Corporation. At the next annual meeting of shareholders, shareholders of Hawker will be asked to elect as directors the six nominees listed in the above table to serve until the close of the next annual meeting of shareholders, or until their respective successors are duly elected or appointed. All of the directors shall be eligible for re-election.

As at March 5, 2004, the directors and executive officers of the Corporation beneficially owned, directly or indirectly, or exercised control or direction over an aggregate 2,763,377 Common Shares and 3,371,852 non-voting Class A Shares, representing 7.7% of the 35,997,200 issued and outstanding Common Shares and 87.0% of the 3,874,437 non-voting Class A Shares, and directors and executive officers held options to acquire an additional 175,000 Common Shares.

CONFLICTS OF INTEREST

Certain of the directors and officers of the Corporation are directors and officers of other private and public companies. Some of these private and public companies may, from time to time, be involved in business transactions or banking relationships which may create situations in which conflicts might arise. Any such conflicts shall be resolved in accordance with the procedures and requirements of the relevant provisions of the Business Corporations Act (Alberta), including the duty of such directors and officers to act honestly and in good faith with a view to the best interests of the Corporation.

ADDITIONAL INFORMATION

Additional information, including remuneration of directors and officers of the Corporation and the and the principal holders of the Common Shares, is contained in the Corporation’s information circular dated March 5, 2004 which relates to the Annual and Special Meeting of shareholders of the Corporation to be held on April 28, 2004.

The Corporation will provide to any person, upon request to the Assistant Corporate Secretary of the Corporation at 700, 700 – 2nd Street S.W., Calgary, Alberta T2P 2W1:

(a) when the securities of the Corporation are in the course of a distribution pursuant to a short form prospectus or a preliminary short form prospectus that has been filed in respect of a distribution of its securities:

(i) one copy of this Annual Information Form together with one copy of any document, or the pertinent pages of any document, incorporated by reference in this Annual Information Form;

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(ii)	one copy of the annual comparative consolidated financial statements of the Corporation for the year ended December 31, 2003, together with the accompanying report of the auditor and one copy of any subsequent interim financial statements;
(iii)	one copy of the Corporation’s management information circular dated March 5, 2004; and
(iv)	one copy of any other documents that are incorporated by reference into the preliminary short form prospectus or the short form prospectus and are not required to be provided under (i) to (iii) above; or

(b) at any other time, one copy of any documents referred to in (i) to (iii) above, provided that the Corporation may require the payment of a reasonable charge if the request is made by a person or company who is not a shareholders of the Corporation.

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APPENDIX A

A-1

FORM 51-101F2
REPORT ON RESERVES DATA
BY
INDEPENDENT QUALIFIED RESERVES
EVALUATOR

Report on Reserves Data

To the board of directors of Hawker Resources Inc. (the “Corporation”):

1. We have evaluated the Corporation’s reserves data as at December 31, 2003. The reserves data consist of the following:

(a)	(i)   proved and proved plus probable oil and gas reserves estimated as at December 31, 2003 using forecast prices and costs; and
	(ii)  the related estimated future net revenue; and
(b)	(i)   proved oil and gas reserves estimated as at December 31, 2003 using constant prices and costs; and
	(ii)  the related estimated future net revenue.

2.	The reserves data are the responsibility of the Corporation’s management. Our responsibility is to express an opinion on the reserves data based on our evaluation.
	We carried out our evaluation in accordance with standards set out in the Canadian Oil and Gas Evaluation Handbook (the “COGE Handbook”) prepared jointly by the Society of Petroleum Evaluation Engineers (Calgary Chapter) and the Canadian Institute of Mining, Metallurgy & Petroleum (Petroleum Society).
3.	Those standards require that we plan and perform an evaluation to obtain reasonable assurance as to whether the reserves data are free of material misstatement. An evaluation also includes assessing whether the reserves data are in accordance with principles and definitions presented in the COGE Handbook.
4.	The following table sets forth the estimated future net revenue (before deduction of income taxes) attributed to proved plus probable reserves, estimated using forecast prices and costs and calculated using a discount rate of 10 percent, included in the reserves data of the Corporation evaluated by us for the year ended December 31, 2003, and identifies the respective portions thereof that we have evaluated and reported on to the Corporation’s board of directors:

Independent Qualified Reserves Evaluator	Description and Preparation Date of	Location of Reserves (Country or Foreign	Net Present Value of Future Net Revenue (before income taxes, 10% discount rate)
or Auditor	Audit Report	Geographic Area)	Audited		Evaluated		Reviewed		Total
McDaniel and Associates Consultants Limited	December 31, 2003	Canada		—	$	116,214.3		—	$	116,214.3

A-2

5.	In our opinion, the reserves data respectively evaluated by us have, in all material respects, been determined and are in accordance with the COGE Handbook. We express no opinion on the reserves data that we reviewed but did not audit or evaluate.
6.	We have no responsibility to update our reports referred to in paragraph 4 for events and circumstances occurring after their respective preparation dates.
7.	Because the reserves data are based on judgments regarding future events, actual results will vary and the variations may be material.
	Executed as to our report referred to above:
	March 12, 2004, Calgary, Alberta, Canada.

McDANIEL AND ASSOCIATES CONSULTANTS LIMITED
Per:	(signed) “Phil Welch” Phil Welch

A-3 -

FORM 51-101F2
REPORT ON RESERVES DATA
BY
INDEPENDENT QUALIFIED RESERVES
EVALUATOR

Report on Reserves Data

To the board of directors of Hawker Resources Inc. (the “Corporation”):

1. We have reviewed the Corporation’s reserves data as at December 31, 2003. The reserves data consist of the following:

(a)	(i)    proved and proved plus probable oil and gas reserves estimated as at December 31, 2003 using forecast prices and costs; and
	(ii)  the related estimated future net revenue; and
(b)	(i)    proved oil and gas reserves estimated as at December 31, 2003 using constant prices and costs; and
	(ii)  the related estimated future net revenue.

2.	The reserves data are the responsibility of the Corporation’s management. Our responsibility is to express an opinion on the reserves data based on our review.
	We carried out our review in accordance with standards set out in the Canadian Oil and Gas Evaluation Handbook (the “COGE Handbook”) prepared jointly by the Society of Petroleum Evaluation Engineers (Calgary Chapter) and the Canadian Institute of Mining, Metallurgy & Petroleum (Petroleum Society).
3.	Those standards require that we plan and perform a review to obtain reasonable assurance as to whether the reserves data are free of material misstatement. A review also includes assessing whether the reserves data are in accordance with principles and definitions presented in the COGE Handbook.
4.	The following table sets forth the estimated future net revenue (before deduction of income taxes) attributed to proved plus probable reserves, estimated using forecast prices and costs and calculated using a discount rate of 10 percent, included in the reserves data of the Corporation reviewed by us for the year ended December 31, 2003, and identifies the respective portions thereof that we have reviewed and reported on to the Corporation’s board of directors:

Independent Qualified Reserves Evaluator	Description and Preparation Date of	Location of Reserves (Country or Foreign	Net Present Value of Future Net Revenue (before income taxes, 10% discount rate)
or Auditor	Audit Report	Geographic Area)	Audited		Evaluated		Reviewed		Total
Gilbert Laustsen Jung Associates Limited	December 31, 2003	Canada		—		—	$	10,828	$	10,828

A-4

5.	In our opinion, the reserves data respectively reviewed by us have, in all material respects, been determined and are in accordance with the COGE Handbook. We express no opinion on the reserves data that we reviewed but did not audit or evaluate.
6.	We have no responsibility to update our reports referred to in paragraph 4 for events and circumstances occurring after their respective preparation dates.
7.	Because the reserves data are based on judgments regarding future events, actual results will vary and the variations may be material.
	Executed as to our report referred to above:
	March 12, 2004, Calgary, Alberta, Canada.

GILBERT LAUSTSEN JUNG ASSOCIATES LIMITED
Per:	(signed) “Jodi Anhorn” Jodi Anhorn

A-5

APPENDIX B

B-1

FORM 51-101F3
REPORT OF
MANAGEMENT AND DIRECTORS
ON OIL AND GAS DISCLOSURE

This is the form referred to in item 3 of section 2.1 of National Instrument 51-101 Standards of Disclosure for Oil and Gas Activities (“NI 51-101”). This form does not apply in British Columbia.

1.	Terms to which a meaning is ascribed in NI 51-101 have the same meaning in this form.1
2.	The report referred to in item 3 of section 2.1 of NI 51-101 shall in all material respects be as follows:
	Report of Management and Directors on Reserves Data and Other Information
	Management of Hawker Resources Inc. (the “Corporation”) are responsible for the preparation and disclosure of information with respect to the Corporation’s oil and gas activities in accordance with securities regulatory requirements. This information includes reserves data, which consist of the following:

3.	(a)	proved and proved plus probable oil and gas reserves estimated as at December 31, 2003 using forecast prices and costs; and
	(b)	the related estimated future net revenue; and
4.	(a)	proved oil and gas reserves estimated as at December 31, 2003 using constant prices and costs; and
	(b)	the related estimated future net revenue.

	Independent qualified reserves evaluators have evaluated and reviewed, respectively, the Corporation’s reserves data. The reports of the independent qualified reserves evaluators will be filed with securities regulatory authorities concurrently with this report;
	The Reserves Committee of the board of directors of the Corporation has
5.	reviewed the Corporation’s procedures for providing information to the independent qualified reserves evaluator and qualified reserves auditor;
6.	met with the independent qualified reserves evaluator to determine whether any restrictions affected the ability of the independent qualified reserves evaluators to report without reservation and, because of the proposal to change the independent qualified reserves evaluators, to inquire whether there had been disputes between the previous independent qualified reserves evaluators or qualified reserves auditors and management; and
7.	reviewed the reserves data with management and the independent qualified reserves evaluators.
	The Reserves Committee of the board of directors has reviewed the Corporation’s procedures for assembling and reporting other information associated with oil and gas activities and has reviewed that information with management. The board of directors has, on the recommendation of the Reserves Committee approved

¹ For the convenience of readers, Appendix 1 to Companion Policy 51-101CP sets out the meanings of terms that are printed in italics in sections 1 and 2 of this Form or in NI 51-101, Form 51-101F1, Form 51-101F2 or the Companion Policy.

B-2

8.	the content and filing with securities regulatory authorities of the reserves data and other oil and gas information;
9.	the filing of the reports of the independent qualified reserves evaluator and the independent qualified reserves auditor on the reserves data; and
10.	the content and filing of this report.
	Because the reserves data are based on judgments regarding future events, actual results will vary and the variations may be material.

(signed) “David A. Tuer” David A. Tuer President and Chief Executive Officer	(signed) “Terry C. Schmidtke” Terry C. Schmidtke Senior Vice President, Operations and Chief Operating Officer
(signed) “Ronald P. Mathison” Ronald P. Mathison Director	(signed) “Martin A. Lambert” Martin A. Lambert Director

March 17, 2004

B-3 EX-6 8 o12483exv6.htm NOTICE OF MEETING AND INFORMATION CIRCULAR

Exhibit 6

HAWKER RESOURCES INC.

Notice of Annual and Special Meeting of Shareholders
and Information Circular

April 28, 2004

Dear Shareholders,

You are invited to join us at Hawker Resources Inc.’s annual and special meeting of shareholders which will be held at the First Canadian Centre Conference Centre, 350 – 7th Avenue S.W., Calgary, Alberta, on Wednesday, April 28, 2004 at 10:00 a.m. (Calgary time).

The following Information Circular describes the business to be conducted at the meeting. We hope that you will take the time to consider the information on these matters set out in the circular. It is important that you exercise your vote. Instructions on how to vote your shares are on the first two pages of the circular.

At the meeting there will be an opportunity to ask questions and meet your fellow shareholders. We look forward to your participation.

Sincerely,

(Signed) Ronald P. Mathison Ronald P. Mathison
Chairman of the Board (Signed) David A. Tuer David A. Tuer
President and Chief Executive Officer

HAWKER RESOURCES INC.

NOTICE OF ANNUAL AND SPECIAL MEETING OF SHAREHOLDERS
APRIL 28, 2004

TO THE SHAREHOLDERS OF HAWKER RESOURCES INC.

NOTICE IS HEREBY GIVEN that the annual and special meeting (the “Meeting”) of shareholders of Hawker Resources Inc. (the “Corporation”) will be held at First Canadian Centre Conference Centre, 350 – 7th Avenue S.W., Calgary, Alberta, on Wednesday, April 28, 2004 at 10:00 a.m. (Calgary time) for the following purposes:

1.	to receive the annual report and the financial statements of the Corporation for the year ended December 31, 2003 together with the report of the auditors thereon;
2.	to fix the number of directors to be elected at the meeting at 6 members and to elect the directors of the Corporation for the ensuing year;
3.	to consider, and if thought appropriate, to pass an ordinary resolution approving future private placements of up to 50% of the issued and outstanding common shares of the Corporation, at any time until the next annual meeting of shareholders, subject to the policies of The Toronto Stock Exchange;
4.	to consider, and if thought appropriate, to pass an ordinary resolution approving amendments to the Corporation’s stock option plan to provide for a cash payment feature and to increase the number of common shares reserved for issuance thereunder;
5.	to consider, and if thought appropriate, to pass a special resolution authorizing an amendment to the Corporation’s articles to reclassify the Corporation’s class A common shares into common shares;
6.	to appoint auditors for the Corporation for the ensuing year and to authorize the directors to fix their remuneration; and
7.	to transact such other business as may properly be brought before the Meeting or any adjournment or adjournments thereof.

Shareholders are referred to the accompanying Information Circular dated March 5, 2004 (the “Information Circular”) for more detailed information with respect to the matters to be considered at the Meeting.

A shareholder may attend the Meeting in person or may be represented thereat by proxy. Shareholders who are unable to attend the Meeting in person are requested to date, sign and return the accompanying form of proxy, or other appropriate form of proxy, in accordance with the instructions set forth in the Information Circular. A proxy will not be valid unless it is deposited at the offices of Computershare Trust Company of Canada, 100 University Avenue, 9th Floor, Toronto, Ontario, M5J 2Y1 Attention: Proxy Department, not less than forty-eight (48) hours (excluding Saturdays, Sundays and holidays) before the Meeting, or any adjournment thereof. A person appointed as proxyholder need not be a shareholder of the Corporation.

DATED the 5th day of March, 2004.
	BY ORDER OF THE BOARD OF DIRECTORS
	(signed) David A. Tuer President and Chief Executive Officer

HAWKER RESOURCES INC.

INFORMATION CIRCULAR
FOR THE ANNUAL AND SPECIAL MEETING
TO BE HELD ON APRIL 28, 2004 AT 10:00 A.M.

SOLICITATION OF PROXIES

     This information circular (the “Circular”) is furnished in connection with the solicitation of proxies by the management of Hawker Resources Inc. (the “Corporation”) for use at the annual and special meeting of the shareholders of the Corporation to be held at First Canadian Centre Conference Centre, 350 – 7th Avenue S.W., in the City of Calgary, in the Province of Alberta, on April 28, 2004 at 10:00 o’clock in the morning (MST) (the “Meeting”) and at any adjournments thereof, for the purposes set forth in the accompanying notice of meeting. The solicitation of proxies will be primarily by mail, but may also be by telephone, telegraph or oral communications by the directors, officers and regular employees of the Corporation. The costs of preparation and mailing of the notice of meeting, form of proxy and this Circular as well as any such solicitation referred to above will be borne by the Corporation. Except as otherwise stated herein the information contained herein is given as of March 5, 2004.

APPOINTMENT OF PROXYHOLDERS AND DISCRETIONARY AUTHORITY

     A shareholder has the right to appoint a person or company (who need not be a shareholder of the Corporation) other than David A. Tuer and Ronald P. Mathison, the management designees, to attend and act for the shareholder at the Meeting. Such right may be exercised by inserting in the blank space provided in the accompanying form of proxy the name of the person or company to be appointed and deleting the names of the management designees or by completing another proper form of proxy and, in either case, depositing the resulting form of proxy at Computershare Trust Company of Canada, 100 University Avenue, 9th Floor, Toronto, Ontario, M5J 2Y1, Attention: Proxy Department, at least 48 hours before the Meeting for which it is to be used. The proxy shall be in writing and shall be executed by the shareholder or an attorney authorized in writing or, if the shareholder is a corporation, under its corporate seal or by an officer or attorney thereof duly authorized.

     All shares represented at the Meeting by properly executed proxies will be voted in accordance with the instructions of the shareholders on any ballot that may be called for and where a choice with respect to any matter to be acted upon has been specified in the form of proxy, the shares represented by the proxy will be voted or withheld from voting in accordance with such specification. In the absence of any such specifications, the management designees, if named as proxy, will vote in favour of all the matters set out therein. If a shareholder appoints a person designated in the form of proxy as nominee and a choice with respect to any matters to be acted upon has not been specified, the proxy will be voted in favour of all the matters set out therein.

     The enclosed form of proxy, when properly signed, also confers discretionary authority upon the persons named therein with respect to amendments or variations to matters identified in the notice of meeting and with respect to other matters that may properly come before the Meeting or any adjournment thereof. Management of the Corporation is not aware of any matters that are to be presented at the Meeting other than the matters set forth in the notice of meeting. If other matters or amendments or variations do properly come before the Meeting, the persons named in the accompanying form of proxy will vote according to their best judgment.

REVOCATION OF PROXIES

     A shareholder or intermediary who has given a proxy, or an attorney authorized in writing, may revoke it as to any matter upon which a vote has not already been cast pursuant to the authority conferred by the proxy, by instrument in writing executed by the shareholder or an attorney authorized in writing, or, if the shareholder is a corporation, under its corporate seal or by an officer or attorney thereof duly authorized in writing, and deposited either at the registered office of the Corporation or the office of Computershare Trust Company of Canada, 100 University Avenue, 9th Floor, Toronto, Ontario, M5J 2Y1, Attention: Proxy Department, at any time up to and including the last business day preceding the day of the Meeting or any adjournment thereof at which the proxy is to be used, or deposited with the Chairman of such Meeting on the day of the Meeting or adjournment thereof, or by

executing a proxy bearing a later date and depositing the new proxy at the office of Computershare Trust Company of Canada, 100 University Avenue, 9th Floor, Toronto, Ontario, M5J 2Y1, Attention: Proxy Department, at any time up to and including the last business day preceding the day of the Meeting or any adjournment thereof at which the proxy is to be used, or with the Chairman of such Meeting on the day of the Meeting or any adjournment thereof. In addition, a proxy may be revoked by the shareholder personally attending at the Meeting and voting his or her shares.

BENEFICIAL HOLDERS OF SHARES

     The information set forth in this section is of significant importance to many shareholders of the Corporation, as a substantial number of the shareholders do not hold their common shares (“Common Shares”) in their own name. Shareholders who do not hold their Common Shares in their own name (referred to in this Circular as “Beneficial Shareholders”) should note that only proxies deposited by shareholders whose names appear on the records of the Corporation as the registered holders of Common Shares can be recognized and acted upon at the Meeting. If Common Shares are listed in an account statement provided to a shareholder by a broker, then in almost all cases those Common Shares will more likely be registered under the name of the broker or an agent of a broker. In Canada, the vast majority of such shares are registered under the name of CDS & Co., (the registration name for The Canadian Depositary for Securities, which acts as nominee for many Canadian brokerage firms). Common Shares held by brokers or their nominees can only be voted upon the instructions of the Beneficial Shareholders. Without specific instructions, brokers/nominees are prohibited from voting Common Shares for their clients. The Corporation does not know for whose benefit the Common Shares registered in the name of CDS & Co. are held. Therefore, Beneficial Shareholders cannot be recognized at the Meeting for purposes of voting the Common Shares in person or by way of proxy, except as set out below.

     Applicable regulatory policy requires intermediaries/brokers to seek voting instructions from Beneficial Shareholders in advance of shareholder meetings. Every intermediary/broker has its own mailing procedures and provides its own return instructions, which should be carefully followed by Beneficial Shareholders in order to ensure that the Common Shares are voted at the Meeting. Often, the form of proxy supplied to a Beneficial Shareholder by its broker is identical to that provided to registered shareholders. However, its purpose is limited to instructing the registered shareholder how to vote on behalf of the Beneficial Shareholder. The majority of brokers now delegate responsibility for obtaining instructions from clients to ADP Investor Communications (“ADP”). ADP typically applies a special sticker to the proxy forms, mails those forms to the Beneficial Shareholders and asks Beneficial Shareholders to return the proxy forms to ADP. ADP then tabulates the results of all instructions received and provides appropriate instructions respecting the voting of Common Shares to be represented at the Meeting. A Beneficial Shareholder receiving a proxy with an ADP sticker on it cannot use that proxy to vote Common Shares directly at the Meeting — the proxy must be returned to ADP well in advance of the Meeting in order to have the Common Shares voted.

     Although a Beneficial Shareholder may not be recognized directly at the Meeting for purposes of voting Common Shares registered in the name of his or her broker (or agent of the broker), a Beneficial Shareholder may attend the Meeting as proxy holder for the registered holder of Common Shares and vote his or her Common Shares in that capacity. Beneficial Holders of Common Shares who wish to attend the Meeting and indirectly vote their Common Shares as proxy holder for the registered holder of such shares should enter their own names in the blank space on the form of proxy provided to them and return the same to their broker (or broker’s agent) in accordance with the instructions provided by such broker (or agent), well in advance of the Meeting.

VOTING SHARES AND PRINCIPAL HOLDERS THEREOF

     March 5, 2004, is the record date for determination of shareholders of the Corporation entitled to notice of and to vote at the Meeting, provided that to the extent a shareholder transfers the ownership of any Common Shares after the record date and the transferee of those shares establishes that he or she owns such shares and requests not later than 10 days before the Meeting that the transferee’s name be included in the shareholders’ list before the Meeting, such transferee is entitled to vote such shares at the Meeting. As at March 5, 2004, the Corporation had 35,997,200 Common Shares outstanding, each share carrying the right to one vote.

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     To the knowledge of the directors and officers of the Corporation, other than Allan P. Markin, no person or company beneficially owns, directly or indirectly, or exercises control or direction over voting securities carrying more than 10% of the voting rights attached to all voting securities of the Corporation. Mr. Markin has advised the Corporation that he holds 3,812,678 Common Shares, representing approximately 11% of the issued and outstanding Common Shares.

EXECUTIVE COMPENSATION

     The following table summarizes, for the periods indicated, the compensation paid by the Corporation to each individual who served as Chief Executive Officer of the Corporation in 2003 and the three most highly compensated executive officers (the “Named Executive Officers”) whose total salary and bonus exceeded $100,000 and who were serving as executive officers on December 31, 2003.

Summary Compensation Table

											Long Term
				Annual Compensation							Compensation
									Other Annual		Securities under		All Other
Name and				Salary			Bonus		Compensation(1)		Options Granted		Compensation
Principal Position		Year		($)			($)		($)		(#)		($)
David A. Tuer(2)			2003		175,000			135,000		17,625		—		—
	President and Chief		2002		—			—		—		—		—
	Executive Officer		2001		—			—		—		—		—
Jim Silye(3)			2003		—	(4)		—		—		—		—
	President and Chief		2002		85,250			—		—		75,000		—
	Executive Officer		2001		—			—		—		—		—
Barry R. Herring			2003		100,000			60,000		11,122		100,000		—
	Senior Vice President, Finance		2002		—			—		—		—		—
	and Chief Financial Officer		2001		—			—		—		—		—
Terry C. Schmidtke			2003		100,000			60,000		10,732		75,000		—
	Senior Vice President, Operations		2002		—			—		—		—		—
	and Chief Operating Officer		2001		—			—		—		—		—
Joe Straka			2003		90,000	(5)		—		6,519		50,000		—
	Director, Exploration		2002		—			—		—		—		—
			2001		—			—		—		—		—

Notes:

(1)	The value of perquisites and benefits for each Named Executive Officer is less than the lesser of $50,000 and 10% of total annual salary and bonus.
(2)	Appointed Chief Executive Officer on January 6, 2003.
(3)	Appointed President and Chief Executive Officer on May 7, 2002. Terminated employment as Chief Executive Officer on January 6, 2003, and terminated employment as President on April 3, 2003.
(4)	A corporation controlled by Mr. Silye received $94,577 for consulting services from the period of January 2003 to the end of June 2003.
(5)	A corporation controlled by Mr. Straka received $32,807 for consulting services provided to the Corporation prior to Mr. Straka’s appointment as Director, Exploration.

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Options Granted During The Most Recently Completed Financial Year

								Market Value of
								Common Shares
	Common Shares Under		% of Total			Exercise or		Underlying Options
	Options Granted		Options Granted			Base Price		on Date of Grant
	(#)		In Fiscal Year			($/Security)		($/Security)		Expiry Date
David A. Tuer		—		—			—		—		—
Jim Silye		—		—			—		—		—
Barry R. Herring		100,000		23.4	%	$	3.45	$	3.45	May 30, 2008
Terry C. Schmidtke		75,000		17.5	%	$	3.45	$	3.45	May 30, 2008
Joe Straka		50,000		11.7	%	$	3.90	$	3.90	July 1, 2008

Notes:

(1)

Pursuant to the material terms of the Corporation’s stock option plan (the “Stock Option Plan”) under which the options were granted, the exercise price is not less than the closing market price on The Toronto Stock Exchange (“TSX”) on the day preceding the grant and are exercisable after one year as to one-third per year plus the portion of the optioned shares which could have been exercised in a previous year.

(2)

The securities under option represent Common Shares.

Aggregated Options Exercised During The Most Recently Completed Financial Year And Financial Year-End Option Values

									Value of Unexercised
					Unexercised Options as at				In-the-Money Options as at
	Securities				December 31, 2003				December 31, 2003
	Acquired on		Aggregate Value		(#)				($)(1)
	Exercise		Realized
	(#)		($)		Exercisable		Unexercisable		Exercisable		Unexercisable
David A. Tuer		—		—		—		—		—		—
Jim Silye		75,000		142,750		—		—		—		—
Barry R. Herring		—		—		—		100,000		—	$	165,000
Terry C. Schmidtke		—		—		—		75,000		—	$	123,750
Joe Straka		—		—		—		50,000		—	$	60,000

Note:

(1) The closing price of the Corporation’s common shares on the TSX on December 31, 2003 was $5.10.

Report On Executive Compensation

     The Compensation Committee approves the compensation paid to the Corporation’s officers and in general the overall compensation paid by the Corporation to its employees. The compensation paid includes base salary, a year-end cash bonus, a cash bonus paid twice per year only if established performance targets are met, and awards of options to acquire the Corporation’s Common Shares pursuant to the Stock Option Plan. These forms of compensation are considered both individually and collectively to determine the compensation levels paid to each of the Corporation’s officers and employees. Compensation levels of the Corporation’s employees are reviewed annually following completed performance reviews by management.

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     In arriving at the compensation levels paid by the Corporation, the Compensation Committee takes into account a number of factors, including the responsibilities and experience of the individuals, the performance of the individuals and the overall performance of the Corporation. The Compensation Committee also uses and consults available compensation surveys conducted on the industry for companies of comparable size.

     The Compensation Committee believes that, to the extent possible, granting of stock options should be used to augment the overall compensation package. To remain competitive with its industry peer group the board of directors believes it is important that the Corporation has an option plan available. The Stock Option Plan is structured so that the exercise price can not be lower than market value at the time of granting options, the options are vested over three years commencing one year after granting, and no re-pricing of options is allowed. These options provide an incentive for all employees and officers to ensure they are striving to maximize shareholder value.

     Base salaries for officers were previously set at a reasonable level for similar positions in oil and natural gas companies of comparable size. In addition, compensation in the form of yearly cash bonuses was provided to recognize performance. These cash payments were supplemented with the awarding of additional stock options. The Compensation Committee believes this is appropriate to ensure that overall compensation levels remain competitive to attract and retain quality employees while also ensuring that overall compensation levels do not become excessive. The compensation of the Corporation’s Chief Executive Officer is based on the same criteria set out above.

     Submitted by the Compensation Committee

     Keith T. Smith (Chair)
     Martin A. Lambert

Performance Graph

     The following performance graph illustrates, over the five year period ended December 31, 2003, the cumulative return to shareholders of an investment in the common shares of the Corporation compared to the cumulative total shareholder return on the S&P/TSX Composite Index, assuming the reinvestment of dividends, where applicable.

At December 31	1998		1999		2000		2001		2002		2003
♦ S&P/TSX Composite Index	$	100	$	129.7	$	137.7	$	118.5	$	102.0	$	126.7
• Hawker Resources Inc.(1)	$	100	$	62.8	$	45.6	$	14.9	$	2.2	$	16.1

Note:

(1) The Corporation announced its intention to change its business from a pharmaceutical development company to an oil and gas company on January 6, 2003.

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Compensation Of Directors

     The Corporation’s directors were not paid for attendance at board and committee meetings for the fiscal year ended December 31, 2003, however, the Corporation reimburses directors in respect of any reasonable expenses incurred by them while acting in their capacity as a director. No reimbursement of expenses was paid to members of the board of directors during the fiscal year ended December 31, 2003.

Employment Agreements

     Pursuant to an employment agreement dated as of April 3, 2003, Mr. Tuer is entitled to an annual base salary of $175,000 per year and to a discretionary bonus of up to a maximum of 200% of his base salary as determined by the board of directors of the Corporation in light of the Corporation’s overall operational and financial performance. In the event Mr. Tuer is terminated other than for cause, he is entitled to a payment equal to his annual base salary at the date of termination multiplied by 1.5 and his average bonus entitlement for the two preceding years multiplied by 1.5.

STATEMENT OF CORPORATE GOVERNANCE PRACTICES

     The Corporation’s board of directors continually evaluates the corporate governance policies and procedures of the Corporation. Regulatory changes that have occurred as a result of the enactment of the Sarbanes-Oxley Act 2002, and proposed changes to the TSX Corporate Governance Guidelines are continually monitored by the Corporation’s Board of directors and the board will take appropriate action as regulatory changes occur. In the following table, the Corporation’s corporate governance procedures are compared with the current TSX guidelines on corporate governance.

	TSX Guideline		Hawker Alignment	Commentary
1.	The board of directors of every corporation should explicitly assume responsibility for the stewardship of the corporation and, as part of the overall stewardship responsibility, should assume responsibility for the following matters:		Yes	The board of directors acknowledges its responsibility for the stewardship of the Corporation in overseeing the business and affairs of the Corporation. In particular, the Board:
	(a)	adoption of a strategic planning process;	Yes	(a)	ensures the Corporation has appropriate short and long term goals and has implemented a strategic planning process;
	(b)	the identification of the principal risks of the corporation’s business and ensuring the implementation of appropriate systems to manage these risks;	Yes	(b)	identifies the principal business risks and ensures proper systems are in place to manage these risks and protect shareholder value;
	(c)	succession planning, including appointing, training and monitoring senior management;	Yes	(c)	ensures that senior management is of the highest caliber and that adequate systems are in place for the appointment, development and monitoring of senior management to facilitate the orderly succession of senior management;
	(d)	a communication policy for the corporation;	Yes	(d)	ensures the Corporation’s communication policy enables it to effectively communicate with shareholders, other stakeholders and the public generally, including the capital markets;

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	TSX Guideline		Hawker Alignment	Commentary
	(e)	the integrity of the corporation’s internal control and management information systems.	Yes	(e)	ensures the Corporation has in place adequate internal controls and management information systems.
2.	The board of directors of every corporation should be constituted with a majority of individuals who qualify as unrelated directors as defined by the TSX.		Yes	The board of directors is comprised of 6 members, all of whom have extensive and varied business experience. The majority of the directors are non-management “unrelated directors”, as defined in the Report of The Toronto Stock Exchange Committee on Corporate Governance in Canada. The Corporation does not have a significant shareholder with the ability to exercise a majority of the votes for the election of directors.
3.	The application of the definition of “unrelated director” to each director should be the responsibility of the board and the analysis of the application of the principles supporting the conclusions of the board should be disclosed on an annual basis.		Yes	All of the members of the board of directors of the Corporation are non-management “unrelated directors” with the exception of Mr. D.A. Tuer, President and Chief Executive Officer. All other members of the board of directors are free from any interest and any business or other relationship that could reasonably be perceived to materially interfere with the director’s ability to act with a view to the best interests of the Corporation.
4.	The board of directors of every corporation should appoint a committee of directors composed exclusively of outside, i.e., non-management, directors, a majority of whom are unrelated directors, with the responsibility of proposing to the full board new nominees to the board and for assessing directors on an ongoing basis.		Yes	The Board created the Corporate Governance Committee comprised exclusively of non-management “unrelated directors” who are M.A. Lambert and R.P. Mathison, which is responsible for the identification and recommendation to the board of individuals qualified to become board members and for the ongoing assessment of directors.
5.	Every board of directors should implement a process to be carried out by the nominating committee or other appropriate committee for assessing the effectiveness of the board as a whole, the committees of the board and the contribution of individual directors.		Yes	The Corporate Governance Committee is responsible for assessing the effectiveness of the board as a whole, the committees of the board and the contribution of individual directors. The assessment is ongoing and includes an annual questionnaire that each director must complete. The committee reviews the submitted questionnaires and the results constitute part of the report to the full board.
6.	Every corporation, as an integral element of the process for appointing new directors, should provide an orientation and education program for new recruits to the board.		Yes	The Corporation has an informal orientation and education program, which allows unrestricted direct access by any board member to any member of senior management and their staff.

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	TSX Guideline	Hawker Alignment	Commentary
7.	Every board of directors should examine its size and, with a view to determining the impact of the number upon effectiveness, undertake, where appropriate, a program to reduce the number of directors to a number which facilitates more effective decision-making.	Yes	The Corporation’s Articles of Incorporation restrict the size of the Board to a maximum of 11 members. The Board continually monitors its decision-making effectiveness and where appropriate will make the necessary changes to establish a board size to facilitate effective decision-making.
8.	The board of directors should review the adequacy and form of the compensation of directors and ensure compensation realistically reflects the responsibilities and risk involved in being an effective director.	Yes	The Compensation Committee comprising Messrs K.T. Smith and M.A. Lambert, reviews the adequacy and structure of directors’ compensation and make recommendations designed to ensure the directors’ compensation realistically reflects the responsibilities of the board of directors. The Compensation Committee is presently reviewing director’s compensation levels with a view to making appropriate adjustments to director’s compensation for the 2004 year to reflect the increased governance responsibilities being placed on the directors by the Corporation.
9.	Committees of the board of directors should generally be composed of outside directors, a majority of whom are unrelated directors, although some board committees, such as the executive committee, may include one or more inside directors.	Yes	The Board has established four committees; (i) the Audit Committee as described in paragraph 13; (ii) the Compensation Committee as described in paragraph 8, (iii) the Corporate Governance Committee as described in paragraphs 4, 5 and 10; and, (iv) the Reserves Committee comprised entirely of non-management “unrelated directors” who are S.G.P. Grad and K.T. Smith. The Reserves Committee communicates directly with the Corporation’s external independent engineering firm to review the qualifications of and procedures used by the independent engineers in determining the estimate of the Corporation’s quantities and value of petroleum and natural gas reserves remaining.
10.	Every board of directors should expressly assume responsibility for, or assign to a committee of directors the general responsibility for, developing the corporation’s approach to governance issues. This committee would, amongst other things, be responsible for the corporation’s response to these governance guidelines.	Yes	The Corporate Governance Committee is expressly charged with the responsibility for developing the Corporation’s approach to governance issues and is responsible for the Corporation’s response to these governance guidelines.

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	TSX Guideline	Hawker Alignment	Commentary
11.	The board of directors, together with the CEO, should develop position descriptions for the board and for the CEO, including the definition of the limits to management’s responsibilities. In addition, the board should approve or develop the corporate objectives, which the CEO is responsible for meeting.	Yes	The Corporate Governance Committee is preparing the Corporation’s corporate governance guidelines for consideration by the full board. The board is responsible for the stewardship of the Corporation. Any responsibility that is not delegated to senior management or a Board committee remains with the full board. In addition, the board in conjunction with senior management determines the limits of management’s responsibilities and establishes annual corporate objectives which management is responsible for meeting.
12.	Every board of directors should have in place appropriate structures and procedures to ensure that the board can function independently of management.	Yes	The board of directors functions independently of management and appoints the Chairman. At least once during each year, immediately following the termination of a regularly scheduled Board meeting, the non-management “unrelated directors” meets in executive session without the presence of management to discuss whatever topics are appropriate. These meetings are chaired by the Chairman of the Corporate Governance Committee. Additional executive sessions may be scheduled from time to time as determined by a majority of the non-management “unrelated directors” in consultation with the Chairman of the Board and Chairman of the Corporate Governance Committee.
13.	The audit committee of every board of directors should be composed only of outside directors. The roles and responsibilities of the audit committee should be specifically defined so as to provide appropriate guidance to audit committee members as to their duties. The audit committee should have direct communication channels with the internal and external auditors to discuss and review specific issues as appropriate. The audit committee duties should include oversight responsibility for management reporting on internal control.	Yes	The Board created the Audit Committee comprised of Messrs. B.J. Kenway, R.P. Mathison and M.A. Lambert who are all non-management “unrelated directors”. The Audit Committee is responsible for selecting and recommending the appointment of the Corporation’s independent auditors by the shareholders, pre-approving all audit and non-audit services to be provided to the Corporation and establishing the fees to be paid to the independent auditors. The committee meets directly with the Corporation’s independent auditors both with management and independent of management and is responsible for monitoring the preparation and audit of the Corporation’s financial statements and the establishment of appropriate internal controls. In addition the committee provides an avenue for communication between each of the independent auditors, financial and senior management and the board.

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	TSX Guideline	Hawker Alignment	Commentary
14.	The board of directors should implement a system, which enables an individual director to engage an outside adviser at the expense of the company in appropriate circumstances. The engagement of the outside advisor should be subject to the approval of an appropriate committee of the board.	Yes	The full board or any member of the board can engage outside advisors at the expense of the Corporation in appropriate circumstances.

FINANCIAL STATEMENTS AND AUDITORS’ REPORT

     The audited financial statements of the Corporation for the year ended December 31, 2003 and the Auditors’ Report thereon will be received at the Meeting. These statements and the Auditors’ Report are contained in the 2003 Annual Report of the Corporation, which is being provided to each shareholder entitled to receive a copy of the notice of meeting and this Circular.

ELECTION OF DIRECTORS

     The board of directors is elected annually and consists of such number of directors as fixed from time to time by resolution of the directors, such number being not less than one and not more than 11. The number of directors to be elected at the Meeting is fixed at six.

     Unless otherwise directed, the persons named in the accompanying form of proxy intend to vote for the election, as directors of the Corporation, of the nominees whose names are set forth below. All of the nominees are currently directors of the Corporation. Each director elected will hold office until the close of the next annual meeting or until his successor is duly elected, unless his office is vacated earlier in accordance with the Corporation’s by-laws or applicable law. The Corporation is required to have an Audit Committee, which is comprised of Messrs. B.J. Kenway, R.P. Mathison and M.A. Lambert. The Corporation does not have an Executive Committee.

			Number of Common
			Shares Beneficially
Name and Municipality of	Position with	Principal Occupation	Owned/Controlled or
Residence	Corporation	Within Last Five Years	Directed			Director Since
David A. Tuer Calgary, Alberta	President and Chief Executive Officer and a Director	President and Chief Executive Officer and a Director of the Corporation. Prior to October 2001, President, Chief Executive Officer and a Director of PanCanadian Energy Corporation.		825,466		January 6, 2003
Ronald P. Mathison(1)(2) Calgary, Alberta	Chairman and a Director	President of Matco Investments Ltd. (a private investment company); prior to 1999, Principal, Peters & Co. Limited.		1,655,374	(5)	April 3, 2003
Stan G.P. Grad(3) Calgary, Alberta	Director	Independent Businessman.		47,050		April 21, 2003

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			Number of Common
			Shares Beneficially
Name and Municipality of	Position with	Principal Occupation	Owned/Controlled or
Residence	Corporation	Within Last Five Years	Directed			Director Since
Bruce J. Kenway, C.A.(1) Calgary, Alberta	Director	Partner, Kenway Mack Slusarchuk Stewart LLP, Chartered Accountants.		70,637		March 31, 1994
Martin A. Lambert(1)(2)(4) Calgary, Alberta	Director	Partner, Bennett Jones LLP (a law firm). Prior to May 2000, Chief Executive Officer and a partner, Bennett Jones LLP.		44,400	(6)	April 3, 2003
Keith T. Smith(3)(4) Calgary, Alberta	Director	President and Chief Executive Officer of zed.i solutions inc. from April 2001. Prior thereto, Vice President, Corporate Development with zed.i solutions inc. since April 2000 and Executive Vice President of Acanthus Resources Ltd., a private oil and gas company, from August 1998 to April 2000.		22,575		April 3, 2003

Notes:

(1)	Member of the Audit Committee.
(2)	Member of the Corporate Governance Committee.
(3)	Member of the Reserves Committee.
(4)	Member of the Compensation Committee.
(5)	Includes 1,430,934 Common Shares held by Matco Capital Ltd. and 30,290 Common Shares held by 970183 Alberta Ltd., entities indirectly controlled by Mr. Mathison.
(6)	Excludes 1,430,934 Common Shares held by Matco Capital Ltd. in respect of which Mr. Lambert has an indirect minority beneficial interest.

FUTURE PRIVATE PLACEMENTS

     The Corporation from time to time investigates opportunities to raise financing on advantageous terms. The Corporation may undertake one or more financings over the next year and, if undertaken, expects some of them to be structured as private placements of treasury shares.

     Under the rules of the TSX the aggregate number of shares of a listed company which are issued or made subject to issuance (i.e. issuable under a share purchase warrant or option or other convertible security) by way of one or more private placement transactions during any particular six-month period must not exceed 25% of the number of shares outstanding (on a diluted basis) prior to giving effect to such transactions (the “TSX 25% Rule”), unless there has been shareholder approval of such transactions.

     The application of the TSX 25% Rule may restrict the availability to the Corporation of funds which it may wish to raise in the future by private placement of its securities.

     In particular, management of the Corporation considers it to be in the best interests of the Corporation to solicit private placement funds for working capital and its operations. The TSX has a working practice that it will accept advance approval by shareholders in anticipation of private placements that may exceed the TSX 25% Rule, provided such private placements are completed within 12 months of the date such advance shareholder approval is given.

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     The Corporation currently has 35,997,200 Common Shares issued and outstanding and the Corporation proposes that the maximum number of Common Shares which either would be issued or made subject to issuance under one or more private placements in the twelve month period commencing on April 28, 2004 would not exceed 17,998,600 Common Shares in the aggregate, or approximately 50% of the Corporation’s issued and outstanding shares as at March 5, 2004.

     Any private placement proceeded with by the Corporation under the advance approval being sought at the Meeting will be subject to the following additional restrictions:

(a)	it must be substantially with parties at arm’s length to the Corporation;
(b)	it cannot materially affect control of the Corporation;
(c)	it must be completed within a twelve month period following the date the shareholder approval is given; and
(d)	it must comply with the private placement pricing rules of the TSX which currently require that the issue price per Common Share must not be lower than the closing market price of the Common Shares on the TSX on the trading day prior to the date notice of the private placement is given to the TSX (the “Market Price”), less the applicable discount, as follows:

Market Price	Maximum Discount
$0.50 or less	25%
$0.51 to $2.00	20%
Above $2.00	15%

(For these purposes, a private placement of unlisted convertible securities is deemed to be a private placement of the underlying listed securities at an issue price equal to the lowest possible price at which the securities are convertible by the holders thereof).

     In any event, the TSX retains the discretion to decide whether a particular placement is “substantially” at arm’s length or will materially affect control, in which case specific shareholder approval may be required.

     In anticipation that the Corporation may wish to enter into one or more private placements in the next 12 months that will result in it issuing and/or making issuable such number of its Common Shares, taking into account any shares that may be issued upon exercise of any warrants, options or other rights granted in connection with the private placements, that will exceed the TSX 25% Rule, at the Meeting the Corporation’s shareholders will be asked to consider and, if thought fit, to approve, a resolution authorizing the issuance by the Corporation, in one or more private placements during the twelve month period commencing April 28, 2004, of such number of securities as would result in the Corporation issuing or making issuable up to 17,998,600 Common Shares.

     In order for the foregoing resolution to be passed, it must be approved by a simple majority of votes cast by shareholders who vote in person or by proxy at the Meeting.

STOCK OPTION PLAN

     At the Meeting, resolutions will be proposed to amend the Stock Option Plan of the Corporation to provide for a cash payment feature and to increase the number of Common Shares reserved for issuance thereunder. The Stock Option Plan was established in May of 2000. At the Corporation’s annual and special meeting held April 3, 2003, the Corporation’s shareholders fixed the aggregate number of Common Shares reserved for issuance thereunder at 1,487,500.

Cash Payment Feature

     The Corporation recognizes the need to strike the proper balance between having a long term compensation program for employees and directors to align their interests with those of shareholders while addressing shareholder

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concerns about dilution caused by the continual granting and exercising of options pursuant to a stock option program. To advance both goals, management of the Corporation proposes a structure which it believes may substantially decrease the number of Common Shares issued pursuant to options. The Corporation proposes to provide optionholders, for both existing and future options, with the right to surrender vested options for cancellation in return for a direct cash payment from the Corporation, which would essentially be the same as the amount the optionholders would otherwise realize in exercising their options and immediately selling the Common Shares issued upon exercise. The choice to surrender options will be the optionholder’s and the Corporation will not have the right to, by its own decision, make the cash payment rather than issue Common Shares pursuant to the exercise of an option. The implementation of this proposal requires shareholder approval.

     The inclusion of this cash payment feature in options granted under the Corporation’s previously approved Stock Option Plan will enable the Corporation to provide the same benefits to optionholders and provide optionholders with a liquidity feature without increasing the number of outstanding Common Shares, to the extent that optionholders utilize this feature. The Corporation anticipates that some optionholders may utilize this feature rather than exercising their options because it will allow optionholders to realize the value of their options through a simplified procedure and without brokerage costs associated with the sale of the Common Shares acquired upon exercise of options. Under current law, the tax liability for optionholders will be essentially the same so long as it is the optionholder and not the Corporation which has the cash-out right.

     The cash payment feature will provide shareholders with the additional benefit of increased transparency of the cost of employee and director compensation as well as a tax advantage to the Corporation, since cash payments made for options surrendered will be deductible by the Corporation as an employment expense for income tax purposes. Under Canadian accounting rules, the Corporation will be required to recognize a liability and compensation expense for options granted with a cash payment feature. The liability to be recorded by the Corporation will equal the intrinsic value of the options, which is the amount by which the current market price exceeds the exercise price. The intrinsic value of options is zero upon grant. The compensation expense for an accounting period will equal the change in the intrinsic value of the options, such that, over the life of an option with a cash payment feature, the cumulative compensation expense recorded by the Corporation will equal the amount of money the Corporation will pay to the optionholder upon exercise of the cash payment feature.

     The board of directors considered a wide range of alternative strategies before determining that the cash payment feature is the optimum solution to concurrently address shareholder concerns regarding the use of options and to advance competitive long-term incentive objectives. Compensation levels and components must be consistent with industry norms in order to attract and retain skilled personnel. Industry norms dictate that the Corporation provide a long-term compensation incentive, which is best realized by providing compensation linked to Common Share performance. If such compensation is not to involve issuing new Common Shares, it must involve, either directly or indirectly, cash compensation. Most forms of cash compensation are taxed as employment income in the hands of the employee or director; therefore, the Corporation would be required to increase compensation levels to achieve the same net incentive if it were to adopt some alternative form of cash compensation. The board of directors believes that including the proposed cash payment feature in existing and future options is the best solution to substantially reduce shareholder dilution while maintaining industry norm compensation levels at a lower cost to the Corporation.

     The board of directors has approved amendments to the Stock Option Plan, subject to shareholder approval, to specifically provide that options granted thereunder may give the optionholder the right to surrender the option for cancellation and receive a cash payment from the Corporation based on the amount by which the market price of the Common Shares at the time of surrender exceeds the exercise price of the option.

     The amendments to the Stock Option Plan provide that the Common Shares subject to any option that is surrendered pursuant to the cash payment feature will be available for future options granted under the Stock Option Plan, as is the case for options which expire or are cancelled without having been exercised. As it is anticipated that some optionholders may utilize the cash payment feature, it is likely that, with an increase in the number of Common Shares reserved under the Stock Option Plan, a steady state of options granted and surrendered will be reached, requiring no further increases in the number of Common Shares reserved for option grants.

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     If the shareholders approve the amendment to the Stock Option Plan, it is anticipated that future options granted under the Stock Option Plan will contain this cash payment feature and that existing options will be amended to include the cash payment feature. If existing options are amended, at the time the amendments become effective the Corporation will record compensation expense and a liability equal to the intrinsic value of the options as determined on the effective date. The intrinsic value will be the amount by which the market price exceeds the exercise price of the amended options. Based on a market price of $5.25/Common Share, the intrinsic value of all the outstanding stock options as at March 5, 2004 is approximately $0.7 million.

Summary of Reasons to Support the Cash Payment Feature

The board of directors recommends implementing the cash payment feature for six principal reasons:

1.	The cash payment feature may reduce the dilution implied by existing unexercised options.
2.	The cash payment feature may reduce the dilution implied by future grants of options.
3.	The cash payment feature will, if utilized by optionholders, make the cost of the Stock Option Plan transparent, as the Corporation will recognize a liability and compensation expense for all cash payments made as a result of the surrender of options.
4.	The Corporation will realize tax deductions for cash payments made pursuant to the feature.
5.	Alternative long-term compensation incentive schemes involving cash payments would be more expensive for the Corporation.
6.	Optionholders who utilize the cash payment feature will no longer be required to pay broker fees to realize option value, and their tax liability will not be materially affected.

Increase in Number of Common Shares Issuable under the Stock Option Plan

     In order for the Stock Option Plan with the proposed cash payment feature to be self-sustaining, a sufficient number of Common Shares must be reserved for issue pursuant to options under the Stock Option Plan. The board of directors does not expect any significant number of such reserved Common Shares will be issued. Rather, an increased number of Common Shares reserved under the Stock Option Plan will allow the Corporation to grant options with a cash payment feature in quantities consistent with industry norms until the rate of options being surrendered for cash payments is sufficient to support subsequent option grants. An increase in Common Shares reserved under the Stock Option Plan is intended to facilitate a steady state of options being granted and surrendered, such that the requirement for any further increase will be unlikely. Accordingly, the board of directors has approved an amendment to the Stock Option Plan to increase the number of Common Shares that may be issued pursuant to options granted thereunder by 1,800,000 Common Shares, subject to the approval of the shareholders.

     The following table sets forth the number of Common Shares that may be subject to option grants under the Stock Option Plan, after the proposed amendment, as at March 5, 2004.

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			Common Shares		Maximum Common
	Common Shares		Available for		Shares Subject to
	Subject to		Future Option		and Available for
	Outstanding Options		Grants		Option Grants
Currently Approved		444,001		737,512		1,181,513
Proposed Increase		—		1,800,000		1,800,000
Total		444,001		2,537,512		2,981,513
% of Outstanding Common Shares		1.2%		7.0%		8.3%

     The board of directors recommends that shareholders vote in favour of both of the proposed resolutions relating to the Stock Option Plan. In order for the resolutions to be passed, they must be approved by a simple majority of votes cast by shareholders who vote in person or by proxy at the Meeting.

RECLASSIFICATION OF CLASS A SHARES

     The board of directors of the Corporation has determined that it is in the best interests of the Corporation to simplify the Corporation’s share structure by reclassifying the existing class A shares in the capital of the Corporation (the “Class A Shares”) into Common Shares. The board of directors believes that the liquidity and valuation of the Common Shares would likely be improved by converting its outstanding securities to a single class, as trading volumes would be aggregated into one security and any discount associated with the inferior security would be eliminated. In addition, the board of directors believes that the existence of a single class of securities contributes to good corporate governance as the Corporation’s share structure is simplified and made more transparent and understandable.

     There are currently 3,874,437 Class A Shares outstanding, which shares have all of the rights and privileges associated with the Common Shares, excluding the right to vote. The nominees for election as directors of the Corporation and the Named Executive Officers as a group control, directly and indirectly, an aggregate of 3,371,652 Class A Shares, representing 87% of the issued and outstanding Class A Shares. The reclassification of the Class A Shares would result in the issuance of an additional 3,874,437 Common Shares, which number represents approximately 10.7% of the current issued and outstanding Common Shares.

     The board of directors recommends that shareholders vote in favour of the proposed reclassification of the Class A Shares. Shareholders will be asked at the Meeting to consider, and if thought fit, to approve, with or without variation, the following resolution:

BE IT RESOLVED, as a special resolution, that the articles of incorporation of the Corporation be amended to reclassify the Class A Shares into Common Shares in the capital of the Corporation on a one for one basis and to remove the Class A Shares from the authorized capital of the Corporation, all as more particularly described in the Information Circular of the Corporation dated March 5, 2004.

     In order for the foregoing special resolution to be passed, it must be approved by a majority of not less than 66 2/3% of the votes cast by the holders of Common Shares and Class A Shares, voting as separate classes, who vote in person or by proxy at the Meeting.

     Under the Business Corporations Act (Alberta) (the “Act”), holders of Class A Shares may dissent in respect of the proposed amendment to the articles of incorporation of the Corporation by following the procedure prescribed in the Act which is summarized below.

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     A shareholder entitled to dissent and who complies with the Act is entitled to be paid by the Corporation the fair value of the Class A Shares held by him, determined as of the close of business on the last business day before the day on which the resolution is adopted. A registered shareholder may dissent only with respect to all of the Class A Shares held by such registered shareholder or with respect to all of the Class A Shares held on behalf of any one beneficial owner and registered in the dissenting shareholder’s name. Persons who are beneficial owners of Class A Shares registered in the name of a broker, custodian, nominee or other intermediary who wish to dissent should be aware that only the registered owners of Class A Shares are entitled to dissent. Accordingly, if you are a beneficial owner of Class A Shares desiring to exercise your right of dissent, you must make arrangements for such shares beneficially owned by you to be registered in your name prior to the time the written objection to the special resolution is required to be received by the Corporation or, alternatively, make arrangements for the registered holder of your Class A Shares to dissent on your behalf.

     Each shareholder who intends to dissent must comply with the provisions of Section 191 of the Act which provides, among other things, that each dissenting shareholder must, at or before the Meeting, send to the Corporation a written objection to the resolution in respect of which he is dissenting. If the shareholder and the Corporation cannot agree on the fair value for the Class A Shares, either the Corporation or the dissenting shareholder may apply to a Court by originating notice after the adoption of the resolution to fix the fair value. Upon an application being made the Corporation is obliged, unless the Court otherwise orders, to send to each dissenting shareholder a written offer to pay him an amount considered by the directors of the Corporation to be the fair value of his shares and a statement showing how the fair value was determined. A dissenting shareholder may accept the Corporation’s offer at any time before the Court fixes the fair value of his shares. If the Corporation’s offer is not accepted, the Court must make an order fixing the fair value of the shares, giving judgment in the amount in favour of each dissenting shareholder and determining the time in which the Corporation must pay the amount. The Court may also in its discretion allow a reasonable rate of interest. A dissenting shareholder is not required to give security for costs in respect of a court application and, except in special circumstances, is not required to pay the costs of the application or appraisal.

     A dissenting shareholder ceases to have any rights as a shareholder of the Corporation other than the right to be paid the fair value of his shares upon:

(a)	the action approved by the resolution from which the shareholder dissents becoming effective;
(b)	the making of an agreement between the Corporation and the shareholder for the purchase of his shares; or
(c)	the pronouncement of an order by the Court respecting the fair value of his shares.

     Prior to the occurrence of one of these events the shareholder may withdraw his dissent or the Corporation may rescind the resolution.

     The Corporation may not make a payment to a dissenting shareholder if there are reasonable grounds for believing that the Corporation is, or would after the payment be, unable to pay its liabilities as they become due, or the realizable value of the Corporation’s assets would thereby be less than the aggregate of its liabilities. In such a case, the Corporation must notify each dissenting shareholder that it is unable lawfully to pay for his shares. Each dissenting shareholder may then withdraw his notice of objection and be reinstated to his full rights as a shareholder, failing which he retains his status as a claimant against the Corporation to be paid when the Corporation is able to do so.

     The above is only a summary of the provisions of Section 191 of the Act and is qualified in its entirety by reference to the full text of Section 191 which is attached hereto as Exhibit “A”. These provisions are technical and complex. It is suggested that any shareholder wishing to dissent seek independent legal advice since the failure to comply strictly with the provisions of the Act may prejudice his or her right to dissent.

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APPOINTMENT OF AUDITORS

     The persons named in the accompanying form of proxy intend to vote for the appointment of Ernst & Young LLP as auditors of the Corporation for the ensuing year at remuneration to be fixed by the board of directors.

INTEREST OF CERTAIN PERSONS AND COMPANIES IN MATTERS TO BE ACTED UPON

     Management of the Corporation is not aware of any material interest of any director or nominee for director, or senior officer or anyone who has held office as such since the beginning of the Corporation’s last financial year, or any associate or affiliate of any of the foregoing in any matter to be acted on at the Meeting, except as disclosed herein.

APPROVAL OF CIRCULAR

     The contents and sending of this Circular has been approved by the board of directors of the Corporation.

CERTIFICATE

     The foregoing contains no untrue statement of a material fact and does not omit to state a material fact that is required to be stated or that is necessary to make a statement not misleading in light of the circumstances in which it was made.

     DATED at Calgary, Alberta, the 5th day of March, 2004.

(Signed) David A. Tuer	(Signed) Barry R. Herring
David A. Tuer	Barry R. Herring
President and Chief Executive Officer	Senior Vice President, Finance and Chief Financial Officer

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EXHIBIT “A”

SECTION 191 OF THE BUSINESS CORPORATIONS ACT (ALBERTA):

191(1) Subject to sections 192 and 242, a holder of shares of any class of a corporation may dissent if the corporation resolves to

(a)	amend its articles under section 173 or 174 to add, change or remove any provisions restricting or constraining the issue or transfer of shares of that class,
(b)	amend its articles under section 173 to add, change or remove any restrictions on the business or businesses that the corporation may carry on,
(c)	amalgamate with another corporation, otherwise than under section 184 or 187,
(d)	be continued under the laws of another jurisdiction under section 189, or
(e)	sell, lease or exchange all or substantially all its property under section 190.

(2)	A holder of shares of any class or series of shares entitled to vote under section 176, other than section 176(1)(a), may dissent if the corporation resolves to amend its articles in a manner described in that section.
(3)	In addition to any other right he may have, but subject to subsection (20), a shareholder entitled to dissent under this section and who complies with this section is entitled to be paid by the corporation the fair value of the shares held by the shareholder in respect of which the shareholder dissents, determined as of the close of business on the last business day before the day on which the resolution from which the shareholder dissents was adopted.
(4)	A dissenting shareholder may only claim under this section with respect to all the shares of a class held by the shareholder or on behalf of any one beneficial owner and registered in the name of the dissenting shareholder.
(5)	A dissenting shareholder shall send to the corporation a written objection to a resolution referred to in subsection (1) or (2)

(a)	at or before any meeting of shareholders at which the resolution is to be voted on, or
(b)	if the corporation did not send notice to the shareholder of the purpose of the meeting or of the shareholder’s right to dissent, within a reasonable time after the shareholder learns that the resolution was adopted and of the shareholder’s right to dissent.

(6) An application may be made to the Court by originating notice after the adoption of a resolution referred to in subsection (1) or (2),

(a)	by the corporation, or
(b)	by a shareholder if the shareholder has sent an objection to the corporation under subsection (5), to fix the fair value in accordance with subsection (3) of the shares of a shareholder who dissents under this section.

(7) If an application is made under subsection (6), the corporation shall, unless the Court otherwise orders, send to each dissenting shareholder a written offer to pay the shareholder an amount considered by the directors to be the fair value of the shares.

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(8) Unless the Court otherwise orders, an offer referred to in subsection (7) shall be sent to each dissenting shareholder

(a)	at least 10 days before the date on which the application is returnable, if the corporation is the applicant, or
(b)	within 10 days after the corporation is served with a copy of the originating notice, if a shareholder is the applicant.

(9) Every offer made under subsection (7) shall

(a)	be made on the same terms, and
(b)	contain or be accompanied with a statement showing how the fair value was determined.

(10)	A dissenting shareholder may make an agreement with the corporation for the purchase of the shareholder’s shares by the corporation, in the amount of the corporation’s offer under subsection (7) or otherwise, at any time before the Court pronounces an order fixing the fair value of the shares.
(11)	A dissenting shareholder

(a)	is not required to give security for costs in respect of an application under subsection (6), and
(b)	except in special circumstances must not be required to pay the costs of the application or appraisal.

(12) In connection with an application under subsection (6), the Court may give directions for

(a)	joining as parties all dissenting shareholders whose shares have not been purchased by the corporation and for the representation of dissenting shareholders who, in the opinion of the Court, are in need of representation,
(b)	the trial of issues and interlocutory matters, including pleadings and examinations for discovery,
(c)	the payment to the shareholder of all or part of the sum offered by the corporation for the shares,
(d)	the deposit of the share certificates with the Court or with the corporation or its transfer agent,
(e)	the appointment and payment of independent appraisers, and the procedures to be followed by them,
(f)	the service of documents, and
(g)	the burden of proof on the parties.

(13) On an application under subsection (6), the Court shall make an order

(a)	fixing the fair value of the shares in accordance with subsection (3) of all dissenting shareholders who are parties to the application,
(b)	giving judgment in that amount against the corporation and in favour of each of those dissenting shareholders, and
(c)	fixing the time within which the corporation must pay that amount to a shareholder.

A-2

(14) On

(a)	the action approved by the resolution from which the shareholder dissents becoming effective,
(b)	the making of an agreement under subsection (10) between the corporation and the dissenting shareholder as to the payment to be made by the corporation for the shareholder’s shares, whether by the acceptance of the corporation’s offer under subsection (7) or otherwise, or
(c)	the pronouncement of an order under subsection (13);

	whichever first occurs, the shareholder ceases to have any rights as a shareholder other than the right to be paid the fair value of the shareholder’s shares in the amount agreed to between the corporation and the shareholder or in the amount of the judgment, as the case may be.
(15)	Subsection (14)(a) does not apply to a shareholder referred to in subsection (5)(b).
(16)	Until one of the events mentioned in subsection (14) occurs,

(a)	the shareholder may withdraw the shareholder’s dissent, or
(b)	the corporation may rescind the resolution,

	and in either event proceedings under this section shall be discontinued.
(17)	The Court may in its discretion allow a reasonable rate of interest on the amount payable to each dissenting shareholder, from the date on which the shareholder ceases to have any rights as a shareholder by reason of subsection (14) until the date of payment.
(18)	If subsection (20) applies, the corporation shall, within 10 days after

(a)	the pronouncement of an order under subsection (13), or
(b)	the making of an agreement between the shareholder and the corporation as to the payment to be made for the shareholder’s shares,

	notify each dissenting shareholder that it is unable lawfully to pay dissenting shareholders for their shares.
(19)	Notwithstanding that a judgment has been given in favour of a dissenting shareholder under subsection (13)(b), if subsection (20) applies, the dissenting shareholder, by written notice delivered to the corporation within 30 days after receiving the notice under subsection (18), may withdraw the shareholder’s notice of objection, in which case the corporation is deemed to consent to the withdrawal and the shareholder is reinstated to the shareholder’s full rights as a shareholder, failing which the shareholder retains a status as a claimant against the corporation, to be paid as soon as the corporation is lawfully able to do so or, in a liquidation, to be ranked subordinate to the rights of creditors of the corporation but in priority to its shareholders.
(20)	A corporation shall not make a payment to a dissenting shareholder under this section if there are reasonable grounds for believing that

(a)	the corporation is or would after the payment be unable to pay its liabilities as they become due, or
(b)	the realizable value of the corporation’s assets would by reason of the payment be less than the aggregate of its liabilities.

A-3 EX-7 9 o12483exv7.htm ERRATUM

Exhibit 7

ERRATUM

     Notwithstanding the inaccurate reference to “March 5, 2004” on page 2 of the enclosed Information Circular under the heading “Voting Shares and Principal Holders Thereof”, the record date for the determination of shareholders of Hawker Resources Inc. who are entitled to notice and to vote at the Annual and Special Meeting of shareholders to be held on April 28, 2004 is March 15, 2004, as previously disclosed in the Notice of Meeting and Record Date filed on the SEDAR disclosure network (www.sedar.com) on March 1, 2004.

EX-8 10 o12483exv8.htm FORM OF PROXY

Exhibit 8

HAWKER RESOURCES INC.
PROXY

Solicited by the Management of Hawker Resources Inc.
for the Annual and Special Meeting of Shareholders to be held on April 28, 2004

The undersigned, being a holder of common shares of Hawker Resources Inc. (the “Corporation”), hereby appoints David A. Tuer or, failing him, Ronald P. Mathison or, instead of either of the foregoing,                               , as proxyholder, with power of substitution, to attend, to act and to vote for and on behalf of the undersigned at the annual and special meeting of the shareholders of the Corporation (the “Meeting”), which is to be held at 10:00 a.m. (Calgary time) on April 28, 2004, at First Canadian Centre Conference Centre, 350 – 7th Avenue S.W., Calgary, Alberta, and at any adjournment thereof and on every poll that may take place thereat, in the same manner, to the same extent and with the same power as if the undersigned were present at the Meeting, and without restricting the general authorization and power hereby conferred, the designee named above is specifically instructed to vote the common shares to which this proxy relates as follows:

1.	FOR o or WITHHOLD FROM VOTING FOR o the election of directors, as set forth in the Information Circular relating to the Meeting dated March 5, 2004 (the “Information Circular”);
2.	FOR o or AGAINST o a resolution approving future private placements of up to 50% of the issued and outstanding common shares of the Corporation, at any time until the next annual meeting of shareholders, subject to the policies of the Toronto Stock Exchange;
3.	FOR o or AGAINST o a resolution approving amendments to the Corporation’s stock option plan to provide for a cash payment feature and to increase the maximum number of common shares issuable thereunder from 1,181,513 to 2,981,513;
4.	FOR o or AGAINST o a special resolution approving the reclassification of the Corporation’s class A common shares into common shares;
5.	FOR o or WITHHOLD FROM VOTING FOR o the appointment of Ernst & Young LLP, Chartered Accountants, to serve as auditors of the Corporation for the ensuing year, at such remuneration as may be determined by the board of directors;
6.	on any other matters that may properly come before the Meeting in such manner as the proxyholder may see fit.

The undersigned instructs the person herein designated as proxyholder to act on the above matters as directed. In the absence of any such direction the common shares will be voted for: (i) the election of directors; (ii) the approval of future private placements of up to 50% of the issued and outstanding common shares of the Corporation at any time until the next annual meeting of shareholders; (iii) the approval of the amendments to the Corporation’s Stock Option Plan; (iv) the approval of the reclassification of the class A common shares; and (v) the appointment of auditors, at such remuneration as may be determined by the directors. The undersigned hereby confers on the proxyholder discretionary authority with respect to amendments to or variations of the matters outlined above and with respect to matters other than those listed in the accompanying notice of meeting that may properly be brought before the Meeting. The undersigned hereby revokes any proxy previously given for the purposes of the Meeting in respect of common shares held by the undersigned.
Dated this                 day of                          , 2004.
Signature of Shareholder
Please Print Name
Number of Shares Held
Notes:
1.	A shareholder has the right to appoint a person (who need not be a shareholder of the Corporation) other than David A. Tuer or Ronald P. Mathison to attend and act on behalf of such shareholder at the Meeting or any adjournment thereof. To exercise this right the shareholder must: (i) insert the name of the other person in the blank space provided above; or (ii) complete another appropriate form of proxy.
2.	In order for this proxy to be valid, it must be deposited at the offices of Computershare Trust Company of Canada, 100 University Avenue, 9th Floor, Toronto, Ontario, M5J 2Y1 Attention: Proxy Department, at least forty-eight (48) hours (excluding Saturdays, Sundays and holidays) before the time of the Meeting or any adjournment thereof.
3.	This proxy must be dated and signed by the shareholder or his duly authorized attorney or, if the shareholder is a corporation, by a duly authorized officer. If this proxy is not dated, it will be deemed to bear the date on which the Information Circular was distributed by the Corporation to the shareholders.

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