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NuVista Energy Ltd. Announces Fourth Quarter and Year End 2012 Results

NuVista Energy Ltd. Announces Fourth Quarter and Year End 2012 Results 
CALGARY, ALBERTA -- (Marketwire) -- 03/06/13 -- NuVista Energy Ltd.
("NuVista") (TSX:NVA) is pleased to announce results for the three
and twelve months ended December 31, 2012 and provide an update on
its future business plans. 2012 was a pivotal and successful year for
NuVista as the business model was transformed in this challenging
natural gas price environment. In our year end 2011 press release we
indicated we would be carefully evaluating our business to preserve
value and ensure a sustainable model without jeopardizing our
financial flexibility. We also indicated a focus on proving the
valuable long term growth opportunities in the Wapiti Montney play,
and that we would pursue dispositions of non-strategic assets
throughout 2012 where attractive values could be realized and
financial flexibility enhanced. We are pleased to report that we have
delivered on these commitments. Through asset sales and strong Wapiti
drilling results we have transformed NuVista into a company focused
on its large and valuable condensate-rich Wapiti Montney play. We
have also reduced long-term debt, net of working capital, from $307
million at December 31, 2011 to $30 million at December 31, 2012,
enabling us to adequately capitalize this world class play. 
NuVista now has the improved asset quality and financial flexibility
to provide the foundation for a growth focused business model and the
creation of long-term shareholder value. Heading into 2013 the next
key steps in our Wapiti Montney-focused strategy are as follows: 


 
--  To deliver a repeatable Wapiti area Montney focused development program
    of production growth, continuing to drive the capital and operating
    efficiencies of scale into this play; 
--  To put in place long term processing infrastructure commitments
    underpinning this growth; 
--  To continue to delineate our reserve and contingent resource base in the
    upper layer of the Montney across the rest of our landholdings and into
    the deeper layers including the so-far under-evaluated Lower Montney; 
--  To execute an opportunistic non-core divestiture program in the range of
    $25 million to $50 million where it enhances our financial flexibility;
    and 
--  To mainta
in flexibility in our capital spending programs to ensure we
    can dial upwards or downwards as we monitor balance sheet strength, play
    results, and the fiscal environment. 

 
The business environment continued to be challenging for all energy
producers in 2012. AECO natural gas prices fell to a 14 year low
annual average price of $2.28/GJ down 35% from 2011. This decline was
primarily due to over supply of natural gas in the face of an
unusually warm winter. In addition, heavy oil prices were down 9% and
Edmonton light prices were down 4% compared to 2011 due to larger
discounts to WTI crude oil. Low heating demand and supply imbalance
have caused propane and butane benchmark prices to drop by 43% and
14% respectively in 2012 versus 2011. Only condensate (pentanes+)
maintained excellent pricing in Western Canada, averaging $100.86/Bbl
in 2012 (107% of WTI) versus $104.19/Bbl in 2011 on the back of
continued strong demand outstripping local supply due to increasing
oilsands bitumen blending needs. Due to continued oilsands growth in
the province, condensate price strength is expected to continue in
the long term, underpinning the strength of NuVista's Wapiti Montney
play in which strong economics are dominated by condensate revenues. 
NuVista is pleased to announce the appointment of two new directors
to its Board, effective March 5, 2013: Mr. Ron Eckhardt and Mr.
Sheldon Steeves. Both leaders have significant experience in various
aspects of the upstream oil and gas business and we welcome their
contributions as we move forward. In addition, Mr. Clayton Woitas has
informed the Board of Directors that he will not be standing for
re-election at the next Annual General Meeting in May 2013 due to
other commitments. The Board of Directors and staff of NuVista would
like to thank Mr. Woitas for his many years of dedicated leadership
and guidance as a Board member. 
Significant highlights for the fourth quarter and full year 2012
include: 


 
--  Completed the disposition of non-strategic assets in the fourth quarter
    of $228 million and for the full year totaling $238 million; 
 
--  Completed equity offerings for gross proceeds of $95 million on December
    11, 2012 with strong support from several existing and new strategic
    institutional investors; 
 
--  Achieved our guidance with an average production rate of 17,692 Boe/d
    for the three months ended December 31, 2012 and 22,577 Boe/d for the
    year ended December 31, 2012 compared to 25,306 Boe/d for the three
    months ended December 31, 2011 and 25,556 Boe/d for the year ended
    December 31, 2011. These production rates reflect the significant
    dispositions in the fourth quarter of 2012 and lower capital spending
    levels in 2012; 
 
--  Achieved funds from operations of $16.3 million for the three months
    ended December 31, 2012 compared to $48.5 million for the same period in
    2011 and $17.2 million for the three months ended September 30, 2012.
    Funds from operations for the full year 2012 totaled $75.7 million
    compared to $164.0 million in 2011. Lower funds from operations in 2012
    were primarily due to a decline in average realized natural gas prices
    from $3.87/Mcf in 2011 to $2.31/Mcf in 2012 and lower production volumes
    in 2012 due to divestitures; 
 
--  Successfully executed an annual capital program of $117 million. Drilled
    4 (3.0 net) wells during the fourth quarter and 18 (14.2 net) wells for
    the year ended December 31, 2012 for a success rate of 94%. 6 (5.9 net)
    of these wells were Wapiti Montney wells and the remainder of the wells
    were primarily W3/W4 heavy oil wells drilled in the first quarter of
    2012; 
 
--  Achieved proved plus probable finding and development costs for 2013 of
    $15.53/Boe including future development capital and all revisions with
    debt adjusted reserves growth of 8% per share. Achieved a proved plus
    probable reserves replacement ratio (excluding divested property
    production) of 315%, and increased our proved plus probable Reserves
    Life Index ("RLI") to 16 years; 
 
--  Increased our rolling hedging program to manage commodity exposure, with
    45% of 2013 oil and liquids production (net of royalties) hedged with an
    average WTI floor price of $91.30/Bbl and 38% of 2013 natural gas
    production (net of royalties) hedged at an average AECO floor price of
    approximately $3.00/Mcf; and 
 
--  Exited 2012 with net debt of $30 million and a trailing 12 month debt to
    annualized fourth quarter funds from operations of 0.4x, a significant
    improvement compared to $307 million and 1.9x at the end of 2011. 

 
Wapiti Montney Play Proven and Set to Grow 
During 2012 NuVista significantly advanced its Wapiti Montney play,
and coupled with industry results in the greater Wapiti and Resthaven
Montney area has confirmed the presence of a large condensate-rich
resource. We have moved up from one to an average of two rigs
drilling the Montney entering 2013. In 2013, approximately 80% of
NuVista's capital budget will be allocated to the Wapiti Montney play
and strong results are expected to have a continued significant and
positive impact on NuVista's overall corporate performance even in
the curren
t natural gas price environment. The premium priced
condensate production is the key economic driver of this play. During
early 2013, NuVista expects to enter into transportation and
processing agreements that will permit NuVista to provide greater
clarity on its future capital and growth plans. 
In the third quarter of 2012, NuVista completed its $70 million five
well and facilities pilot program. Based on the positive results from
these wells NuVista continued with its Montney drilling program and
this play has become the prime focus of NuVista's future growth and
value creation initiatives. NuVista owns Montney rights on 192 (176
net) sections concentrated in the greater Wapiti area after having
added 16% more lands to our block in the past year. At December 31,
2012, NuVista had five wells on production, each for a period of at
least four months, with average production on track with our 4.4 Bcf
raw (5.2 Bcfe) forecast typecurve with the valuable condensate
component of this production at 46 Bbls/MMcf (raw), exceeding our
typecurve of 35 Bbls/MMcf. Total C3+ liquids have averaged 59
Bbls/MMcf versus our typecurve expectation of 50 Bbls/MMcf. 
In September of 2012, NuVista conducted an independent study,
assigning contingent resource to the Middle Montney formation on
approximately 79 sections, or about 45% of its landholdings. The
assigned resource totaled 200 MMBoe (Best estimate), including 45
MMBoe of condensate with a resource net present value before tax,
discounted at 10% of $1.25 billion based on evaluator price forecasts
at that time. Details of this resource evaluation were disclosed in
NuVista's press release dated November 7, 2012. Our independently
evaluated 2012 year end reserves report highlights that significant
momentum is also building with NuVista's Wapiti Montney reserves.
Montney proved reserves increased to 15.7 MMBoe from 5.1 MMBoe and
proved plus probable reserves increased to 29.2 MMBoe from 12.1 MMBoe
on a year over year basis. At December 31, 2012, only 42 Wapiti
Montney wells have been included in NuVista's proved plus probable
reserves report. As shown in the reserves section of this document,
the 2012 Wapiti Montney activity almost offset the impact of
dispositions in the fourth quarter despite drilling with only one
rig.  
Since our last quarterly press release on November 7, 2012, NuVista
has completed and recently brought its sixth Middle Montney well onto
production. We have two more wells which have been successfully
fractured and completed with testing underway. They are expected to
be tied-in and on production in late March or early April of 2013
subject to spring break-up conditions. One fracture completion was
delayed due to a mechanical downhole equipment failure and we are
currently in the middle of remedial action. Completions and tie-ins
continue and we expect to be reporting several more 30-day initial
production results in our first quarter 2013 press release. We will
continue to update actual production versus typecurve as additional
production data is achieved. NuVista has noted industry data on at
least five wells with up to a year's production data which indicate
larger fracture treatments provide sustained results which support a
typecurve increase of 50% or more. Due to this and our technical
analysis, we are planning larger fracture treatments for early 2013.  
NuVista has drilled two vertical wells near the southwest and
northeast extremities of our Montney land blocks in order to acquire
logs and core samples towards evaluation of the upper and lower
Montney zones. This moves the resource evaluation outwards and
deeper. One of these wells is currently being completed in the lowest
Montney zone as we continue to lay the groundwork of proving the
deeper layers of the Montney formation. 
Impairment in Value of Oil and Gas Properties 
NuVista recognized a fourth quarter impairment to the value of
Property, Plant and Equipment and Goodwill in the amount of $70.5
million. These impairments are primarily due to economic revisions
associated with lower oil and natural gas price forecasts used in
reserves evaluation and secondarily due to technical reserve
revisions. For the year ended December 31, 2012, NuVista recognized
impairments to the value of Property, Plant and Equipment and
Goodwill totaling $218.5 million. The impairments are described in
more detail in NuVista's audited financial statements and
management's discussion and analysis for the year ended December 31,
2012, available through NuVista's filings on SEDAR at www.SEDAR.com.  
2013 Guidance 
In 2013, NuVista is taking a measured approach to its capital and
operating programs. NuVista expects to produce in the range of 15,250
Boe/d to 16,250 Boe/d in the first half of 2013, with the growth
benefits of the Montney program beginning to kick-in post breakup
with fourth quarter 2013 guidance of 17,500 Boe/d to 18,500 Boe/d
depending on second half capital spending. We expect to average two
rigs in the Montney formation in 2013, but have front-loaded our
capital in the first and second quarter of 2012 with prelaid
infrastructure and a temporary third rig, in order to best work
around spring break-up. As a result, first half 2013 spending is
anticipated to be approximately $110 million followed by reduction in
the second half of 2013. We have the flexibility to increase or
decrease this average annualized rig count of two subject to balance
sheet monitoring, dispositions, the commodity environment, ongoing
results, and infrastructure announcements. We will also continue our
focus on opportunistic asset divestitures, with a full year 2013
target of $25 million to $50 million in divestiture proceeds. 
We remain excited about the tremendous condensate-rich potential of
our Montney play at Wapiti, and the continued growth and exceptional
value that will be created as we build our scale and the efficiencies
that come with it. 


 
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Corporate Highlights                                                        
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                                    Three months ended            Year ended
                                          December 31,          December 31,
                                       2012       2011       2012       2011
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Financial                                                                   
($ thousands, except per share)                                             
Oil and natural gas revenue          48,277     96,578    242,012    369,234
Funds from operations(1)             16,278     48,467     75,672    164,019
  Per basic share                      0.15       0.49       0.75       1.68
  Per diluted share                    0.15       0.49       0.75       1.68
Net earnings (loss)                (59,042)  (158,462)  (195,200)  (143,800)
  Per basic share                    (0.56)     (1.59)     (1.93)     (1.47)
  Per diluted share                  (0.56)     (1.59)     (1.93)     (1.47)
Adjusted net earnings (loss)(1)    (10,920)   (19,965)   (52,462)   (33,366)
Per basic share                      (0.10)     (0.20)     (0.52)     (0.34)
Per diluted share                    (0.10)     (0.20)     (0.52)     (0.34)
Total assets                                              878,174  1,373,705
Long-term debt, net of adjusted                                             
 working capital(1)                                        30,388    306,791
Capital expenditures, before                                                
 dispositions                        29,194     57,784    116,638    161,830
Dispositions                        227,971      5,250    237,821     42,444
Weighted average common shares                                              
 outstanding (thousands):                                                   
  Basic                             106,006     99,513    101,148     97,557
  Diluted                           106,006     99,513    101,148     97,557
 
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Operating                                                                   
Production                                                                  
  Natural gas (MMcf/d)                 74.9      101.3       95.3      104.3
  Natural gas liquids (Bbls/d)        2,939      2,912      3,201      2,974
  Oil (Bbls/d)                        2,278      5,506      3,542      5,206
    Total oil equivalent (Boe/d)     17,692     25,306     22,577     25,556
Average product prices(2)                                                   
  Natural gas ($/Mcf)                  2.76       3.63       2.31       3.87
  Natural gas liquids ($/Bbl)         55.97      68.82      56.97      64.31
  Oil ($/Bbl)                         66.86      80.92      70.12      74.42
Operating expenses                                                          
  Natural gas and natural gas                                               
   liquids ($/Mcfe)                    1.78       1.69       1.87       1.70
  Oil ($/Bbl)                         15.53      14.41      11.00      14.63
    Total oil equivalent ($/Boe)      11.29      11.06      11.17      11.12
Operating netback ($/Boe)             14.82      24.88      13.36      21.56
Funds from operations netback                                               
 ($/Boe)(1)                           10.00      20.81       9.16      17.58
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Share trading statistics                                                    
  High                                 5.95       6.67       5.95      10.50
  Low                                  4.48       3.96       2.65       3.96
  Close                                5.87       5.24       5.87       5.24
Average daily volume                332,863    334,916    336,316    272,338
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NOTES:                                                                      
(1)    Funds from operations, funds from operations per share, funds from   
       operations netback, operating netback, adjusted net earnings and     
       adjusted working capital are not defined by GAAP in Canada and are   
       referred to as non-GAAP measures. Funds from operations are based on 
       cash flow from operating activities as per the statement of cash     
       flows before changes in non-cash working capital and asset retirement
       expenditures. Funds from operations per share is calculated based on 
       the weighted average number of common shares outstanding consistent  
       with the calculation of net earnings (loss) per share. Funds from    
       operations netback equals the total of revenues including realized   
       commodity derivative gains/losses less royalties, transportation,    
       operating, general and administrative, restricted stock units,       
       interest expenses and cash taxes calculated on a Boe basis. Adjusted 
       net earnings equals net earnings excluding after tax unrealized gains
       (losses) on commodity derivatives, impairments and gains (losses) on 
       property divestments. Operating netback equals the total of revenues 
       including realized commodity derivative gains (losses) less          
       royalties, transportation and operating expenses calculated on a Boe 
       basis. Adjusted working capital excludes the current portions of the 
       commodity derivative asset or liability. Total Boe is calculated by  
       multiplying the daily production by the number of days in the period.
       For more details on non-GAAP measures, refer to NuVista's            
       "Management's Discussion and Analysis".                              
(2)    Product prices include realized gains (losses) on commodity          
       derivatives.                                                         

 
2012 Year End Reserves Highlights 
Our 2012 independent engineering evaluation has been completed by GLJ
Petroleum Consultants Ltd. ("GLJ") effective December 31, 2012 (the
"GLJ Report").  
2012 year end proved reserves were 59.2 MMBoe compared to 69.5 MMBoe
at year end 2011. Proved plus probable year end reserves were 94.1
MMBoe compared to 109.7 MMBoe at year end 2011. NuVista's proved and
proved plus probable reserve additions (net of revisions) of 13.5
MMBoe and 19.1 MMBoe (over 90% Montney) respectively were offset by
reductions from the 2012 asset dispositions totaling 15.6 MMBoe of
proved reserves and 26.5 MMBoe of proved plus probable reserves. Also
included were negative proved plus probable revisions of 4.5 MMBoe,
83% of which were economic revisions due to reduced price forecasts.
Overall finding and development costs, including revisions and future
development capital, were $19.17/Boe for proved reserves and
$15.53/Boe for proved plu
s probable reserves. This resulted in a
corporate proved plus probable operating netback recycle ratio of
0.9. The corporate recycle ratio reflects the lower average operating
netback of our current production mix at low gas prices and is not
reflective of the economics of our Montney focused reserve additions
in 2012.  
2012 Wapiti Montney play specific proved plus probable finding and
development costs were $13.16/Boe. Fourth quarter operating netbacks
were $18.75/Boe which result in a play recycle ratio of 1.4x despite
the challenging natural gas price environment and high one-time
operating costs from midstream processors where a once-in-5-year
turnaround was completed. The Wapiti Montney play recycle ratio is
expected to increase significantly in 2013 (absent of commodity price
changes) as drilling and completion costs are reduced and operating
costs and netbacks are optimized through scale. The Wapiti Montney
recycle ratio and expectations for further improvements are one of
the many factors that provide us with the confidence to focus on this
play and its ability to create long-term growth and shareholder
value.  
Other highlights of our reserve report include a proved plus probable
RLI of 16.1 years, and a proved plus probable reserves replacement
ratio (excluding divested property production) of 315% (based on
fourth quarter 2012 production excluding divested properties).  
Summary of Corporate Reserves Data 
The following table outlines NuVista's corporate finding and
development costs in more detail: 


 
                      3 Year-Average                                        
                             (1)(2)          2012 (1)(2)         2011 (1)(2)
                 ------------------- ------------------- -------------------
                         Proved plus         Proved plus         Proved plus
                  Proved    probable  Proved    probable  Proved    probable
----------------------------------------------------------------------------
After reserve                                                               
 revisions and                                                              
 including                                                                  
 changes in                                                                 
 future                                                                     
 development                                                                
 capital ($/Boe)                                                            
  Finding and                                                               
   development                                                              
   costs          $22.66      $19.12  $19.17      $15.53  $30.58      $28.20
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(1) The aggregate of the exploration and development costs incurred in the  
    most recent financial year and the change during the year in estimated  
    future development costs generally will not reflect total finding and   
    development costs related to reserve additions for the year.            
(2) Drilling credits of nil and $1.3 million were recorded in 2012 and in   
    2011 respectively.                                                      

 
The following table provides summary reserve information based upon
the GLJ Report using the published GLJ January 1, 2013 price forecast
set forth below: 


 
                                     Natural Gas              Liquids       
----------------------------------------------------------------------------
                                    Working               Working           
                                   Interest        Net   Interest        Net
Reserves category(1)                 (MMcf)     (MMcf)    (MBbls)    (MBbls)
----------------------------------------------------------------------------
Proved:
                                                                     
  Developed producing               131,894    118,431      4,218      3,170
  Developed non-producing            24,606     21,942      1,936      1,530
  Undeveloped                        97,679     91,453      5,166      4,104
----------------------------------------------------------------------------
Total proved                        254,179    231,826     11,320      8,805
Probable                            147,177    133,892      6,839      5,133
----------------------------------------------------------------------------
Total proved plus probable          401,356    365,718     18,159     13,938
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                                         Oil                   Total        
----------------------------------------------------------------------------
                                    Working               Working           
                                   Interest        Net   Interest        Net
Reserves category(1)                (MBbls)    (MBbls)     (MBoe)     (MBoe)
----------------------------------------------------------------------------
Proved:                                                                     
  Developed producing                 3,609      3,315     29,810     26,223
  Developed non-producing               251        209      6,288      5,396
  Undeveloped                         1,611      1,406     23,056     20,752
----------------------------------------------------------------------------
Total proved                          5,471      4,929     59,155     52,372
Probable                              3,549      2,998     34,917     30,447
----------------------------------------------------------------------------
Total proved plus probable            9,020      7,927     94,072     82,819
----------------------------------------------------------------------------
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(1) Numbers may not add due to rounding.                                    

 
The following table is a summary reconciliation of the 2012 year end
reserves with the reserves reported in the 2011 year end reserves
report: 


 
                                                                   Total Oil
                       Natural Gas(1)     Liquids(1)    Oil(1) Equivalent(1)
                                (Bcf)        (MBbls)   (MBbls)        (MBoe)
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Total proved                                                                
 Balance, December 31,                                                      
  2011                          296.8          9,049    10,950        69,464
   Exploration and                                                          
    development(2)               59.9          5,391       407        15,774
   Technical revisions            6.0            226     (706)           515
   Economic revisions          (12.9)          (222)     (382)       (2,758)
   Acquisitions                     -              -         -             -
   Dispositions                (61.0)        (1,963)   (3,511)      (15,648)
   Production                  (34.5)        (1,162)   (1,287)       (8,192)
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 Balance, December 31,                                                      
  2012                          254.2         11,320     5,471        59,155
----------------------------------------------------------------------------
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Total proved plus                                                           
 probable                                                                   
 Balance, December 31,                                                      
  2011                          470.2         14,917    16,373       109,660
   Exploration and                                                          
    development(2)               87.4          7,896     1,158        23,628
   Technical revisions            4.1            333   (1,765)         (752)
   Economic revisions          (18.9)          (452)     (136)       (3,739)
   Acquisitions                     -              -         -             -
   Dispositions               (107.0)        (3,374)   (5,323)      (26,533)
   Production                  (34.5)        (1,162)   (1,287)       (8,192)
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 Balance, December 31,                                                      
  2012                          401.4         18,159     9,020        94,072
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(1) Numbers may not add due to rounding.                                    
(2) Reserve additions for Drilling Extensions, Infill Drilling and Improved 
    Recovery.                                                               

 
The following table summarizes the future development capital
included in the GLJ Report: 


 
----------------------------------------------------------------------------
                                                                 Proved plus
($ thousands, undiscounted)                              Proved     probable
----------------------------------------------------------------------------
Balance, December 31, 2011                              251,525      473,643
  Dispositions                                         (43,738)    (120,935)
  Economic revisions                                   (37,225)     (51,284)
  Exploration and development, improved recoveries                          
   and other                                            168,412      232,766
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Balance, December 31, 2012                              338,974      534,190
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Summary Wapiti Montney Play Reserves Data 
The following table provides summary Wapiti Montney play reserve
information based upon the GLJ Report using the published GLJ January
1, 2013 price forecast set forth below (with comparatives at January
1, 2012 price forecast): 


 
                                      2012                    2011          
----------------------------------------------------------------------------
                                 Working                 Working            
                                Interest         Net    Interest         Net
Reserves category                 (MBoe)      (MBoe)      (MBoe)      (MBoe)
----------------------------------------------------------------------------
Proved Producing                   2,572       2,312         668         577
----------------------------------------------------------------------------
Total Proved                      15,656      14,003       5,075       4,543
----------------------------------------------------------------------------
Total Proved plus Probable        29,172      25,876      12,125      10,781
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The following table summarizes the Wapiti Montney play future
development capital included in the GLJ Report: 


 
----------------------------------------------------------------------------
                                                                 Proved plus
($ thousands, undiscounted)                            Proved       probable
-----------------
-----------------------------------------------------------
Balance, December 31, 2011                             54,581        126,739
  Exploration and development changes in the year     119,882        159,245
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Balance, December 31, 2012                            174,463        285,984
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The estimates of reserves for the Wapiti Montney play may not reflect
the same confidence level as estimates of reserves of all NuVista's
properties due to the effect of aggregation. 
Summary of Corporate Net Present Value Data 
The estimated net present values of future net revenue before income
taxes associated with NuVista's reserves effective December 31, 2012
and based on published GLJ future price forecast as at January 1,
2013 as set forth below are summarized in the following table. 
The estimated future net revenue contained in the following table
does not necessarily represent the fair market value of the reserves.
There is no assurance that the forecast price and cost assumptions
contained in the GLJ 2012 Report will be attained and variations
could be material. The recovery and reserve estimates described
herein are estimates only. Actual reserves may be greater or less
than those calculated. 


 
                                               Discount factor (%/year)     
----------------------------------------------------------------------------
Reserves category (1)(2) ($ millions)             0%      8%     10%     12%
----------------------------------------------------------------------------
Proved:                                                                     
  Developed producing                            543     372     346     324
  Developed non-producing                        136      72      65      58
  Undeveloped                                    319     125     100      79
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Total proved                                     998     570     511     461
Probable                                         775     319     269     230
----------------------------------------------------------------------------
Total proved plus probable                     1,773     889     780     691
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(1) Numbers may not add due to rounding.                                    
(2) Estimate future net reserves do not represent the fair market value of  
    reserves                                                                

 
The following table is a summary of pricing and inflation rate
assumptions based on published GLJ forecast prices and costs as at
January 1, 2013: 


 
               Natural Gas                        Liquids                   
----------------------------------------------------------------------------
                 AECO Gas Price                                             
                         ($Cdn/      Edmonton Propane        Edmonton Butane
Year                     MMbtu)            ($Cdn/Bbl)             ($Cdn/Bbl)
----------------------------------------------------------------------------
Forecast                                                                    
2013                       3.38                 34.06                  65.45
2014                       3.83                 45.75                  70.46
2015                       4.28                 56.40                  72.38
2016                       4.72                 57.90                  74.31
2017                       4.95                 57.90                  74.31
2018                       5.22                 57.90                  74.31
2019                       5.32                 58.52                  75.11
2020                       5.43                 59.71                  76.62
2021                       5.54                 60.91                  78.17
2022                       5.64                 62.14                  79.75
2023                     +2%/yr                +2%/yr                 +2%/yr
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                              Oil                                           
----------------------------------------------------------------------------
                        Edmonton   Hardisty     Cromer                      
                       Par Price      Heavy     Medium                      
          WTI Cushing     40 API     12 API     29 API  Inflation   Exchange
             Oklahoma     ($Cdn/     ($Cdn/     ($Cdn/      Rates   Rate(2) 
Year        ($US/Bbl)       Bbl)       Bbl)       Bbl) %/ Year(1) ($US/$Cdn)
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Forecast                                                                    
2013            90.00      85.00      60.92      79.90        2.0       1.00
2014            92.50      91.50      68.36      84.18        2.0       1.00
2015            95.00      94.00      71.10      86.48        2.0       1.00
2016            97.50      96.50      73.02      88.78        2.0       1.00
2017            97.50      96.50      73.02      88.78        2.0       1.00
2018            97.50      96.50      73.02      88.78        2.0       1.00
2019            98.54      97.54      73.81      89.74        2.0       1.00
2020           100.51      99.51      75.32      91.55        2.0       1.00
2021           102.52     101.52      76.87      93.40        2.0       1.00
2022           104.57     103.57      78.44      95.28        2.0       1.00
2023           +2%/yr     +2%/yr     +2%/yr     +2%/yr        2.0       1.00
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(1) Inflation rate for costs.                                               
(2) Exchange rate used to generate the benchmark reference prices in this   
    table.                                                                  

 
CONSOLIDATED FINANCIAL STATEMENTS AND MD&A 
December 31, 2012 audited consolidated financial statements and notes
to the consolidated financial statements and Management's Discussion
and Analysis for NuVista Energy Ltd. have been filed on SEDAR
(www.sedar.com) under NuVista Energy Ltd. and can also be accessed on
NuVista's website at www.nuvistaenergy.com. 
ADVISORY REGARDING OIL AND GAS INFORMATION 
This news release contains the terms barrels of oil equivalent
("Boe") and thousand cubic feet equivalent ("Mcfe"). Natural gas is
converted to a Boe using six thousand cubic feet of gas to one barrel
of oil. In certain circumstances natural gas liquid volumes have been
converted to a Mcfe on the basis of one barrel of natural gas liquids
to six thousand cubic feet of gas. Boes and Mcfes may be misleading,
particularly if used in isolation. The foregoing conversion ratios
are 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 based on the
current price of crude oil as compared to natural gas 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. 
ADVISORY REGARDING FORWARD-LOOKING INFORMATION AND STATEMENTS 
This press release contains forward-looking statements and
forward-looking information (collectively, "forward-looking
statements") within the meaning of applicable securities laws. The
use of any of the words "will", "expects", "believe", "plans",
"pot
ential" and similar expressions are intended to identify
forward-looking statements. More particularly and without limitation,
this press release contains forward looking statements, including
management's assessment of: NuVista's future strategy, plans,
opportunities and operations; forecast production; production mix;
drilling, development, completion and tie-in plans and results;
targeted debt level; the timing, allocation and efficiency of
NuVista's capital program and the results therefrom; plans regarding
transportation and processing arrangements, the timing thereof and
the results therefrom; the anticipated potential of NuVista's asset
base; disposition plans, future production; the source of funding of
capital expenditures; the objectives and focus of NuVista's capital
program and the allocation thereof and results therefrom; recycle
ratios, drilling and completion costs, operating costs, netbacks;
NuVista's risk management strategy; expectations regarding future
commodity prices; and industry conditions.  
By their nature, forward-looking statements are based upon certain
assumptions and are subject to numerous risks and uncertainties, some
of which are beyond NuVista's control, including the impact of
general economic conditions, industry conditions, current and future
commodity prices, currency and interest rates, anticipated production
rates, borrowing, operating and other costs and funds from
operations, the timing, allocation and amount of capital expenditures
and the results therefrom, anticipated reserves and the imprecision
of reserve estimates, the performance of existing wells, the success
obtained in drilling new wells, the sufficiency of budgeted capital
expenditures in carrying out planned activities, competition from
other industry participants, availability of qualified personnel or
services and drilling and related equipment, stock market volatility,
effects of regulation by governmental agencies including changes in
environmental regulations, tax laws and royalties; the ability to
access sufficient capital from internal sources and bank and equity
markets; and including, without limitation, those risks considered
under "Risk Factors" in our Annual Information Form. We have included
the above summary of assumptions and risks related to forward-looking
statements provided in this news release in order to provide
investors with a more complete perspective on our current and future
operations and such information may not be appropriate for other
purposes. 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.
NuVista'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
NuVista will derive therefrom. NuVista 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. 
ADVISORY REGARDING CONTINGENT RESOURCES 
In this press release, NuVista has disclosed the results of an
evaluation of the contingent resources associated with the Middle
Montney formation of NuVista's Wapiti Montney play. The contingent
resource evaluation was prepared by GLJ, NuVista's independent
qualified reserves evaluator, in accordance with NI 51-101 and the
Canadian Oil and Gas Evaluation Handbook and is effective September
1, 2012. Contingent resources are those quantities of petroleum
estimated, as of a given date, to be potentially recoverable from
known accumulations using established technology or technology under
development but which are not currently considered to be commercially
recoverable due to one or more contingencies. The contingencies may
include factors such as economics, legal, environmental, political
and regulatory matters or lack of markets. A best estimate is the
estimate of the quantity of resource that will be recovered from the
accumulation, which under probabilistic methodology reflects a 50
percent confidence level. A low estimate is the estimate of the
quantity of resource that will be recovered from the accumulation,
which under probabilistic methodology reflects a 90 percent
confidence level. A high estimate is the estimate of the quantity of
resource that will be recovered from the accumulation, which under
probabilistic methodology reflects a 10 percent confidence level.
Contingent resources are further classified in accordance with the
level of certainty associated with the estimates. Contingent
resources do not constitute and should not be confused with reserves.
There is no certainty that it will be commercially viable to produce
any portion of the contingent resources. The contingent resources as
disclosed herein are considered economic based on forecast prices and
costs as at September 1, 2012. The majority of the 200 MMBoe best
estimate of the contingent resources associated with the Middle
Montney is represented by natural gas; however, 28.5% (56.8 MMBoe) of
the best estimate is represented by natural gas liquids including
44.5 MMBoe of which is classified as condensate. Additional
information relating to the contingent resources estimate for the
Middle Montney formation of NuVista's Wapiti Montney play, including
specific contingencies and significant positive and negative factors
associated with the estimate, can be found in NuVista's November 7,
2012 press release, which can be accessed on SEDAR (www.sedar.com)
under NuVista Energy Ltd. and can also be accessed on NuVista's
website at www.nuvistaenergy.com.
Contacts:
NuVista Energy Ltd.
Jonathan A. Wright
President and CEO
(403) 538-8501 
NuVista Energy Ltd.
Robert F. Froese
VP, Finance and CFO
(403) 538-8530
www.nuvistaenergy.com
 
 
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