PetroBakken Announces Current Production of 45,000 boepd and

PetroBakken Announces Current Production of 45,000 boepd and Third
Quarter Funds Flow From Operations of $122 Million 
CALGARY, ALBERTA -- (Marketwire) -- 11/07/12 -- PetroBakken Energy
Ltd. (the "Company" or "PetroBakken") (TSX:PBN) is pleased to provide
an operations update and to announce our third quarter financial and
operating results. 
CURRENT OPERATING HIGHLIGHTS 


 
--  Early November production is approximately 45,000 barrels of oil
    equivalent per day ("boepd"), based on field estimates, with 53 net
    wells in inventory waiting to be completed or brought on stream. 
--  For the balance of 2012, we plan on drilling 42 net wells and bringing
    74 net wells on production. 
--  A new facility in our Cardium business unit at Brazeau is expected to be
    completed by the end of November, allowing us to bring on incremental
    production in excess of 2,500 boepd. 
--  We are accelerating a portion of Q1 2013 capital program into the fourth
    quarter of this year and expect 2012 capital expenditures of $975
    million prior to dispositions ($340 million net of dispositions), which
    will positively impact our 2013 production rates. 
--  As part of our capital plan expansion, we have acquired 218 net sections
    of land in a new potential resource play area, bringing our new prospect
    land inventory to 512 net sections. 
--  We are currently running 17 drilling rigs, 6 fracing spreads and 13
    completion service rigs. 

 
THIRD QUARTER FINANCIAL & OPERATING HIGHLIGHTS 
(In this press release, quarterly comparisons are third quarter 2012
compared to third quarter 2011, and the first nine months of 2012
compared to the first nine months of 2011 unless otherwise noted.) 


 
--  Third quarter production averaged 38,503 boepd (82% light oil and
    liquids), relatively flat over the third quarter of 2011, due primarily
    to the disposition of producing assets in the first half of 2012 and a
    delayed start to the second half 2012 capital program. 
--  Nine month production averaged 41,303 boepd, a 7% increase over the same
    period in 2011. 
--  Our operating netback for the third quarter was $45.09/boe, influenced
    by lower realized commodity prices, as light oil differentials to WTI
    were wider than historical levels. 
 
--  Funds flow from operations was $122 million ($0.65 per basic share) for
    the quarter, a 20% decrease over the third quarter of 2011, primarily
    due to lower realized commodity prices. 
--  Capital expenditures before dispositions totalled $283 million in the
    third quarter, resulting in 82 net wells drilled. 
--  Net income was $24 million ($0.13 per basic share) for the third
    quarter. 

 
Summary of Results 


 
----------------------------------------------------------------------------
                                    Three months ended   Nine months ended  
                                       September 30,       September 30,    
----------------------------------------------------------------------------
                                         2012      2011      2012       2011
----------------------------------------------------------------------------
Oil and natural gas sales             237,833   272,346   808,399    828,595
Funds flow from operations (1)        122,037   152,357   428,754    478,734
  Per share - basic ($)                  0.65      0.81      2.28       2.56
Adjusted Net income(1)                 27,449    29,671   155,767    138,938
  Per share - basic ($)                  0.15      0.16      0.83       0.74
Net Capital Expenditures(1)           275,233   271,786   (36,410)   669,688
Net debt (1)                        1,500,655 1,338,425 1,500,655  1,338,425
Dividends per share ($)                  0.24      0.24      0.72       0.72
Cash dividends per share ($)             0.09      0.24      0.31       0.72
Common Shares, end of period (000)                                          
 (2)                                  189,704   187,237   189,704    187,237
Operating netback ($/boe) (1) (3)                                           
 (4)                                    45.09     50.04     48.00      52.89
Average daily production (3) (boe)     38,503    39,074    41,303     38,636
----------------------------------------------------------------------------
                                                                            
(1) Non-GAAP measure. See "Non-GAAP Measures" section.                      
(2) Denotes basic common shares outstanding.                                
(3) Six Mcf (thousand cubic feet) of natural gas is equivalent to one barrel
    of oil equivalent ("boe").                                              
(4) Net of transportation expenses.                                         

 
CURRENT OPERATIONS UPDATE 
Our activity has continued at a strong pace since the end of
September, and we currently have 17 drilling rigs, 6 fracing spreads
and 13 completion service rigs working in the field. Since the end of
the third quarter, we have drilled 41 net wells and brought 31 net
wells on production, with a current inventory of 53 wells waiting to
be completed or brought on production. As expected, the execution of
our program has increased production from 39,200 boepd in September
to 45,000 boepd in early November, based on field estimates. 
2012 CAPITAL EXPENDITURES 
We are updating our forecasted 2012 capital expenditures to $975
million, prior to dispositions ($340 million after dispositions).
This increase reflects an active land acquisition strategy in a
potential new resource play in which we accumulated 218 net sections
and an acceleration of certain 2013 capital investments in drilling
and completions, facility construction, and optimization efforts
which we expect to positively impact production results in early
2013. As part of our plan, we will be drilling an additional 15 net
Cardium wells, while partially offsetting this effort by reducing our
Bakken business unit drilling count by 10 net wells, which were
targeting Mississippian opportunities. Facility and optimization
capital that is being accelerated, particularly in southeast
Saskatchewan, will allow us to increase production and should reduce
downtime during spring break-up in 2013. Given the timing of this
capital acceleration there will be minimal impact on 2012 production
rates, as the majority of the impact will be seen in the first
quarter of 2013. We are maintaining our 2012 exit rate production
guidance of 52,000 to 56,000 boepd.  
OPERATING RESULTS 
Our third quarter average production of 38,503 boepd was comprised of
15,767 boepd from the Bakken business unit, 14,721 boepd from the
Cardium business unit, and the remainder from the Saskatchewan
Conventional and AB/BC business units. A delayed start to our second
half capital program resulted in third quarter production levels
being flat to the second quarter. However, reduced industry activity
during the second half of 2012 has provided increased access to
services, allowing us to catch up on our drilling program. The
results of this activity will be realized in the fourth quarter.  
Average Daily Production 


 
                             Three months ended        Nine months ended    
                             September 30, 2012       September 30, 2012    
                          Oil &NGL     Gas   Total  Oil &NGL     Gas   Total
Business Unit              (bbl/d) (Mcf/d) (boe/d)   (bbl/d) (Mcf/d) (boe/d)
------------------------------------------------
----------------------------
 Bakken                     15,007   4,561  15,767    16,182   5,516  17,102
 Conventional (SE SK)        5,205   1,391   5,437     5,346   1,412   5,581
 Cardium (central AB)       10,625  24,577  14,721    12,224  21,036  15,730
 Alberta/BC                    825  10,519   2,578       981  11,456   2,890
----------------------------------------------------------------------------
                            31,662  41,048  38,503    34,733  39,420  41,303
----------------------------------------------------------------------------
----------------------------------------------------------------------------

 
Production expenses on a per boe basis were 7% lower in the third
quarter of 2012 as compared to the second quarter. This decrease was
primarily due to reduced trucking costs resulting from the completion
of our new Cardium facility. Production expenses for the first nine
months of 2012 were relatively consistent to 2011 on a unit of
production basis and slightly higher on a total basis due to
increased production. 
Q3 2012 Drilling Activity 


 
                           Drilled    Completed  On Production  Inventory(1)
Business Unit            Gross   Net Gross   Net  Gross    Net  Gross    Net
----------------------------------------------------------------------------
  Bakken                    48    40    39    30     42     31     18     17
  Conventional (SE SK)      19    10    17     8     14      6      8      3
  Cardium (central AB)      43    32    12     8     18     15     31     23
  Alberta/BC                 -     -     -     -      -      -      -      -
----------------------------------------------------------------------------
Total                      110    82    68    46     74     52     57     43
----------------------------------------------------------------------------
----------------------------------------------------------------------------
(1) Inventory refers to the number of wells pending completion and/or tie-  
    in.                                                                     

 
The majority of the capital expenditures in the third quarter were
focused on drilling and completions following spring break-up. We
executed an aggressive program that represented a 4% increase over
the same period last year. Drilling activity focused primarily on the
Bakken and Cardium business units, where 40 and 32 net wells were
drilled, respectively, with an additional 10 net wells drilled in our
Saskatchewan Conventional business unit. We completed 46 net wells
during the quarter, including 30 net wells in the Bakken business
unit and 8 net wells in each of the Cardium and Saskatchewan
Conventional business units. The production resulting from this
activity, including bringing on the 43 net wells in inventory at the
end of the quarter, will largely be realized in the fourth quarter. 
Bakken Business Unit  
In southeast Saskatchewan, the Bakken business unit averaged 15,767
boepd of production, an increase of six percent over the second
quarter, as the majority of our shut-in production related to spring
break-up conditions was restored. Drilling activity increased
throughout the third quarter, resulting in 40 net wells drilled and
31 net wells brought on production. Currently, we have 7 drilling
rigs operating in this business unit and have drilled 17 net wells
since quarter-end, with 15 net wells waiting to be completed or
brought on production. 
Cardium Business Unit  
In Alberta, the Cardium business unit averaged 14,721 boepd of
production, a decrease of seven percent from the second quarter of
2012, due to a delayed start to our second half capital program and
restricted production and downtime resulting from routine maintenance
of individual wells and facilities. A battery and a gathering system
expansion in the Brazeau area of West Pembina is expected to be
completed by the end of November, which will significantly reduce
current well restrictions, reduce trucking expenses and add over
2,500 boepd of production. During the quarter we drilled 32 net wells
and brought 15 net wells on production in the Cardium, most of which
were in the last half of the quarter and had minimal impact on
production during the period. We currently have 8 drilling rigs
operating in the Cardium and have drilled 16 net wells since the end
of September, with 29 net wells in inventory waiting to be completed
or brought on production. 
Other Activity 
Our southeast Saskatchewan Conventional business unit continues to
provide a low decline, light oil production base. Production averaged
5,437 boepd in the third quarter of 2012, and we drilled 10 net
wells. Two drilling rigs are currently operating in this area. 
In our Alberta/BC business unit, we have 2,578 boepd of production
and have compiled an inventory of over 294 net sections of land
prospective for new oil resource plays in one or more of the Nordegg,
Montney, Duvernay and Swan Hills zones. We plan to drill 6 wells in
the fourth quarter targeting the Swan Hills or Montney zones. In
addition, we have now accumulated 218 net sections of land through
Crown sales in another new potential resource play area.  
FINANCIAL RESULTS 
Our production of 38,503 boepd and operating netback of $45.09/boe
resulted in funds flow from operations of $122 million ($0.65 per
basic share) for the third quarter, a 20 percent decrease over the
same period in 2011 due primarily to lower realized oil prices and
higher interest costs. Our adjusted net income for the third quarter
was approximately $27 million ($0.15 per basic share), similar to the
third quarter of 2011, largely resulting from a 10% lower operating
netback and unrealized risk management loss (due to a rising WTI
price) being offset by a non-cash foreign exchange gain (due to a
stronger Canadian dollar versus the US dollar). Capital expenditures
were in line with the third quarter of 2011, but are expected to be
higher in the fourth quarter this year compared to last year. 
Realized wellhead commodity prices in the third quarter were weaker
this year than last year. WTI prices in the quarter were 4% higher
than last year but were volatile, and wider oil differentials caused
our realized prices to be approximately 8% lower than the third
quarter of 2011. Oil differentials improved each month during the
quarter, with September being slightly narrower than the historical
average. However, taken as a whole, our average third quarter 2012
differential to WTI was approximately 12%, compared to 1% last year.
The improvement in differentials during the quarter has been
supported by the expansion of rail capacity to move oil, but we
expect differentials to widen again due to major refinery turnarounds
occurring in the fourth quarter of 2012 and the first quarter of
2013.  
Our monthly dividend of $0.08 per share has remained constant since
the Company's inception. During the third quarter, total dividends of
$45 million were declared. The dividend represented 37% of funds flow
from operations for the quarter; however participation in our
Dividend Reinvestment Plan is at 62%, resulting in cash dividends of
approximately $17 million, or 14% of quarterly funds flow from
operations.  
As at September 30, 2012, PetroBakken had $0.4 billion of debt drawn
on our $1.4 billion credit facility. We currently have $1
.0 billion
of available credit and a debt capital structure with diversified
sources of credit and a layered maturity profile that compliments the
long term nature of our light oil-focused assets. 
We remained active with our Normal Course Issuer Bid, purchasing
approximately 493,000 shares in the third quarter at a total cost of
$6.4 million ($13.09/share). Year-to-date, we have purchased
approximately 3.8 million shares at a total cost of $51.7 million
($13.51/share). 
OUTLOOK  
Beginning in the third quarter, drilling activity levels increased as
we ramped up the execution of our 2012 drilling program. This
activity has continued into the fourth quarter, during which we plan
to drill a further 83 wells and bring an additional 105 wells onto
production. The addition of these new wells to our early November
production rate of approximately 45,000 boepd, together with the
removal of current production restrictions caused by facility
constraints, puts us on pace to meet our forecast 2012 exit
production rate of 52,000 boepd to 56,000 boepd.  
PETROBANK REORGANIZATION 
On October 29, 2012, PetroBakken and Petrobank entered into an
arrangement agreement that will see Petrobank shareholders receive
Petrobank's proportionate interest in PetroBakken (the
"Reorganization"). Pursuant to the Reorganization, a new Alberta
corporation will be formed ("New Petrobank") which will acquire all
of the existing assets and liabilities of Petrobank, including
THAI(R) and related technologies, but excluding Petrobank's ownership
interest in PetroBakken shares, and existing shareholders of
Petrobank will receive one share of New Petrobank for each Petrobank
share held.  
Following this distribution of Petrobank's heavy oil business to New
Petrobank, Petrobank and PetroBakken will, through a series of
transactions, amalgamate, with the resulting company to continue
under the name "PetroBakken Energy Ltd." ("New PetroBakken").
Existing PetroBakken shareholders will receive one share of New
PetroBakken for every share of PetroBakken held prior to the
Reorganization and Petrobank shareholders will receive, in aggregate,
a number of New PetroBakken shares equal to the number of PetroBakken
shares held by Petrobank immediately prior to the Reorganization,
approximately 1.06 to 1.10 New PetroBakken shares for each Petrobank
share held. The number of shares outstanding in New PetroBakken will
be the same as the number of shares outstanding in PetroBakken
immediately prior to the Reorganization.  
The Reorganization will not result in any changes to the business of
PetroBakken or our existing Board and senior management. The
Reorganization is subject to the approval of the shareholders of each
of Petrobank and PetroBakken. 
THIRD QUARTER FINANCIAL & OPERATING TABLES 
The following table provides a summary of PetroBakken's financial and
operating results for the three and nine months ended September 30,
2012 and 2011. The interim consolidated financial statements with
Management's Discussion and Analysis ("MD&A") are available on the
Company's website at www.petrobakken.com and will be available on the
SEDAR website at www.sedar.com. 


 
                                                Three months ended          
                                                   September 30,            
----------------------------------------------------------------------------
                                               2012        2011    % change 
----------------------------------------------------------------------------
Financial ($000s, except where noted)                                       
Oil and natural gas sales                   237,833     272,346         (13)
Funds flow from operations (1)              122,037     152,357         (20)
Per share - basic ($)                          0.65        0.81         (20)
          - diluted ($)(2)                     0.62        0.76         (18)
Adjusted Net income(1)                       27,449      29,671          (7)
Per share - basic ($)                          0.15        0.16          (6)
          - diluted ($)                        0.14        0.16         (13)
Net Capital expenditures(1)                 275,233     271,786           1 
Total assets                              6,131,988   6,346,447          (3)
Net debt (1)                              1,500,655   1,338,425          12 
Total debt(1)                             1,795,765   2,117,600         (15)
Dividends                                    45,392      44,880           1 
  Per share ($)                                0.24        0.24           - 
Cash dividends                               17,224      44,880         (62)
  Per share ($)                                0.09        0.24         (63)
Payout ratio (%)(1)                              37          29          28 
Cash payout ratio (%)(1)                         14          29         (52)
Common shares, end of period (000)                                          
  Basic                                     189,704     187,237           1 
  Diluted(2)                                214,817     220,261          (2)
----------------------------------------------------------------------------
----------------------------------------------------------------------------
Operations                                                                  
  Oil, NGL and natural gas revenue (3)        66.58       75.67         (12)
  Royalties                                    9.09       12.20         (25)
  Production expenses                         12.40       13.13          (6)
----------------------------------------------------------------------------
  Operating netback ($/boe) (1) (4)           45.09       50.04         (10)
Average daily production (4)                                                
  Oil and NGL (bbls)                         31,662      33,112          (4)
  Natural gas (Mcf)                          41,048      35,776          15 
----------------------------------------------------------------------------
  Total (boe)                                38,503      39,074          (1)
----------------------------------------------------------------------------
----------------------------------------------------------------------------
                                                                            
 
                                          Nine months ended September 30,   
----------------------------------------------------------------------------
                                              2012         2011    % change 
----------------------------------------------------------------------------
Financial ($000s, except where noted)                                       
Oil and natural gas sales                  808,399      828,595          (2)
Funds flow from operations (1)             428,754      478,734         (10)
Per share - basic ($)                         2.28         2.56         (11)
          - diluted ($)(2)        
            2.19         2.36          (7)
Adjusted Net income(1)                     155,767      138,938          12 
Per share - basic ($)                         0.83         0.74          12 
          - diluted ($)                       0.82         0.73          12 
Net Capital expenditures(1)                (36,410)     669,688           - 
Total assets                             6,131,988    6,346,447          (3)
Net debt (1)                             1,500,655    1,338,425          12 
Total debt(1)                            1,795,765    2,117,600         (15)
Dividends                                  136,112      134,692           1 
  Per share ($)                               0.72         0.72           - 
Cash dividends                              59,501      134,692         (56)
  Per share ($)                               0.31         0.72         (57)
Payout ratio (%)(1)                             32           28          14 
Cash payout ratio (%)(1)                        14           28         (50)
Common shares, end of period (000)                                          
  Basic                                    189,704      187,237           1 
  Diluted(2)                               214,817      220,261          (2)
----------------------------------------------------------------------------
----------------------------------------------------------------------------
Operations                                                                  
  Oil, NGL and natural gas revenue (3)       71.04        77.98          (9)
  Royalties                                  10.26        12.36         (17)
  Production expenses                        12.78        12.73           - 
----------------------------------------------------------------------------
  Operating netback ($/boe) (1) (4)          48.00        52.89          (9)
Average daily production (4)                                                
  Oil and NGL (bbls)                        34,733       32,965           5 
  Natural gas (Mcf)                         39,420       34,030          16 
----------------------------------------------------------------------------
  Total (boe)                               41,303       38,636           7 
----------------------------------------------------------------------------
----------------------------------------------------------------------------
                                                                            
(1) Non-GAAP measure. See "Non-GAAP Measures" section.                      
(2) Consists of common shares, stock options, deferred common shares, and   
    incentive shares on the same basis as net income. Convertible debentures
    have been included as at the period end date based on the conversion    
    price as of that date.                                                  
(3) Net of transportation expenses.                                         
(4) Six Mcf (thousand cubic feet) of natural gas is equivalent to one barrel
    of oil equivalent ("boe").                                              

 
INVESTOR CONFERENCE CALL  
Management of PetroBakken will be holding a conference call for
investors, financial analysts, media and any interested persons on
Thursday, November 8, 2012 at 9:00 a.m. (MST) (11:00 a.m. EST) to
discuss PetroBakken's third quarter financial and operating results. 
The investor conference call details are as follows: 
Live call dial-in number: 1-800-745-8951 
Replay dial-in numbers: 1-416-626-4100 / 1-800-558-5253 
Reservation number: 21610564 
Live audio webcast link:
http://events.digitalmedia.telus.com/petrobakken/110812/index.php 
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. 
Non-GAAP Measures. This press release contains financial terms that
are not considered measures under IFRS, such as funds flow from
operations, adjusted net income, funds flow per share, adjusted net
income per share, payout ratio, net debt, total debt, operating
netback and net capital expenditures. These measures are commonly
utilized in the oil and gas industry and are considered informative
for management and stakeholders. Specifically, funds flow from
operations reflects cash generated from operating activities before
changes in non-cash working capital. Adjusted net income is
determined by adding back any losses or deducting any gains on the
derivative liabilities, adding back any losses or deducting any gains
on settlement of convertible debentures, and adding back impairments.
Payout ratio is determined as dividends paid as a percentage of funds
flow from operations. Management considers funds flow from
operations, funds flow per share, adjusted net income, adjusted net
income per share, and payout ratio important as it helps evaluate
performance and demonstrate the ability to generate sufficient cash
to fund future growth opportunities, pay dividends and repay debt.
Net debt includes bank debt outstanding plus accounts payable less
accounts receivable and prepaid expenses plus the full value
outstanding on the senior unsecured notes converted to Canadian
dollars at the exchange rate on the period end date. Total debt
includes net debt plus the full value outstanding on the convertible
debentures converted to Canadian dollars at the exchange rate on the
period end date. Net debt and total debt are used to evaluate
PetroBakken's financial leverage. Profitability relative to commodity
prices per unit of production is demonstrated by an operating
netback. Operating netback reflects revenues less royalties,
transportation costs, and production expenses divided by production
for the period. Net capital expenditures represent capital
expenditures, including exploration and evaluation expenditures, less
proceeds from asset dispositions. Funds flow from operations, funds
flow per share, adjusted net income, adjusted net income per share,
payout ratio, net debt, total debt, operating netbacks, and net
capital expenditures may not be comparable to those reported by other
companies nor should they be viewed as an alternative to cash flow
from operations or other measures of financial performance calculated
in accordance with IFRS. Further information in respect of these
non-GAAP measures is set forth in our MD&A. 
Forward Looking Statements. Certain information provided in this
press release constitutes forward-looking statements. Specifically,
this press release contains forward-looking statements relating to
financial results, results from operations, future production rates,
proposed exploration and development activities, our drilling
prospect inventory, projected costs, the timing of certain projects,
our future debt levels and liquidity position and the terms of and
timing for completion of the Reorganization. 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 new and existing wells,
prevailing commodity prices and economic conditions, the availability
of labour and services, weather and access to drilling locations, the
geological nature of the formations targeted and the receipt of
required shareholder and regulatory approvals and satisfaction of
other conditions to the Reorganization. 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 fac
tors, changes in applicable regulatory regimes and
health, safety and environmental risks), commodity price and exchange
rate fluctuations, general economic conditions and risks associated
with the approval of the Reorganization by our shareholders, the
receipt of regulatory approvals and the satisfaction of other
conditions to the Reorganization. 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. 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. 
Natural gas volumes have been converted to barrels of oil equivalent
("boe"). Six thousand cubic feet ("Mcf") of natural gas is equal to
one barrel of oil equivalent based on an energy equivalency
conversion method primarily attributable at the burner tip and does
not represent a value equivalency at the wellhead. Boes may be
misleading, especially if used in isolation.
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
ir@petrobakken.com
www.petrobakken.com
 
 
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