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Strategic Oil & Gas Ltd. Announces Year-End Reserves and Provides Operations Update

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CALGARY, ALBERTA -- (Marketwire) -- 02/25/13 -- Strategic Oil & Gas Ltd. ("Strategic" or the "Company") (TSX VENTURE: SOG) is pleased to announce its year-end reserves and provide an update on its first quarter drilling program.

RESERVES

In accordance with National Instrument 51-101 - Standards of Disclosure for Oil and Gas Activities ("NI 51-101"), the Company's oil, natural gas and natural gas liquids ("NGL") reserves were evaluated by an independent engineering firm, McDaniel and Associates Consultants Ltd. ("McDaniel") as at December 31, 2012. Gross reserves included in this release are Strategic's working interest reserves before royalty burdens. Complete NI 51-101 reserves disclosure will be included in Strategic's annual NI 51-101 filings which will be filed prior to April 30, 2013.

The Company's aggregate proved and probable reserves are reported in barrels of oil equivalent (Boe). Boe may be misleading, particularly if used in isolation. A Boe conversion ratio for natural gas of 6 Mcf: 1 Boe has been used, which is based on an energy equivalency conversion method primarily applicable at the burner tip and does not necessarily represent a value equivalency at the wellhead. As the value ratio between natural gas and crude oil based on the current prices of natural gas and crude oil is significantly different from the energy equivalency of 6:1, utilizing a conversion on a 6:1 basis may be misleading as an indication of value.

HIGHLIGHTS

-- Strategic added 3.7 MMBoe of proved and probable reserves in 2012, excluding production, for a reserve replacement ratio of 479 percent.-- After production of 0.8 MMBoe, proved and probable reserves increased 2.9 MMBoe (55 percent) from 5.3 MMBoe at year-end 2011 to 8.2 MMBoe (78% oil) at December 31, 2012. Proved reserves increased 25 percent to 4.0 MMBoe (85% oil) from 3.2 MMBoe at year-end 2011.-- Pre-tax net asset value of the Company's reserves, using McDaniel's forecast pricing and discounted at 10%, increased to $90 million for proved reserves and $139 million for proved and probable reserves at December 31, 2012 from $68 million for proved reserves and $96 million for proved and probable reserves at December 31, 2011.-- Strategic realized finding and development costs ("F&D"), including future development capital ("FDC"), of $26.23 per Boe for 2012 based on capital expenditures of $63.2 million.-- Including the previously-announced acquisition of Steen River assets in December 2012, finding, development and acquisition costs ("FD&A"), including changes in FDC, were $29.58 per Boe on a proved and probable basis.



Strategic's reserves at December 31, 2012 are summarized below.

Light and Medium Natural Crude Heavy Natural Gas Oil Oil Oil Gas Liquids EquivalentGross Reserves(1) (Mbbl) (Mbbl) (MMcf) (Mbbl) (MBoe)----------------------------------------------------------------------------Proved Producing 2,669 137 2,604 40 3,279Proved Non-Producing 405 0 809 1 541Proved Undeveloped 193 0 20 0 197Total Proved 3,268 137 3,433 41 4,017----------------------------------------------------------------------------Total Probable 2,905 78 6,895 34 4,167----------------------------------------------------------------------------Total Proved and Probable 6,173 215 10,328 75 8,184--------------------------------------------------------------------------------------------------------------------------------------------------------(1) Gross Corporate reserves are the Company's total working interest sharebefore the deduction of any royalties and without including any royaltyinterests of the Company. The December 31, 2012 reserves report has beenprepared in accordance with the definitions, procedures and standardscontained in the Canadian Oil and Gas Evaluation Handbook and NI 51-101-Standards of Disclosure for Oil and Gas Activities.



Proved and probable producing reserves represent 55 percent of total proved and probable reserves. 87 percent of the Company's total reserves are located in the Steen River core area.

McDaniel estimates the FDC required to convert undeveloped and non-producing reserves to producing reserves at $50.1 million.

A reconciliation of the Company's reserves at December 31, 2012 to the previous year-end is as follows.

Thousand Barrels of Oil Equivalent Proved (MBoe) Proved Probable and Probable----------------------------------------------------------------------------Opening Balance December 31, 2011 3,217 2,054 5,271Discoveries and Extensions 1,101 2,534 3,635Technical Revisions 289 (475) (186)Acquisitions 316 122 439Economic Factors (138) (68) (206)Production(1) (769) 0 (769)----------------------------------------------------------------------------Closing Balance December 31, 2012 4,017 4,167 8,184--------------------------------------------------------------------------------------------------------------------------------------------------------(1)Production information is from Strategic's preliminary unauditedconsolidated financial statements for the year ended December 31, 2012.



Strategic's light and medium oil, natural gas and NGL reserves were evaluated by McDaniel using McDaniel's product price forecasts effective January 1, 2013 prior to provision for financial risk management contracts, income taxes, interest, debt service charges and general and administrative expenses. The following table summarizes the net present value from recognized reserves at December 31, 2012, assuming various discount rates, and incorporating future development costs and abandonment liabilities. It should not be assumed that the discounted future net revenues estimated by McDaniel represent the fair market value of the Company's assets or future production from the assets.

Summary of Before Tax Net Present Value of Future Net Revenue (Forecast Pricing(1)) (2) Discounted at($ thousands) Undiscounted 5% 10% 15%----------------------------------------------------------------------------Proved Producing 95,561 81,823 72,034 64,755Proved Non-Producing 16,693 14,770 13,267 12,064Proved Undeveloped 6,613 5,657 4,901 4,293----------------------------------------------------------------------------Total Proved 118,867 102,250 90,202 81,111Total Probable 99,020 68,127 48,853 35,991----------------------------------------------------------------------------Total Proved and Probable 217,887 170,377 139,055 117,103--------------------------------------------------------------------------------------------------------------------------------------------------------(1) Based on McDaniel's January 1, 2013 escalated price forecast.(2) Tables may not add due to rounding. There is no assurance that theforecast prices and costs assumptions will be attained and variances couldbe material. The recovery and reserve estimates of Strategic's crude oil,natural gas liquids and natural gas reserves provided herein are estimatesonly and there is no guarantee that the estimated reserves will berecovered. Actual crude oil, natural gas and natural gas liquids reservesmay be greater than or less than the estimates provided herein.



Strategic incurred capital expenditures of $87 million in 2012, of which $59 million was spent on exploration and development, $4 million was spent on land and seismic and $24 million was spent on acquisitions. The following table summarizes Strategic's F&D costs as well as FD&A costs, both before and after the inclusion of changes in FDC.

2012 F&D and FD&A Costs Proved &($ thousands (unaudited), except as noted) Proved Probable----------------------------------------------------------------------------F&D Costs, Excluding FDCExploration and Development Expenditures(1) 63,206 63,206Reserve Additions, Including Revisions - MBoe 1,253 3,244F&D Costs - $/Boe 50.44 19.49F&D Costs, Including FDCExploration and Development Expenditures(1) 63,206 63,206Total Change in FDC (8,721) 21,865----------------------------------------------------------------------------Total F&D Capital, Including Change in FDC 54,485 85,071Reserve Additions, Including Revisions - MBoe 1,253 3,244F&D Costs- $/Boe 43.48 26.23FD&A Costs, Excluding FDCExploration and Development Capital Expenditures(1) 63,206 63,206Net Acquisitions 23,835 23,835----------------------------------------------------------------------------FD&A Capital Expenditures, Including Net Acquisitions 87,041 87,041Reserve Additions, Including Net Acquisitions - MBoe 1,919 3,682FD&A Costs - $/Boe 45.36 23.64FD&A Costs, Including FDCFD&A Capital Expenditures, Including Net Acquisitions(1) 87,041 87,041Total Change in FDC (8,721) 21,865----------------------------------------------------------------------------Total FD&A Capital, Including Change in FDC 78,320 108,906Reserve Additions, Including Net Acquisitions - MBoe 1,919 3,682FD&A Costs, Including FDC - $/Boe 40.82 29.58--------------------------------------------------------------------------------------------------------------------------------------------------------(1) Financial information is from Strategic's preliminary unauditedconsolidated financial statements for the year ended December 31, 2012.



OPERATIONAL UPDATE

During 2012, Strategic undertook to expand its land holdings at Steen. Strategic was very successful, acquiring approximately 100,000 hectares at an average cost of $16 per hectare, well below the 2012 Alberta average cost of $360 per hectare. Strategic's undeveloped land position has now grown to 155,984 net hectares.

Keg River

In late 2012 Strategic drilled two vertical keg river wells, 02/11-28 was drilled into the existing keg river pool and 02-13 as a step out well to test a potential new keg river structure. The well 02/11-28, producing at an oil rate of over 200 Boe/d is outperforming the keg river type curve. Vertical step out well 02-13 resulted in a new keg river pool discovery on the eastern side of the rim. The vertical well has intersected a lower permeability keg river reservoir which has been mapped to extend over 5 square km with an estimated original oil in place of 40 million barrels. The vertical well is currently producing at 50 Boe/d. This new keg river pool will be an ideal candidate for horizontal development.

In 2013, Strategic drilled 3 step out vertical wells at Steen River. Two of the three vertical wells were targeting new pools with the third well extending an existing keg river pool. All three wells have been cased with promising shows while drilling and on logs. The three wells are currently being flow tested to a temporary battery and are expected to be tied in during March.

Muskeg Stack

Strategic completed its first multistage frac well 03/12-18 into the muskeg formation in the fourth quarter of 2012. Due to limited fluid handling capability at the West Marlowe field, the horizontal well has been flowing into a pipeline against a back pressure of 4000-5000 kpa, which limits the drawdown on the well. The well is currently producing 180 Boed (45% light oil) with limited drawdown. Strategic is planning to tie the well into the newly acquired facility and optimize the drawdown in March 2013.

In 2013 Strategic drilled a muskeg stack horizontal well 14-18, following up on the success of the horizontal well 03/12-18. A second muskeg horizontal well is currently underway from the same pad and completion operations will commence on both wells once the second drilling operation is completed.

In order to prove up the muskeg stack fairway, Strategic completed a vertical well 07-28 in the muskeg stack. This well is located approximately 15 km east of the first muskeg stack horizontal well. This well is currently producing at 75 Boe/d. A third muskeg stack horizontal well has been spudded at 13-28, keying off of a successful vertical test of the Muskeg Stack in that region of the field. Strategic will be tying in the three new muskeg stack horizontal wells in March 2012.

In addition, Strategic has undertaken four recompletions in existing wellbores to confirm the resource potential of several zones as well as testing completion techniques to improve the initial production potential of the wells. The results have been very encouraging and these wells are being placed on production to ascertain the longer term performance of these wells.

Strategic's current corporate production is 3,100 Boe/d (91% oil). The current production does not include any new production from the wells drilled to date in 2013. The new wells will be tied into Strategic's facility at Steen River starting in March 2013. Approximately 50% of Strategic's current light oil production is transported by rail. The rail option gives Strategic exposure to Brent and WTI pricing for its crude. The Company reaffirms its earlier production guidance of an average of 4,000 Boe/d for 2013.

ABOUT STRATEGIC

Strategic is a well-capitalized junior oil and gas company committed to growth by exploiting its light oil assets in Canada. Strategic is primarily focused on implementing development plans for its light oil properties, while continuing to review other high impact light oil resource plays. Strategic's common shares trade on the TSX Venture Exchange under the symbol SOG.

ADDITIONAL INFORMATION

Additional information is also available at www.sogoil.com and at www.sedar.com.

Unaudited Financial Information

Certain financial and operating information included in this press release for the year ended December 31, 2012, such as capital expenditures, production, F&D costs and FD&A costs are based on unaudited financial results, and are subject to the same limitations as discussed under "Forward-Looking Information". These estimated amounts may change upon the completion of audited financial statements for the year-ended December 31, 2012 and changes could be material.

Forward-Looking Statements

This news release includes certain information, with management's assessment of Strategic's future plans and operations, and contains forward-looking statements which may include some or all of the following: (i) forecasted production rates; (ii) exploration, drilling and development plans and results there from, (iii) prospects and drilling inventory and locations; (iv) anticipated production rates; (v) expected royalty rate; (vi) anticipated operating and service costs; (vii) the Company's financial strength and capitalization; (viii) incremental development opportunities; (ix) estimates of reserves, reserve values, future oil and gas prices, and future FDC and abandonment costs; which are provided to allow investors to better understand the Company's business. By their nature, forward-looking statements are subject to numerous risks and uncertainties; some of which are beyond Strategic's control, including the impact of general economic conditions, industry conditions, volatility of commodity prices, currency fluctuations, imprecision of reserve estimates, environmental risks, changes in environmental tax and royalty legislation, competition from other industry participants, the lack of availability of qualified personnel or management, stock market volatility and ability to access sufficient capital from internal and external sources, and other risks and uncertainties described under the heading 'Risk Factors' and elsewhere in the Company's Annual Information Form for the year ended December 31, 2011 and other documents filed with Canadian provincial securities authorities and are available to the public at www.sedar.com. Readers are cautioned that the assumptions used in the preparation of such information, although considered reasonable at the time of preparation, may prove to be imprecise and, as such, undue reliance should not be placed on forward-looking statements. The principal assumptions Strategic has made includes security of land interests; drilling cost stability; royalty rate stability; oil and gas prices to remain in their current range; finance and debt markets continuing to be receptive to financing the Company and industry standard rates of geologic and operational success. Strategic's actual results, performance or achievement could differ materially from those expressed in, or implied by, these forward-looking statements or if any of them do so, what benefits that Strategic will derive there from. Strategic disclaims any intention or obligation to update or revise any forward-looking statements, whether as a result of new information, future events or otherwise, except as required by law.

OOIP Disclaimer: Original oil in place ("OOIP") are contingent resources and are not reserves. There is no certainty that it will be commercially viable to produce any portion of OOIP except to the extent they are subsequently classified as proved or probable reserves.

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



Contacts:
Strategic Oil & Gas Ltd.
Gurpreet Sawhney, MBA, MSc., PEng.
President and CEO
403.767.2949
403.767.9122 (FAX)

Strategic Oil & Gas Ltd.
Sean Hayes, PhD, PGeol
Chief Operating Officer
403.767.2946
403.767.9122 (FAX)

Strategic Oil & Gas Ltd.
1100, 645 7th Avenue SW
Calgary, AB T2P 4G8
www.sogoil.com



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