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PetroBakken Announces 2012 Reserves Replacing 229% of 2012 Production and Achieving Proved Plus Probable FD&A Costs of

PetroBakken Announces 2012 Reserves Replacing 229% of 2012 Production and 
Achieving Proved Plus Probable FD&A Costs of $11.91/boe and F&D
Costs of $26.74/boe 
CALGARY, ALBERTA -- (Marketwire) -- 02/21/13 -- PetroBakken Energy
Ltd. ("PetroBakken" or the "Company") (TSX:PBN) is pleased to
announce the Company's 2012 year-end reserves and provide an
operational update.  
Unless otherwise noted, all reserves herein are "Company Interest"
reserves, which represent the Company's working interest and royalty
interest share of reserves, before deduction of the Company's royalty
obligations. All values in this press release are based on Sproule's
forecast prices and estimates of future operating and capital costs
at December 31, 2012. The Company's annual audit of our consolidated
financial statements is not yet complete and accordingly all
financial amounts herein are management's best estimates which are
unaudited and subject to change. 
HIGHLIGHTS 


 
--  Proved plus probable ("2P") reserves (before dispositions) grew by 10%
    to 206.8 million barrels of oil equivalent ("MMboe") at December 31,
    2012. 
    
--  The 2012 capital program replaced 229% of 2012 production through the
    addition of 35.8 MMboe of 2P reserves and achieved a recycle ratio of
    1.8 times, based on our 2012 operating netback of $47.89. 
    
--  The light oil and liquids weighting of our reserves is 82%. 
    
--  In 2012, PetroBakken delivered finding, development and net acquisition
    ("FD&A") costs, including changes in future development capital ("FDC"),
    of $11.45/boe for total proved reserves and $11.91/boe for 2P reserves. 
    
--  2012 acquisitions and divestitures resulted in the net disposition of
    11.1 MMBoe total proved reserves and 16.9 MMBoe of 2P reserves, yielding
    disposition metrics (including FDC) of $64.59/boe for total proved
    reserves and $43.38/boe for 2P reserves. 
    
--  Our F&D costs (including land purchases) were $26.83/boe for proved
    reserve additions and $26.74/boe for 2P reserves. 
    
--  Total FDC for our 2P reserves decreased by $94.6 million in 2012 to $1.8
    billion, with FDC per well remaining largely unchanged year over year
    across our resource plays. The ratio of proved developed to 2P reserves
    increased year
-over-year from 36% to 39% and the ratio of total proved
    to 2P reserves increased from 59% to 64%. 
    
--  Early stage success in our enhanced oil recovery ("EOR") initiatives
    resulted in the initial booking of additional 2P reserves related to our
    pilot natural gas flood in the Bakken. 
    
--  Production in January 2013, based on field estimates, was approximately
    49,700 barrels of oil equivalent per day ('boepd"). Currently, we have
    48 (36 net) wells at various stages of completion waiting to be brought
    on production. 
    
--  Our current combined dividend reinvestment plan ("DRIP") and stock
    dividend program ("SDP") participation is approximately 30%. 

 
RESERVES 
Sproule Associates Limited ("Sproule") has completed their evaluation
of PetroBakken's reserves, effective December 31, 2012 ("Sproule
Evaluation"). 
Year-end 2012 2P reserves grew 2% to 206.8 MMboe, with total organic
additions of 35.8 MMboe more than replacing our 16.9 MMboe of
non-core dispositions and 15.7 MMboe of production. Sproule's net
present value of our 2P reserves, discounted at 10%, is $4.0 billion
before tax and $3.4 billion on an after tax basis. Our operating
recycle ratio for 2012 was 1.8 times based on an operating netback of
$47.89/boe. These results were driven primarily by strong performance
in the Cardium business unit and continued maturation of our Bakken
business unit. 
We had an active program in 2012, drilling 217 net wells with a 98%
success rate. Total net capital expenditures in 2012 were $320
million, with $928 million spent on exploration and development
activities (including approximately $75 million of our 2013 capital
that was accelerated into November and December of 2012) and $24
million on land, less net dispositions of $632 million. 2P F&D costs
were $26.74/boe (including FDC), representing an improvement of 14%
over 2011, primarily due to innovations in our drilling and
completion techniques in the Cardium and lower service costs. The
Company's three- year weighted average F&D cost, including land and
FDC, is $28.37/boe, generating an operating recycle ratio of 1.8
times. 
2P reserves in the Cardium business unit increased from 72.2 MMboe in
2011 to 93.7 MMboe in 2012, representing a 30% increase and replacing
production by 461%. Our drilling activity led to additions of 28.0
MMBoe. In 2012, FD&A costs for this business unit were $18.42/boe,
generating an operating recycle ratio of 2.6 times based on our
operating netback for the business unit of $47.76/boe. The Cardium
business unit will continue to be a key source of growth for
PetroBakken, with a development drilling inventory of over 580 net
locations, of which 306 net locations were included in the Sproule
Evaluation. 
2P reserve growth in the Bakken business unit (before dispositions)
was relatively flat for 2012, replacing approximately 107% of
production. This moderation of growth is consistent with our business
plan of relatively stable production generating positive free cash
flow net of capital expenditures. Net reserve additions in the Bakken
business unit (before dispositions) were 7.0 MMboe, resulting in
year-end 2P reserves of 78.7 MMboe. The potential for future
EOR-related reserve growth in the Bakken is encouraging after
receiving initial 2P reserve recognition for the early stage success
of our pilot natural gas flood. At year-end, we had an inventory of
over 900 net locations in the business unit, of which 347 net
locations were included in the Sproule Evaluation. 


 
Reserves                                                                    
Forecast Prices(1)                                                          
As at December 31, 2012                                                     
                                                       Royalty              
                                                     Interests      Company 
                  Company Gross(2)                          (3)  Interest(4)
             ---------------------------------------------------------------
                Total           Natural                                     
                  Oil     NGL       Gas  Sub-total   Sub-total        Total 
                (Mbbl)  (Mbbl)    (MMcf)     (Mboe)      (Mboe)       (Mboe)
----------------------------------------------------------------------------
Proved                                                                      
 Developed                                                                  
 Producing     61,448   4,766    86,388     80,611         698       81,309 
Total Proved   99,185   7,503   143,694    130,637         722      131,359 
Proved +                                                                    
 Probable                                                                   
 (2P)         157,156  11,860   219,988    205,681       1,077      206,758 
----------------------------------------------------------------------------
                                                                            
Net Present Value - Before Tax ($ millions)(5)(6)                           
Forecast Prices(1)                                                          
As at December 31, 2012               
                                      
                                                      0%        5%       10%
----------------------------------------------------------------------------
Proved Developed Producing                      $  3,528  $  2,732  $  2,258
Total Proved                                       4,919     3,573     2,792
Proved + Probable (2P)                          $  8,186  $  5,442  $  4,014
----------------------------------------------------------------------------
                                                                            
Net Present Value - After Tax ($ millions)(5)(6)                            
Forecast Prices(1)                                                          
As at December 31, 2012                                                     
                                                      0%        5%       10%
----------------------------------------------------------------------------
Proved Developed Producing                      $  3,254  $  2,574  $  2,160
Total Proved                                       4,287     3,177     2,521
Proved + Probable (2P)                          $  6,700  $  4,545  $  3,404
----------------------------------------------------------------------------
                                                                            
Company Interest Reserve Reconciliation (Mboe)(4)                           
Forecast Prices(1)                                                          
As at December 31, 2012                                                     
                                            Developed      Total    Proved+ 
                                            Producing     Proved   Probable 
----------------------------------------------------------------------------
PetroBakken reserves at December 31, 2011      74,110    119,867    203,464 
2012 production                               (15,659)   (15,659)   (15,659)
Net dispositions                               (7,693)   (11,061)   (16,882)
Net additions and revisions                    30,551     38,212     35,835 
                                           ---------------------------------
PetroBakken reserves at December 31, 2012      81,309    131,359    206,758 
                                                                            
PetroBakken year-over-year increase in                                      
 reserves                                          10%        10%         2%
PetroBakken production replacement (7) (8)        195%       244%       229%
----------------------------------------------------------------------------
                                                                            
Notes:                                                                      
(1) Based on the Sproule price forecast effective December 31, 2012.        
(2) Company Gross reserves, which represent the Company's working interest  
    share of reserves excluding the Company's royalty interests in reserves 
    and before deduction of royalty obligations.                            
(3) Royalty interest reserves owned by the Company.                         
(4) "Company Interest" reserves, which represent the Company's working      
    interest share of reserves including the Company's royalty interests in 
    reserves and before deduction of the Company's royalty obligations.     
(5) Company working interest reserves value plus royalties received less    
    royalties and burdens.                                                  
(6) Estimated values of future net revenue disclosed in this press release  
    do not represent fair market values.                                    
(7) Represents total reserve additions, including revisions and before      
    dispositions, as a percentage of 2012 production.                       
(8) The disclosures required in accordance with National Instrument 51-101  
    of the Canadian Securities Administrators will be available in the      
    Company's Annual Information Form to be filed on the SEDAR website at   
    http://www.sedar.com/ prior to March 31, 2013.                          
                                                                            
                                                                            
F&D and FD&A Costs(1)                                                       
For the year ended December 31, 2012                                        
                                                Acquisitions                
                                          F&D              &         FD&A(3)
                                                Dispositions                
----------------------------------------------------------------------------
Capital expenditures (unaudited-                                            
 $000s)                                                                     
  Capital expenditures            $   952,556    $         -    $   952,556 
  Acquisition/(Disposition)                                                 
   capital                                  -       (632,173)      (632,173)
                                 -------------------------------------------
  Total capital                       952,556       (632,173)       320,383 
  Less: Land value                     24,323              -         24,323 
                                 -------------------------------------------
  Total capital excluding land                                              
   value                          $   928,233    $  (632,173)   $   296,060 
                                                                            
Change in FDC ($000s)                                                       
  Total Proved                    $    72,620    $   (82,252)   $    (9,632)
  Proved + Probable (2P)          $     5,545    $  (100,109)   $   (94,564)
----------------------------------------------------------------------------
                                                                            
Total costs ($000s)                                                         
  Total Proved                    $ 1,025,176    $  (714,425)   $   310,752 
  Proved + Probable (2P)          $   958,101    $  (732,282)   $   225,819 
                                                                            
Net reserve additions (mboe)                                                
  Total Proved                         38,212        (11,061)        27,151 
  Proved + Probable (2P)               35,835        (16,882)        18,953 
----------------------------------------------------------------------------
F&D and FD&A costs ($/boe)                                                  
 (including land)                                                           
  Total Proved                    $     26.83    $    (64.59)   $     11.45 
  Proved + Probable (2P)                26.74         (43.38)         11.91 
FD&A costs ($/boe) (excluding                                               
 land)                                                                      
  Total Proved                          26.19         (64.59)         10.55 
  Proved + Probable (2P)          $     26.06    $    (43.38)   $     10.63 
----------------------------------------------------------------------
------
                                                                            
For the year-ended Dec. 31, 2011                                            
F&D and FD&A costs ($/boe)                                                  
 (including land)                                                           
  Total Proved                    $     40.20    $    (76.28)   $     39.43 
  Proved + Probable (2P)                31.22         (55.73)         30.74 
F&D and FD&A costs ($/boe)                                                  
 (excluding land)                                                           
  Total Proved                          39.14         (76.28)         38.35 
  Proved + Probable (2P)          $     30.51    $    (55.73)   $     30.01 
                                                                            
For the 3 years-ended Dec. 31,                                              
 2012(2)                                                                    
F&D and FD&A costs ($/boe)                                                  
 (including land)                                                           
  Total Proved                    $     33.98    $    (11.65)   $     35.63 
  Proved + Probable (2P)                28.37          (5.64)         30.71 
F&D and FD&A costs ($/boe)                                                  
 (excluding land)                                                           
  Total Proved                          32.33         (66.70)         29.79 
  Proved + Probable (2P)          $     27.08    $    (37.66)   $     25.99 
----------------------------------------------------------------------------
(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) FD&A costs for 2010 include the corporate acquisitions of Berens Energy 
    Ltd., Rondo Petroleum Inc., Result Energy Inc. and certain other asset  
    acquisitions. For corporate acquisitions, acquisition costs represent   
    the portion of the purchase prices allocated to property, plant &       
    equipment and reflect the net present value of each corporate           
    acquisition as at its acquisition date based on 2P NPV10%, before tax.  
(3) The Company uses FD&A as a measure of the efficiency of its overall     
    capital program including the effect of acquisitions and dispositions.  
(4) Boe's may be misleading, particularly if used in isolation. A boe       
    conversion ratio of 1 boe for 6 thousand cubic feet of natural gas is   
    based on an energy equivalency conversion method primarily applicable at
    the burner tip and does not represent a value equivalency at the        
    wellhead.                                                               

 
OPERATIONAL UPDATE 
Production in January 2013, based on field estimates, was
approximately 49,700 boepd (83% light oil and liquids), up from our
fourth quarter 2012 average production of 47,192 boepd. In January,
our Bakken business unit produced approximately 19,800 boepd and our
Cardium business unit produced approximately 20,800 boepd, with the
remainder of the production generated by our southeast Saskatchewan
Conventional and AB/BC business units. During the month of January,
production was negatively impacted by approximately 600 boepd due to
restrictions at third-party facilities in the Cardium. 
Currently we have 13 rigs operating in the field, with 6 in the
Cardium, 4 in the Bakken, 1 in Southeast Saskatchewan, 1 in Swan
Hills and 1 in a new play area. Drilling activity year to date has
resulted in 39 (30 net) wells drilled, comprised of 13 (11 net) in
the Bakken, 12 (10 net) in the Cardium, 9 (5 net) in our Saskatchewan
Conventional business unit and 5 (4 net) on our emerging plays.
Currently, we have 48 (36 net) wells at various stages of completion
waiting to be brought on production. 
With our active program at the end of 2012 generating strong
production growth leading into year-end, we anticipate a base
production profile that will have steeper declines in the first part
of this year, followed by lower declines in the later part of the
year. We have forecasted an average production decline rate from
December 2012 to December 2013 of 39%. On a quarterly basis, our base
production decline from fourth quarter 2012 to fourth quarter 2013 is
expected to be 31%, normalizing the impacts of our strong production
additions during December 2012. We now forecast 2014 base declines to
range from 28% to 33%. 
Our 2013 capital expenditure plan of $675 million is more balanced
throughout the year, which will help us reduce production volatility
and manage declines while delivering anticipated year-over-year
average production growth of 8% to 12%. 
REALIZED PRICES AND COMMODITY DIFFERENTIALS 
North America is currently experiencing infrastructure challenges
resulting from growth in domestic production of oil and gas due to
the development of oil sands assets and the application of horizontal
multi-stage fracturing technology. The impact has been felt across
the continent through lower realized oil and gas prices, with WTI
prices trading at a discount to Brent pricing and North American
natural gas trading well below world prices. To compound the problem,
increased production from Western Canada and the mid-western United
States has resulted in additional discounts for crude produced in
Canada. The biggest impact has been on the price other producers
receive for heavy crudes, where discounts of 25% to 35% of WTI have
been experienced. The current differential for our light oil
production is approximately 7% off WTI, allowing us to benefit from
realized pricing that is more favourable than our internal 2013
forecast of US$90/bbl WTI with a 10% differential. 
Consistent with the rest of our industry, commodity price volatility
will impact our results and we will continue to take steps to
mitigate commodity price risks and attempt to optimize our rates of
return. 
DIVIDEND REINVESTMENT PROGRAM AND SHARE DIVIDEND PLAN 
PetroBakken has a DRIP in place that is available only to Canadian
PetroBakken shareholders. Our SDP is now available to both Canadian
shareholders and most non-Canadian shareholders. The DRIP and the SDP
allow shareholders to effectively receive their monthly PetroBakken
dividends as PetroBakken shares at a 5% discount to the market price
at the date of the dividend payment. Current combined DRIP and SDP
participation is approximately 30%. 
For further information regarding our SDP and DRIP, please visit
PetroBakken's website at www.petrobakken.com or contact Olympia Trust
Company at 403-668-8887, toll free at 1-800-727-4493 or via email at
corporateactions@olympiatrust.com. 
PetroBakken Energy Ltd. is an oil and gas exploration and production
company combining light oil Bakken and Cardium resource plays with
conventional light oil assets, delivering industry leading operating
netbacks, strong cash flows and production growth. PetroBakken is
applying leading edge technology to a multi-year inventory of Bakken
and Cardium light oil development locations, along with a significant
inventory of opportunities in the Horn River and Montney gas resource
plays in northeast BC. Our strategy is to deliver accretive
production and reserves growth, along with an attractive dividend
yield. 
Forward-Looking Statements 
This press release contains forward-looking statements. More
particularly, it contains forward-looking statements concerning 2013
production rates, potential exploration and development activities,
our 2013 capital budget, potential drilling locations, timing for
bringing restricted production on-stream and the future potential of
enhanced oil recovery projects. The forward- looking statements are
based on certain key expectations and
 assumptions, including
expectations and assumptions concerning the availability of capital,
the success of future drilling, completion, recompletion and
development activities, the performance of existing wells, the
performance of new wells, prevailing commodity prices and economic
conditions, the cost and availability of labour and services, the
ability to market our production, weather and access to drilling
locations. 
Although we believe that the expectations and assumptions on which
the forward-looking statements are based are reasonable, undue
reliance should not be placed on the forward-looking statements
because we can give no assurance that they will prove to be correct.
Since forward-looking statements address future events and
conditions, by their very nature they involve inherent risks and
uncertainties. Actual results could differ materially from those
currently anticipated due to a number of factors and risks. These
include, but are not limited to, risks associated with the oil and
gas industry in general (e.g., operational risks in development,
exploration and production; delays or changes in plans with respect
to exploration or development projects or capital expenditures; the
uncertainty of reserve estimates; the uncertainty of estimates and
projections relating to production, costs and expenses; reliance on
industry partners, availability of equipment and personnel,
uncertainty surrounding timing for drilling and completion activities
resulting from weather and other factors; changes in applicable
regulatory regimes and health, safety and environmental risks),
commodity price and exchange rate fluctuations and general economic
conditions. Certain of these risks are set out in more detail in our
Annual Information Form which has been filed on SEDAR and can be
accessed at www.sedar.com. There is no representation by PetroBakken
that actual results achieved during the forecast period will be the
same in whole or in part as those forecast. Except as may be required
by applicable securities laws, PetroBakken assumes no obligation to
publicly update or revise any forward - looking statements made
herein or otherwise, whether as a result of new information, future
events or otherwise. 
Caution Respecting BOE 
When used in this press release, Boe means a barrel of oil equivalent
on the basis of 1 Boe to 6 thousand cubic feet of natural gas. Boe
per day means a barrel of oil equivalent per day. Boe's may be
misleading, particularly if used in isolation . A Boe conversion
ratio of 1 Boe for 6 thousand cubic feet of natural gas is based on
an energy equivalency conversion method primarily applicable at the
burner tip and does not represent a value equivalency at the
wellhead. Given that the value ratio of oil compared to natural gas
based on currently prevailing prices is significantly different than
the energy equivalency conversion ratio of 6 Mcf to 1 BOE, utilizing
a conversion ratio of 6 Mcf to 1 BOE may be misleading as an
indication of value.
Contacts:
PetroBakken Energy Ltd.
John D. Wright
President and Chief Executive Officer
(403) 268.7800 
PetroBakken Energy Ltd.
Peter D. Scott
Senior Vice President and Chief Financial Officer
(403) 268.7800 
PetroBakken Energy Ltd.
Bill A. Kanters
Vice President Capital Markets
(403) 268.7800
www.petrobakken.com
 
 
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