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Strategic Oil & Gas Ltd. Announces Second Quarter 2014 Financial and Operating Results and Updated Reserves Report

Achieves 40% Increase in Reserves Value

CALGARY, ALBERTA -- (Marketwired) -- 08/15/14 -- Strategic Oil & Gas Ltd. ("Strategic" or the "Company") (TSX VENTURE:SOG) reports an updated independent reserves report dated July 1, 2014, showing significant growth in reserves volumes and value in the Company's Marlowe area, as well as financial and operating results for the three and six months ended June 30, 2014. Detailed results are presented in Strategic's interim condensed consolidated financial statements and related Management's Discussion and Analysis ("MD&A") which will be available through the Corporation's website at www.sogoil.com, on SEDAR at www.sedar.com and also at http://media3.marketwire.com/docs/SOG2014FSMDA.pdf.

FINANCIAL AND OPERATIONAL SUMMARY


----------------------------------------------------------------------------
                     Three Months Ended June 30    Six Months Ended June 30 
----------------------------------------------------------------------------
                                              %                           % 
                         2014      2013  change      2014      2013  change 
----------------------------------------------------------------------------
Financial                                                                   
 ($thousands, except                                                        
 per share amounts)                                                         
----------------------------------------------------------------------------
Oil and natural gas                                                         
 sales                 23,723    23,770       -    45,483    41,657       9 
Funds from                                                                  
 operations (1)         3,541     8,672     (59)    4,526    12,629     (64)
  Per share basic &                                                         
   diluted (1)           0.01      0.04     (75)     0.01      0.06     (83)
Cash provided by                                                            
 (used in) operating                                                        
 activities            (5,627)    7,124    (179)    4,476     9,962     (55)
  Per share basic &                                                         
   diluted              (0.02)    (0.03)    (33)     0.01      0.05     (80)
Net loss               (2,717)   (2,336)     16   (12,379)   (5,709)    117 
  Per share basic &                                                         
   diluted              (0.01)    (0.01)      -     (0.04)    (0.02)    100 
Capital expenditures                                                        
 (excluding                                                                 
 acquisitions)         13,540    14,782      (8)   51,993    65,050     (20)
Net acquisitions                                                            
 (dispositions)        (3,478)        -       -    (3,821)   10,098    (138)
Bank debt              75,000    70,800       6    75,000    70,800       6 
Net debt (1)           78,307    80,879      (3)   78,307    80,879      (3)
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Operating                                                                   
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Average daily                                                               
 production                                                                 
  Crude oil (bbl per                                                        
   day)                 2,294     2,768     (17)    2,327     2,544      (9)
  Natural gas (mcf                                                          
   per day)             7,461     6,936       8     6,098     4,916      24 
  Barrels of oil                                                            
   equivalent (boe                                                          
   per day)             3,538     3,924     (10)    3,343     3,364      (1)
Average prices                                                              
  Oil & NGL, before                                                         
   risk management                                                          
   ($ per bbl)          98.21     85.22      15     92.83     83.63     112 
  Oil & NGL,                                                                
   including risk                                                           
   management ($ per                                                        
   bbl)                 84.23     86.58      (3)    81.74     84.49      (3)
  Natural gas ($ per                                                        
   mcf)                  4.75      3.65      30      5.05      3.54      43 
Netback ($ per boe)                                                         
 (1)                                                                        
  Oil and natural                                                           
   gas sales            73.68     66.57      11     75.16     68.41      10 
  Royalties            (16.26)   (13.46)     21    (16.07)   (14.74)      9 
  Production                                                                
   expenses            (29.17)   (24.15)     21    (33.94)   (26.48)     28 
----------------------------------------------------------------------------
Operating Netback       28.25     28.96      (2)    25.15     27.19      (8)
----------------------------------------------------------------------------
Common Shares                                                               
 (thousands)                                                                
----------------------------------------------------------------------------
Common shares                                                               
 outstanding, end of                                                        
 period               361,001   210,404      72   361,001   210,404      72 
Weighted average                                                            
 common shares                                                              
 (basic)              360,959   210,404      72   311,646   200,121      56 
Weighted average                                                            
 common shares                                                              
 (diluted)            360,959   210,404      72   311,646   200,121      56 
----------------------------------------------------------------------------
(1) Funds from operations, net debt and operating netback are non-IFRS      
    measurements; see "Non-IFRS Measurements" in this MD&A.                 

FINANCIAL & OPERATIONS SUMMARY


--  Capital expenditures of $13.5 million for the second quarter of 2014
    were directed towards the sales oil pipeline, related infrastructure
    expansion, completion of the 10-24 Muskeg well which was drilled in the
    first quarter and the initiation of the Company's summer 2014 drilling
    program in June.  
--  Average daily production increased 12 percent to 3,538 boe/d for the
    three months ended June 30, 2014 from 3,147 boe/d for the first quarter
    of the year. The three Muskeg wells drilled during the first quarter
    achieved over 95 percent uptime and are performing at or above the
    Company's type curve. Sales volumes for the current period decreased by
    10 percent from the second quarter of 2013 due to no new tie-in
    activity,, 9,000 barrels of oil production at Marlowe was used to fill
    the sales oil pipeline and the sale of 90 boe/d of non-operated
    production. 
--  Funds from operations increased to $3.5 million ($0.01 per share) in the
    current quarter from $1.0 million ($nil per share) for the first three
    months of 2014, due to higher production levels and a decrease of $1.7
    million in production costs. Included in the funds from operations for
    the current quarter was $2.9 million ($0.01 per share) of realized
    losses on risk management contracts related to the Company's oil sales
    hedging program. 
--  The Company realized a $41.00/boe operating netback in the Marlowe core
    area in the current period as compared to $27.99/boe in the first
    quarter of 2014, a 46% improvement due to a reduction of production
    costs at its core asset. 
    --  Achieved production costs of $22/boe in the Marlowe core area in the
        current period as compared to $38/boe in the first quarter of 2014,
        a reduction of 42%. Due to the fixed cost base of its operations,
        the Company will achieve further reductions in costs per boe during
        the second half of 2014 as more production is brought on. Strategic
        also expects further cost savings as the installation of sales oil
        pumps at the Marlowe 9-17 oil battery is completed in the third
        quarter of 2014, which will allow for increased volumes to flow
        through the newly constructed sales oil pipeline and further reduce
        trucking. 
--  The Company's operating netback increased to $28.25/boe for the three
    months ended June 30, 2014 from $21.61/boe for the first quarter of 2014
    as a result of several factors: 
    --  A decrease in production costs by $10.20/boe from the first quarter
        of 2014 mainly due to cost reduction initiatives focused on the
        Company's northern operations; 
    --  The effect of these cost decreases was partially offset by an
        increase in the Company's royalty rate to 22.4 percent from 20.6
        percent in the first quarter of 2014, as no new wells with the 5%
        royalty were drilled during second quarter of 2014 and a decrease of
        $3.14 in revenues per boe. 
--  Operating costs increased to $1 million ($3.10/boe) in the current
    quarter from the comparative period in 2013 due to costs incurred to
    repair the Bistcho facility and higher chemicals/fuel charges. Majority
    of the chemical/fuel expenses in the winter access area were incurred by
    the previous operator in 2013 prior to Strategic's acquisition of the
    asset. 
--  Strategic closed a disposition of non-core oil and gas assets in
    southern Alberta for proceeds of $3.5 million. The sold assets consisted
    of approximately two sections of land and 90 boe/d of production (94%
    natural gas and associated liquids). The proceeds were allocated towards
    the Company's Muskeg stack development at Marlowe. 
--  The company has maintained its $80 million credit facility with National
    Bank of Canada. The $20 million acquisition/development facility has not
    been used to date in 2014 and has been removed from the credit facility,
    which will reduce bank fees going forward. 

RESERVES HIGHLIGHTS


--  Strategic increased proved plus probable reserves by 32% to 16.0 MMboe
    (66% oil) after accounting for year to date production. 
--  The Company realized a 40% increase the net present value of proved and
    probable reserves, discounted at 10% to $251 million as compared to
    year-end 2013.  
--  The net asset value per share calculated on a present value before tax
    of 10% ("PVBT10") increased to an estimated $0.70 per share at June 30,
    2014 inclusive of an internal land value of $80 million. 
--  Total proved and probable, drilled and future locations increased to 43
    which represent approximately 10% of the 400+ risked Muskeg locations at
    Marlowe. 
--  As a result of the strong performance of the 3 Muskeg wells drilled to
    date in 2014, average per well booking for proved and probable
    undeveloped reserves has increased by 30% to 250 MBOE from 190 MBOE at
    the end of 2013. 

Drilling Success Pushes Reserve Base Up 32%

The Company's oil, natural gas and natural gas liquids ("NGL") reserves were fully evaluated by McDaniel and Associates ("McDaniel") as at July 1, 2014, and are summarized below.


                          Light and                       Natural           
                             Medium             Natural       Gas        Oil
                          Crude Oil Heavy Oil       Gas   Liquids Equivalent
Gross Reserves(1)            (Mbbl)    (Mbbl)    (MMcf)    (Mbbl)  (MBoe(2))
----------------------------------------------------------------------------
Proved Producing              3,036        84     8,749         9      4,587
Proved Non-Producing            128         0     3,323         0        682
Proved Undeveloped            1,400         0     3,107         0      1,918
Total Proved                  4,564        84    15,179         9      7,187
----------------------------------------------------------------------------
Total Probable                5,926        38    17,248         4      8,842
----------------------------------------------------------------------------
Total Proved and Probable    10,489       123    32,427        12     16,029
----------------------------------------------------------------------------
----------------------------------------------------------------------------
(1) Gross Corporate reserves are the Company's total working interest share 
    before the deduction of any royalties and without including any royalty 
    interests of the Company. The July 1, 2014 reserves report has been     
    prepared in accordance with the definitions, procedures and standards   
    contained in the Canadian Oil and Gas Evaluation Handbook and NI 51-101-
    Standards of Disclosure for Oil and Gas Activities.                     
(2) 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.                          

Proved and probable producing reserves represent 40 percent of total proved and probable reserves. Strategic's light and medium oil, natural gas and NGL reserves were evaluated by McDaniel using McDaniel's product price forecasts effective July 1, 2014 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 July 1, 2014, 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 its assets.


Summary of Before Tax Net Present Value of Future Net Revenue (Forecast     
 Pricing) (1)                                                               
                                                                            
                                                     Discounted at          
($ thousands)                  Undiscounted         5%        10%        15%
----------------------------------------------------------------------------
Proved Producing                    112,286     93,931     81,625     72,827
Proved Non-Producing                  9,817      7,630      6,130      5,060
Proved Undeveloped                   47,460     31,505     20,901     13,496
----------------------------------------------------------------------------
Total Proved                        169,563    133,066    108,657     91,382
Total Probable                      323,693    202,742    142,506    107,908
----------------------------------------------------------------------------
Total Proved and Probable           493,256    335,808    251,163    199,291
----------------------------------------------------------------------------
----------------------------------------------------------------------------
(1) Tables may not add due to rounding. There is no assurance that the      
    forecast prices and costs assumptions will be attained and variances    
    could be material. The recovery and reserve estimates of Strategic's    
    crude oil, natural gas liquids and natural gas reserves provided herein 
    are estimates only and there is no guarantee that the estimated reserves
    will be recovered. Actual crude oil, natural gas and natural gas liquids
    reserves may be greater than or less than the estimates provided herein.

OPERATIONS UPDATE

Strategic initiated its summer Muskeg drilling program on June 13, 2014, and has since drilled three wells and spud a fourth. Strategic made enhancements in the Muskeg well design that have proven successful in reducing drilling times and associated costs while boosting production rates. As a result of the efficiencies, the Company is well ahead of schedule and anticipates having five Muskeg wells drilled, completed and on stream by the end of the third quarter and intends to keep one rig active for the remainder of the year.

Muskeg Production

The Muskeg 11-24 well was drilled and completed with a 13 stage frac and was the first well drilled on the western rim at Marlowe post break-up. Over the first 25 days the well has produced an oil equivalent rate of 487 boe/d (63% oil).

For comparison, the previous Muskeg 10-24 well was drilled and completed with a 15 stage frac prior to spring break-up. Average production rates over the first 30 and 90 days were 560 and 420 boe/d, respectively. This well has produced 38,600 boe (60% oil) in three months and continues to outperform the Company's pre drill estimates.

Reduced Drilling Cost

The Company has significantly decreased drilling days and other associated well costs. The average days to drill a horizontal Muskeg well post break-up has been 18 days, a decrease of 12 days from the wells drilled in the first quarter of 2014. The reduction in drilling days is a result of a shift change in the overall well plan that has been the first step in Strategic's continued focus on cost reductions. These reductions in drilling days have resulted in a cost savings of more than $1.0 million per well from the average cost of the previously drilled wells.

GUIDANCE

On January 17, 2014, Strategic provided annual guidance of 4,400-4,600 Boe/d of production (70% oil) and $35-40 million in funds from operations. Strategic spent a significant portion of the capital program during the first half of 2014 on facility and pipeline projects. During the first half of 2014, the Company planned to drill seven wells however drilling was limited to three Muskeg wells in order to manage debt levels and as a result the production and funds from operations did not meet guidance. On June 17, 2014 Strategic provided an exit guidance of 4,000 Boe/d.

With the efficiency data drawn from its recent successful summer drilling program, Strategic is evaluating financing alternatives to capitalize on the positive momentum and accelerate development. The Company plans to drill up to 10 wells during the second half of the year. Strategic is encouraged by its recent success in the Muskeg program and is increasing its 2014 exit production guidance from 4,000 Boe/d to 4,600 Boe/d.

Strategic is planning a 20 well program for 2015 focused on further Muskeg development and 3 exploratory Keg River tests.

ABOUT STRATEGIC

Strategic is a junior oil and gas company with a dominant land position of 500,000 acres in Canada. The company is committed to building a premier oil company through from its high-quality, concentrated reserve base, and constructing a company-operated integrated sales infrastructure to support the company's significant future growth. 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.

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) anticipated production rates; (ii) expected production and service costs and the impact of capital projects on production costs; (iii) expected capital spending; (iv) the Corporation's financial strength and capitalization; (v) estimates of reserves; (vi) potential financing and the use of proceeds; (vii) corporate production levels; (viii) wells to be drilled in 2014 and momentum from current drilling programs; (ix) timing for completion of drilling programs and resulting production additions; which are provided to allow investors to better understand the Corporation'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 Corporation's Annual Information Form for the year ended December 31, 2013 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 Corporation and industry standard rates of geologic and operational success. Actual results could differ materially from those expressed in, or implied by, these forward-looking statements. 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.

Basis of Presentation

This discussion and analysis of Strategic's oil and natural gas production and related performance measures is presented on a working-interest, before royalties basis. For the purpose of calculating unit information, the Corporation's production and reserves are reported in barrels of oil equivalent (Boe) and Boe per day (Boed). 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.

Non-IFRS Measurements

The Corporation utilizes certain measurements that do not have a standardized meaning or definition as prescribed by IFRS and therefore may not be comparable with the calculation of similar measures by other entities, including net debt, operating netback and funds from operations. Readers are referred to advisories and further discussion on Non-IFRS measurements contained in the Corporation's MD&A.

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.
Aaron Thompson, CA
CFO
403.767.2952
403.767.9122 (FAX)

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

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