Hawk Announces Year End Reserves and Provides Operations Update

CALGARY, March 20, 2013 /CNW/ - Hawk Exploration Ltd. ("Hawk" or the "Corporation") is pleased to provide an operations update and a summary of its December 31, 2012 reserve information as evaluated by GLJ Petroleum Consultants Ltd. ("GLJ").

HIGHLIGHTS

Increased total proved reserves by 43% from 797 thousand barrels of oil equivalent ("MBoe") in 2011 to 1,137 MBoe in 2012 and increased total proved plus probable oil reserves by 31% from 1,319 MBoe to 1,725 MBoe;
Added total proved reserves in 2012 at a finding and development cost of $19.77 per Boe, including future development costs, and added total proved plus probable reserves at a finding and development cost of $16.87 per Boe, including future development costs;
Achieved a recycle ratio on a proved basis of 1.7 times and on a proved plus probable recycle ratio of 1.9 times based on estimated 2012 operating netback of $32.80 per Boe;
Replaced 2012 production on a proved basis by 283% and on a proved plus probable basis by 318%;
Increased undeveloped land holdings to 42,700 net acres mainly in the plains area of eastern Alberta and western Saskatchewan; and
Continued to increase the oil weighting of the Corporation as oil and liquids reserves comprise 88% of proved plus probable reserve at the end of 2012 from 85% in at the end of 2011.

OPERATIONS

During the first quarter of 2013, Hawk drilled three (2.0 net) vertical oil wells in the Silverdale area of western Saskatchewan and one (1.0 net) vertical oil well in the Dulwich area of western Saskatchewan. The well at Dulwich (1.0 net) has been cased and completed and is currently producing 35 barrels per day ('bbl/d") of heavy oil. At Silverdale, two (1.0 net) wells have been recently completed and are currently producing a combined 50 bbl/d of heavy oil, net to Hawk, while the other one (1.0 net) well at Silverdale is expected to be completed after spring break up in June. Hawk's current production is approximately 700 Boe/d, with oil comprising 96 percent of total production. Hawk is planning an active drilling program for the second and third quarter of 2013 and expects to drill three (2.5 net) vertical wells and one (1.0 net) horizontal well targeting heavy oil in Hawk's core area of east central Alberta and western Saskatchewan.

As a follow up to our press release on February 5, 2013, Hawk has seen a narrowing of the heavy oil differentials for Western Canadian Select ("WCS") from over $30 per bbl in January and February 2013 to under $20 per bbl for the April 2013 contract month. Current WCS prices are trading at approximately $72.00 to $73.00 per bbl compared to approximately $65.00 per bbl at the time of our last press release. Hawk will continue to monitor the impact of these differentials on the Corporation's cash flow and, if necessary, will adjust capital spending to maintain its strong balance sheet.

HEDGING

During the first quarter of 2013, Hawk entered into two separate costless collar contracts for West Texas Intermediate Crude ("WTI"). The first costless collar was on a notional 100 bbl/d from April 1, 2013 to December 31, 2013 with a floor price of Canadian ("CAD") $87.50 per bbl and a ceiling of CAD $97.52 per bbl while the second costless collar contract was for a notional 75 bbl/d from April 1, 2013 to December 31, 2013 with a floor price of CAD $92.00 per bbl and a ceiling of CAD $101.60 per bbl.

RESERVES

GLJ prepared an independent engineering report in accordance with National Instrument 51-101 ("NI 51-101") with an effective date of December 31, 2012 (the "GLJ Report"). The tables below are a summary of the oil, NGL and natural gas reserves attributable to the Corporation and the net present value of future net revenue attributable to such reserves as evaluated in the GLJ Report.

The net present value of future net revenue attributable to reserves is stated without provision for interest costs and general and administrative costs, but after providing for estimated royalties, production costs, development costs, other income, future capital expenditures and well abandonment costs for only those wells assigned reserves by GLJ. It should not be assumed that the undiscounted or discounted net present value of future net revenue attributable to reserves estimated by GLJ represents the fair market value of those reserves. Other assumptions and qualifications relating to costs, prices for future production and other matters are summarized herein. The recovery and reserve estimates of oil, NGL and natural gas reserves provided herein are estimates only. Actual reserves may be greater than or less than the estimates provided herein.

The reserve data provided in this press release only represents a summary of the disclosure required under NI 51-101. Additional reserves disclosure will be provided in the Corporation's Annual Information Form to be filed on SEDAR (www.sedar.com) on or before April 30, 2013.

Summary of Oil and Gas Reserves as of December 31, 2012
Reserves Summary

		Oil		Natural Gas		Natural Gas Liquids		Total Oil Equivalent
Reserves Category		Gross (Mbbl)	Net (Mbbl)	Gross (MMcf)	Net (MMcf)	Gross (Mbbl)	Net (Mbbl)	Gross (Mboe)	Net (Mboe)
Proved
	Developed Producing	785	679	276	231	12	9	843	727
	Developed Non-producing	61	50	-	-	-	-	61	50
	Undeveloped	216	184	81	64	4	3	233	198
Total Proved		1,062	913	357	295	16	12	1,137	975
Probable		428	369	925	601	6	5	588	474
Total Proved plus Probable		1,490	1,282	1,282	896	22	17	1,725	1,449


Net Present Value Summary as of December 31, 2012
		Net Present Value of Future Net Revenue Before Income Taxes Discounted At (%/year)					Unit Value Before Income Tax Discounted at 10%/year
Reserves Category		0% M$	5% M$	10% M$	15% M$	20% M$	$/boe
Proved
	Developed Producing	27,987	24,916	22,477	20,499	18,867	30.92
	Developed Non-producing	3,053	2,609	2,272	2,009	1,800	45.21
	Undeveloped	6,659	5,437	4,503	3,772	3,190	22.74
Total Proved		37,700	32,962	29,251	26,280	23,857	30.00
Probable		18,139	13,060	9,962	7,916	6,483	21.03
Total Proved plus Probable		55,839	46,022	39,213	34,196	30,340	27.07


Total Future Net Revenue (Undiscounted) as of December 31, 2012
Reserves Category	Revenue M$	Royalties M$	Operating Cost M$	Capital Development Costs M$	Abandonment Costs M$	Future Net Revenue Before Income Tax M$

Total Proved	77,209	11,906	23,947	2,639	1,017	37,700
Total Proved plus Probable	116,043	18,878	36,767	3,412	1,146	55,839


Summary of Forecast Pricing and Inflation Assumptions

The GLJ Report used the following prices, exchange rates, and inflation rate assumptions as of December 31, 2012:
Year	WTI Cushing Oklahoma ($US/bbl)	Edmonton 40 degree API Crude Oil ($CAD/bbl)	WCS Crude Oil ($CAD/bbl)	AECO - NIT Spot ($CAD/mmbtu)	Inflation Rate %	Exchange Rate ($US/$CAD)
2013	90.00	85.00	70.13	3.38	2.0	1.00
2014	92.50	91.50	76.15	3.83	2.0	1.00
2015	95.00	94.00	78.22	4.28	2.0	1.00
2016	97.50	96.50	80.29	4.72	2.0	1.00
2017	97.50	96.50	80.29	4.95	2.0	1.00
2018	97.50	96.50	80.29	5.22	2.0	1.00
2019	98.54	97.54	81.16	5.32	2.0	1.00
2020	100.51	99.51	82.79	5.43	2.0	1.00
2021	102.52	101.52	84.46	5.54	2.0	1.00
2022	104.57	103.57	86.16	5.64	2.0	1.00
Escalated at 2.0 % per year thereafter.


FINDING AND DEVELOPMENT COSTS ("F&D") ⁽¹⁾
		2012		2011		Three Year Average
		Proved	Proved plus Probable	Proved	Proved plus Probable	Proved	Proved plus Probable
Exploration and development costs (M$) ⁽²⁾		9,152	9,152	10,907	10,907	35,339	35,339

Change in future development cost (M$)
	Exploration and development	1,249	838	40	(1,475)	2,225	2,574
Total costs (M$)		10,401	9,990	10,947	9,432	37,564	37,913

Net reserve additions and revisions (Mboe)		526	592	208	103	1,002	1,268

Finding and Development - including future development cost ($/boe)

	Total F&D costs ($/boe)	19.77	16.87	52.55	91.57	37.48	29.90

⁽¹⁾	The aggregate of the exploration and development costs incurred in the most recent financial year and the change during that year in estimated future development costs generally will not reflect total finding and development costs related to reserve additions for that year.
⁽²⁾	The Corporation's annual audit of the 2012 financial statements has not been completed and accordingly all financial amounts are management's best estimates which are unaudited and subject to change.


NET ASSET VALUE
M$, except per share amounts			December 31, 2012

Proved plus probable reserves discounted at 10% (before taxes)			39,213
Undeveloped land ⁽¹⁾			5,344
Net debt and working capital deficit ⁽²⁾			(4,780)
Proceeds from dilutive options			737
Net asset value			40,514
Fully diluted Class A shares outstanding (000's) ⁽³⁾			36,954
Net asset value per fully diluted Class A share			$1.10
Fully diluted Class A and Class B shares outstanding (000's) ⁽⁴⁾			47,754
Net asset value per fully diluted Class A and Class B shares			$0.85

⁽¹⁾	Undeveloped land is based on management's internal estimate at December 31, 2012. Hawk had a total of 42,748 net acres of land at December 31, 2012 assessed at an average value of $125 per net acre.
⁽²⁾	The Corporation's annual audit of the 2012 financial statements has not been completed and accordingly all financial amounts are management's best estimates which are unaudited and subject to change.
⁽³⁾	Includes Class A shares outstanding at December 31, 2012 of 34,480,953 plus dilutive options of 2,473,000.
⁽⁴⁾	For purposes of this calculation, Class B shares were converted to Class A shares at $1.00 per share such that the 1,080,000 Class B shares outstanding at December 31, 2012 were converted into 10,800,000 Class A shares. The Class B common shares are convertible (at the option of the Corporation) at any time after July 2, 2012 and on or before June 30, 2014 into Class A shares. The number of Class A shares to be issued upon conversion of one Class B share is calculated by dividing $10 by the greater of $1 and the then current market price of the Class A shares at the date of conversion. If conversion has not occurred by the close of business on June 30, 2014, the Class B shares become convertible (at the option of the shareholder) into Class A shares pursuant to the conversion formula described above. Effective at the close of business on July 31, 2014, all remaining Class B shares will be automatically converted into Class A shares pursuant to the conversion formula described above.


LAND HOLDINGS
	Developed		Undeveloped		Total
Acres	Gross	Net	Gross	Net	Gross	Net
Alberta	2,000	1,991	30,533	28,321	32,533	30,312
Saskatchewan	2,090	1,658	19,015	14,427	21,105	16,085
Total	4,090	3,649	49,548	42,748	53,638	46,397

Hawk is an emerging company engaged in the exploration, development and production of conventional crude oil and natural gas in western Canada and is based in Calgary, Alberta. The Class A Shares and Class B Shares of Hawk trade on the TSX Venture Exchange under the trading symbols of HWK.A and HWK.B, respectively.

Neither the TSX Venture Exchange nor its Regulation Services Provider (as the term is defined in the policies of the TSX Venture Exchange) accepts responsibility for the adequacy or accuracy of this release.

Certain statements contained in this press release constitute forward-looking statements. All forward-looking statements are based on the Corporation's beliefs and assumptions based on information available at the time the assumption was made. The use of any of the words "anticipate", "continue", "estimate", "expect", "may", "will", "project", "should", "believe" and similar expressions are intended to identify forward-looking statements. 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. Hawk believes the expectations reflected in those forward-looking statements are reasonable, but no assurance can be given that these expectations will prove to be correct. Such forward-looking statements included in this press release should not be unduly relied upon. These statements speak only as of the date of this press release.

In particular, but without limiting the forgoing, this press release contains forward-looking statements pertaining to the following: the volumes and estimated value of the Corporation's oil and gas reserves; future oil and natural gas prices; future costs, expenses, royalty rates and the exchange rate between the $US and $CAD; supply and demand for oil and natural gas; planned development of the Corporation's oil and natural gas properties; the timing of production additions from the first quarter 2013 drilling program; planned timing and nature of the second and third quarter 2013 drilling program; and future capital expenditure programs.

The material factors and assumptions used to develop these forward looking statements include, but are not limited to: the ability of the Corporation to engage drilling contractors, to obtain and transport equipment, services, supplies and personnel in a timely manner and at an acceptable cost to carry out its activities and plans; the ability of the Corporation to market its oil and natural gas and to transport its oil and natural gas to market; the timely receipt of regulatory approvals and the terms and conditions of such approval; the ability of the Corporation to obtain drilling success consistent with expectations; and the ability of the Corporation to obtain capital to finance its exploration, development and operations.

Actual results could differ materially from those anticipated in these forward-looking statements as a result of the risk factors including, without limitation: volatility in market prices for oil and natural gas; liabilities inherent in oil and natural gas operations; uncertainties associated with estimating oil and natural gas reserves; competition for, among other things, capital, acquisitions of reserves, undeveloped lands and skilled personnel; incorrect assessments of the value of acquisitions and exploration and development programs; geological, technical, drilling and processing problems; changes in tax laws and incentive programs relating to the oil and natural gas industry; failure to realize the anticipated benefits of acquisitions; general business and market conditions; and certain other risks detailed from time to time in Hawk's public disclosure documents.

Statements relating to "reserves" or "resources" are deemed to be forward-looking statements, as they involve the implied assessment, based on certain estimates and assumptions that the resources and reserves described can be profitably produced in the future. Readers are cautioned that the foregoing lists of factors are not exhaustive. The forward-looking statements contained in this press release are expressly qualified by this cautionary statement. Except as required under applicable securities laws, Hawk does not undertake any obligation to publicly update or revise any forward-looking statements.

Barrels of oil equivalent (boe) may be misleading, particularly if used in isolation. A boe conversion ratio of six thousand cubic feet (mcf) of natural gas to one barrel (bbl) of oil is based on an energy conversion method primarily applicable at the burner tip and is not intended to represent a value equivalency at the wellhead. All boe conversions in this press release are derived by converting natural gas to oil in the ratio of six thousand cubic feet of natural gas to one barrel of oil. Certain financial amounts are presented on a per boe basis, such measurements may not be consistent with those used by other companies.

SOURCE Hawk Exploration Ltd.

Hawk Exploration Ltd. (TSXV:HWK.A)
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