Longview Announces 2013 Year End Financial Results and Independent Reserve Report

CALGARY, March 27, 2014 /CNW/ - Longview Oil Corp. ("Longview" or the "Corporation") (TSX: LNV) announces the financial and operating results for the year ended December 31, 2013 and the accompanying reserves as of December 31, 2013.

      Three months ended   Year ended    
      December 31,     December 31,    
      2013     2012     2013     2012    
                       
Financial ($000, except as otherwise indicated) (1)                    
Sales excluding realized hedging  $ 35,687    $ 35,257    $ 149,652    $ 139,774    
  per share (2)  $ 0.76    $ 0.75    $ 3.19    $ 2.99    
  per boe  $ 66.70    $ 60.75    $ 68.87    $ 61.25    
Funds from operations  $ 13,740    $ 15,639    $ 63,195    $ 60,420    
  per share (2)  $ 0.29    $ 0.33    $ 1.35    $ 1.29    
  per boe  $ 25.68    $ 26.95    $ 29.08    $ 26.47    
Net income (loss) and comprehensive                          
income (loss)  $ 2,495    $ (21,466)    $ 13,189    $ (8,268)    
  per share (2)  $ 0.05    $ (0.46)    $ 0.28    $ (0.18)    
Dividends declared  $ 6,570    $ 7,025    $ 27,670    $ 28,085    
  per share  $ 0.14    $ 0.15    $ 0.59    $ 0.60    
Expenditures on property, plant and equipment  $ 8,868    $ 11,763    $ 38,696    $ 44,491    
Payout ratio   112%     120%     105%     120%    
Working capital deficit  $ 9,486    $ 11,712    $ 9,486    $ 11,712    
Bank indebtedness  $ 117,642    $ 111,895    $ 117,642    $ 111,895    
Shares outstanding at end of period (000)   46,928     46,837     46,928     46,837    
Basic weighted average shares (000)   46,928     46,837     46,896     46,807    
                           
Operating (1)                          
Daily production                          
  Crude oil (bbls/d)   4,226     4,307     4,226     4,171    
  NGLs (bbls/d)   506     580     522     574    
  Natural gas (mcf/d)   6,503     8,526     7,232     8,938    
  Total boe/d @ 6:1   5,816     6,308     5,953     6,235    
Average prices (excluding hedging)                          
  Crude oil ($/bbl)  $ 79.15    $ 75.17    $ 84.70    $ 78.55    
  NGLs ($/bbl)  $ 56.66    $ 52.05    $ 53.34    $ 54.67    
  Natural gas ($/mcf)  $ 3.81    $ 3.44    $ 3.35    $ 2.56    
Operating netback ($/boe)                          
  Petroleum and natural gas sales  $ 66.70    $ 60.75    $ 68.87    $ 61.25    
  Royalties   (11.97)     (11.26)     (12.10)     (11.71)    
  Operating expense   (21.56)     (21.04)     (21.08)     (20.35)    
  Operating netback  $ 33.17    $ 28.45    $ 35.69    $ 29.19    
                         

(1) Boe, funds from operations, payout ratio and working capital deficit do not have a standardized meaning under GAAP.
Refer to "Non-GAAP Measures, Definitions and Abbreviations" in this press release.
   
(2) Based on basic weighted average shares outstanding.                
                     

 Message to Shareholders

  • Funds from operations increased by 5% for the year ended December 31, 2013 to $63.2 million from $60.4 million received in 2012.
    • On a per share basis, funds from operations for the year ended December 31, 2013 was $1.35 per share versus $1.29 per share in 2012, an increase of 5%.
    • The increase in funds from operations is attributable to strengthening pricing for Canadian oil sales, offset by lower total production.
  • The payout ratio for the year ended December 31, 2013 was 105% versus 120% for the year ended December 31, 2012.
    • Preservation of a sustainable payout ratio is the cornerstone of our business strategy which is based on the maintenance of a solid balance sheet while funding our dividend payments and capital expenditure programs primarily with funds from operations.

    Three months ended     Year ended    
    December 31,     December 31,    
($000)   2013     2012 % change   2013     2012 % change
Cash provided by operating activities  $ 14,867    $ 23,157 (36) %  $ 65,651    $ 66,396 (1) %
Changes in non-cash working capital   (174)     (6,373) (97) %   2,571     (1,856) (239) %
Interest on bank indebtedness   (1,334)     (1,193) 12 %   (5,521)     (4,794) 15 %
Expenditures on decommissioning liability   381     48 694 %   494     674 (27) %
Funds from operations  $ 13,740    $ 15,639 (12) %  $ 63,195    $ 60,420 5 %
Dividends declared   6,570     7,025 (6) %   27,670     28,085 (1) %
Capital expenditures (1)   8,868     11,763 (25) %   38,696     44,491 (13) %
Total funds outflow  $ 15,438    $ 18,788 (18) %  $ 66,366    $ 72,576 (9) %
Payout ratio (2)   112%     120%       105%     120%    
                             

(1) Capital expenditures includes expenditures on property, plant and equipment and expenditures on exploration and evaluation assets.
(2) Payout ratio is calculated as cash dividends declared and capital expenditures divided by funds from operations.    
                     
                     
  • 2013 Crude oil production remained comparable to 2012, increasing 1%, despite a 13% decrease in capital spending.
    • Extreme spring break-up conditions in Southeast Saskatchewan, where 70% of Longview's 2013 capital spending occurred, persisted throughout the second quarter and well into the third quarter of 2013 causing delays in our capital program. Additionally, extreme cold weather conditions created operational execution issues in the latter half of the fourth quarter of 2013. As a result, Longview was unable to add new production volumes to offset natural declines.
    • In spite of these delays in executing our 2013 drilling program, our crude oil and natural gas liquids production volumes remained relatively stable when compared to levels reported in 2012, demonstrating the high quality, low decline nature of our existing production base.
  • Crude oil revenue, which comprised 87% of total revenue in 2013, increased by 9% to $130.7 million from $120.0 million in 2012.
    • Longview realized better crude oil pricing as the price of WTI increased in 2013 averaging US$97.97/bbl versus US$94.19/bbl in 2012.
    • The WTI/Canadian oil price differential averaged $7.70/bbl in 2013, comparable to the average WTI/Canadian oil price differential of $7.46/bbl in 2012.
  • Operating netbacks increased by 22% from $29.19/bbl in 2012 to $35.69/bbl in 2013.
    • Operating costs were held constant with prior year levels as ongoing cost reduction efforts are offsetting inflationary pressures seen throughout the Western Canadian sedimentary basin.
    • Royalty expenses remained comparable to those of the prior year whereas royalties as a percentage of sales decreased due to lower rates associated with new production additions.
  • Total capital expenditures for the year ended December 31, 2013 amounted to $38.7 million. During 2013, we drilled a total of 18.1 net (24 gross) wells at a 95% success rate.
  • As at December 31, 2013, Longview's bank debt was $117.6 million on a credit facility of $200 million (59% drawn) resulting in an unutilized capacity of approximately $82.4 million. Longview currently pays a monthly dividend of $0.04 per common share and has declared and paid $28.1 million of dividends for the year ended December 31, 2013.

Reserve Additions Replace 103% of Production

  • At December 31, 2013 we had Proved plus Probable ("2P") Company interest reserves of 37.9 mmboe with proved reserves representing 51% of the total. Our 2013 capital program replaced 103% of production adding 2.2 mmboe of 2P reserves.
  • Finding, Development & Acquisition ("FD&A") cost was $31.45 /boe including the change in Future Development Capital ("FDC"), resulting in a one year recycle ratio of 1.0x using our 2013 annual operating netback of $32.57/boe.
  • Longview's December 31, 2013 Net Asset Value ("NAV") is $11.23/share at a 10% discount rate on a pre-tax basis.
  • The Corporation's 2P Reserve Life Index ("RLI") is 17.9 years using our fourth quarter 2013 average production rate.

Commodity Hedging Program

  • Longview's hedging program for calendar 2014 includes crude oil hedges of 2,000 bbls/d at $94.84/bbl for January to December 2014.
  • The Corporation will continue to hedge a portion of its production in the future in order to provide stability to cash flow in order to fund our dividend payments and capital expenditure program.

Possible Transportation Disruption

  • On March 24, 2014, the Corporation learned that due to a safety order from the National Energy Board, the Nevis North and Nevis South meter stations on the Nova Gas Transmission Ltd. ("NGTL") system are to be 100% restricted beginning on or before April 3, 2014. The restriction may affect Longview's ability to ship natural gas produced at its Nevis property and impact its crude oil and NGLs production. For the year ended December 31, 2013, our Nevis property produced approximately 570 bbl/d of crude oil, 165 bbl/d of NGLs and 3,880 mcf/d of natural gas. As of March 27, 2014, NGTL has provided no information as to the length of the restriction and the Corporation has yet to determine the extent, if any, of the impact on our production volumes.

Looking Forward

  • Longview's business strategy is based on providing shareholders with attractive long term returns by exploiting our assets in a financially disciplined manner and by acquiring additional long-life oil and gas assets of a similar nature. Longview has a base decline rate of approximately 19% which allows the Corporation to maintain production with a modest level of capital expenditures, as demonstrated during 2013 and 2012.
  • The 2014 drilling program is budgeted to increase by 44% from 2013 spending levels and will focus on the ongoing development of light oil reserves at 11 project areas in both Saskatchewan and Alberta. The majority of the 29 gross (22.3 net) wells in our 2014 drilling program are expected to qualify for reduced royalty rates and will be directed towards areas where we have existing infrastructure in place resulting in lower operating costs and comparatively high rates of return. In addition, approximately 14% of our total capital budget will be allocated to waterflood enhancement and facility improvements at seven project areas designed to increase reservoir pressures and establish additional drilling locations.
  • In order to fund the expansion of our capital development program, Longview pared back its monthly dividend to four cents per common share in December 2013. Longview anticipates that this strategy will lead to a 20% increase in cash flow per share, 16% increase in operating netbacks and 12% increase in crude oil production in 2014, with a payout ratio of 102%. This is supported by our expected base decline rate of 19%, which is among the lowest in the industry.

Financial Statements and MD&A

  • This press release should be read in conjunction with Longview's audited financial statements for the year ended December 31, 2013 together with the notes thereto, and Management's Discussion and Analysis for the three months and year ended December 31, 2013 which have been prepared in accordance with International Financial Reporting Standards ("IFRS") and posted on our website at www.longviewoil.com and filed under our profile on SEDAR at www.sedar.com.

APPENDIX 1 - Reserves Summary

Longview engaged our independent qualified reserves evaluator Sproule Associates Ltd. ("Sproule") to update the reserves analysis for the Company in accordance with National Instrument 51-101 and the COGE Handbook. Reserves and production information included herein is stated on a Company Interest basis (before royalty burdens and including royalty interests receivable) unless noted otherwise. This summary contains several cautionary statements that are specifically required by NI 51-101. In addition to the detailed information disclosed in this press release, more detailed information on a net interest basis (after royalty burdens and including royalty interests) and on a gross interest basis (before royalty burdens and excluding royalty interests) will be included in Longview's Annual Information Form ("AIF") and will be available at www.longviewoil.com and www.sedar.com.

Highlights - Company Interest Reserves (Working Interests plus Royalty Interests Receivable)

  December 31, 2013   December 31, 2012
Proved plus probable reserves (mboe)  37,936    38,263
Present Value of 2P reserves discounted at 10%, before tax ($000)(1)  $613,983    609,507
Net Asset Value per Share discounted at 10%, before tax (2)  $11.23    $11.40
Reserve Life Index (proved plus probable - years) (3)  17.9    16.6
Reserves per Share (proved plus probable) (2)  0.81    0.81
Bank debt per boe of reserves (4)  $3.50    $3.29

(1)  Assumes that development of each property will occur, without regard to the likely availability to the Company of funding required for that development.
(2) Based on 46.93 million shares outstanding at December 31, 2013 and 46.84 million shares outstanding at December 31, 2012.
(3) Based on Q4 average production and company interest reserves.
(4) Using boe's may be misleading, particularly if used in isolation. In accordance with NI 51-101, a boe conversion ratio for natural gas of 6 mcf: 1 bbl has been used which 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 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.

Company Interest Reserves (Working Interests plus Royalty Interests Receivable)

Summary as at December 31, 2013

            Natural       Oil
    Light & Medium Oil    Heavy Oil    Gas Liquids    Natural Gas  Equivalent
    (mbbl)    (mbbl)    (mbbl)    (mmcf)  (mboe)
Proved                         
Developed Producing    8,190    1,168   1,059   14,948 12,909
Developed Non-producing    550    55    7   156 637
Undeveloped    3,332    299    630   10,659  6,037
Total Proved    12,071    1,521   1,696    25,763 19,584
Probable    10,837    2,998   1,139   20,270 18,352
Total Proved + Probable    22,908    4,519    2,835   46,033 37,936

Proved plus Probable reserve additions for Company Interest Reserves were 2,232 mboe in 2013 which replaced 103% of annual production of 2,173 mboe.

Gross Working Interest Reserves (Working Interest only)

Summary as at December 31, 2013

      Natural     Oil
  Light & Medium Oil  Heavy Oil  Gas Liquids  Natural Gas  Equivalent
  (mbbl)  (mbbl)  (mbbl)  (mmcf)  (mboe)
Proved                
Developed Producing  8,060  1,165  1,051  14,889  12,758
Developed Non-producing  535  52  145  616
Undeveloped  3,326  299  630  10,659  6,031
Total Proved  11,921  1,515  1,686  25,693  19,405
Probable  10,740  2,988  1,133  20,224  18,232
Total Proved + Probable  22,661  4,503  2,819  45,918  37,636

Present Value of Future Net Revenue using Sproule price and cost forecasts (1)(2)
($000)

  Before Income Taxes Discounted at
    0%    10%  15%
Proved            
Developed Producing  $ 434,194  $ 264,391  $ 224,562
Developed Non-producing    23,841    16,294    13,984
Undeveloped    163,085    76,095    53,448
Total Proved    621,120    356,780    291,993
Probable    777,117    257,203    177,403
Total Proved + Probable  $ 1,398,237  $ 613,983  $ 469,396

(1) Longview's crude oil, natural gas and natural gas liquid reserves were evaluated using Sproule's product price forecast effective December 31, 2013 prior to the provision for income taxes, interests, debt services charges and general and administrative expenses. It should not be assumed that the discounted future revenue estimated by Sproule represents the fair market value of the reserves.
(2) Assumes that development of each property will occur, without regard to the likely availability to the Company of funding required for that development.

Sproule Price Forecasts

The present value of future net revenue at December 31, 2013 was based upon crude oil and natural gas pricing assumptions prepared by Sproule effective December 31, 2013. These forecasts are adjusted for reserve quality, transportation charges and the provision of any applicable sales contracts. The price assumptions used over the next seven years are summarized in the table below:

      WTI    Edmonton Light    Alberta AECO-C    Henry Hub    Exchange
      Crude Oil    Crude Oil    Natural Gas    Natural Gas    Rate
Year      ($US/bbl)    ($Cdn/bbl)    ($Cdn/mmbtu)    ($US/mmbtu)    ($US/$Cdn)
2014      94.65    92.64    4.00    4.17    0.94
2015      88.37     89.31    3.99    4.15    0.94
2016      84.25    89.63    4.00    4.17    0.94
2017      95.52    101.62    4.93    5.04    0.94
2018      96.96    103.14    5.01    5.12    0.94
2019      98.41    104.69    5.09    5.19    0.94
2020      99.89    106.26    5.18    5.27    0.94

Net Asset Value using Sproule price and cost forecasts (before income taxes)

The following net asset value ("NAV") table shows what is normally referred to as a "produce-out" NAV calculation under which the current value of the Company's reserves would be produced at forecast future prices and costs. The value is a snapshot in time and is based on various assumptions including commodity prices and foreign exchange rates that vary over time.

    Before Income Taxes Discounted at
($000, except per share amounts)      0%      10%      15%
Net asset value per share - December 31, 2012    $  26.38    $   11.40    $  8.40
Present value proved and probable reserves    $  1,398,237    $  613,983    $  469,396
Undeveloped acreage and seismic (2)       46,072       46,072       46,072
Working capital (deficit) and other       (15,307)      (15,307)      (15,307)
Bank debt       (117,642)      (117,642)       (117,642)
Net asset value - December 31, 2013    $ 1,311,360    $  527,106    $   382,519
Net asset value per share (1) - December 31, 2013    $  27.94    $  11.23    $  8.15

(1) Based on 46.93 million shares outstanding at December 31, 2013.
(2) Internal estimate.

Gross Working Interest Reserves Reconciliation

    Light &    Heavy    Natural Gas    Natural    Oil
    Medium Oil    Oil    Liquids    Gas    Equivalent
Proved    (mbbl)    (mbbl)    (mbbl)    (mmcf)    (mboe)
Opening balance Dec. 31, 2012     13,238    1,766    1,587    27,427    21,162
Extensions    784    27    180    2,476    1,404
Improved recovery            -
Infill drilling    429    46    82    893    705
Discoveries      -       -    -
Economic factors    107    15      384    192
Technical revisions    (1,293)    (4)    23    (2,845)    (1,748)
Acquisitions            -
Dispositions    (3)    (133)      (2)    (136)
Production     (1,341)    (202)    (190)    (2,640)    (2,173)
Closing balance at Dec. 31, 2013    11,921    1,515    1,686    25,693    19,405
                     
    Light &    Heavy    Natural Gas    Natural    Oil
    Medium Oil    Oil    Liquids    Gas    Equivalent
Proved + Probable    (mbbl)    (mbbl)    (mbbl)    (mmcf)    (mboe)
Opening balance Dec. 31, 2012     22,610    4,602    2,632    48,189    37,876
Extensions    1,753    285    246    3,480    2,864
Improved recovery            -
Infill drilling    611    71    108    1,184    988
Discoveries            -
Economic factors    180     23    (11)    (223)    155
Technical revisions    (1,147)    70    34    (4,068)    (1,721)
Acquisitions        -    -    -
Dispositions    (6)    (346)      (4)    (352)
Production    (1,341)    (202)    (190)    (2,640)    (2,173)
Closing balance at Dec. 31, 2013    22,661    4,503    2,819    45,918    37,636

Finding, Development & Acquisitions Costs ("FD&A") (1)(2)(3)

2013 FD&A Costs - Gross Working Interest Reserves excluding Future Development Capital

      Proved      Proved + Probable
Capital expenditures ($000)    $  40,648     $  40,648
Acquisitions net of dispositions ($000)            (1,952)       (1,952)
Total capital ($000)    $  38,696     $ 38,696
Total mboe, end of year       19,405       37,636
Total mboe, beginning of year       21,162       37,876
Production, mboe       2,173       2,173
Reserve additions, mboe       416       1,933
FD&A costs ($/boe)            
  2013    $  93.13    $ 20.02
  2012    $  16.23    $ 17.26
  Three year average (4)    $  26.16    $ 15.41
F&D costs ($/boe)            
  2013    $  97.83    $ 21.03
  2012     $  16.23    $ 17.26
  Three year average (4)    $ 22.18    $ 17.85

NI 51-101
2013 FD&A Costs - Gross Working Interest Reserves including Future Development Capital

      Proved      Proved + Probable
Capital expenditures ($000)    $  40,648    40,648
Acquisitions net of dispositions ($000)      (1,952)      (1,952)
Net change in Future Development Capital ($000)      2,877      31,491
Total capital ($000)    41,573    70,187
Reserve additions, mboe      416      1,933
FD&A costs ($/boe)            
  2013    100.05    36.31
  2012    24.42    29.10
  Three year average (4)    28.60    18.03
F&D costs ($/boe)            
  2013     104.75    37.32
  2012     24.42    29.10
  Three year average (4)     32.28    32.62

(1) Under NI 51-101, the methodology to be used to calculate FD&A costs includes incorporating changes in future development capital ("FDC") required to bring the proved undeveloped and probable reserves to production. For continuity, Longview has presented herein FD&A costs calculated both excluding and including FDC. In addition, the Corporation has presented FD&A costs which includes the effects of acquisitions and dispositions. The Corporation has also presented finding and development ("F&D") costs excluding the effects of acquisitions and dispositions as required under NI 51-101. FD&A costs have been presented because acquisitions and dispositions can have a significant impact on the Corporation's ongoing reserve replacement costs and excluding these amounts could result in an inaccurate portrayal of the Corporation's cost structure.
(2) 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 reserves additions for that year. Changes in forecast FDC occur annually as a result of development activities, acquisition and disposition activities and capital cost estimates that reflect Sproule's best estimate of what it will cost to bring the proved undeveloped and probable reserves on production.
(3) In all cases, the FD&A number is calculated by dividing the identified capital expenditures by the applicable reserve additions.  Boes may be misleading, particularly if used in isolation.  A boe conversion ratio of 6 MCF:1 BBL 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 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.
(4)  Longview commenced operations on April 14, 2011 with the acquisition of certain oil-weighted assets from Advantage Oil & Gas Ltd. Therefore, the three year average figures are calculated beginning April 14, 2011.

Forward-Looking Statements

Certain information regarding Longview set forth in this press release, including management's assessment of the Corporation's future plans and operations, contains forward-looking statements that involve substantial known and unknown risks and uncertainties. The use of any of the words "anticipate", "continue", "estimate", "expect", "may", "will", "project", "should", "believe" and similar expressions are intended to identify forward looking statements. Such statements represent Longview's internal projections, estimates or beliefs concerning, among other things, an outlook on the estimated amounts and timing of capital expenditures or other expectations, beliefs, plans, objectives, assumptions, intentions or statements about future events or performance. These statements are only predictions and actual events or results may differ materially. Although Longview believes that the expectations reflected in the forward-looking statements are reasonable, it cannot guarantee future results, levels of activity, performance or achievement since such expectations are inherently subject to significant business, economic, competitive, political and social uncertainties and contingencies. Many factors could cause Longview's actual results to differ materially from those expressed or implied in any forward-looking statements made by, or on behalf of, Longview.

In particular, forward-looking statements included in this press release include, but are not limited to, statements with respect to Longview's business strategy; the Corporation's dividend policy; the Corporation's hedging program and its plans to hedge a portion of its production in the future; expected restrictions on the south meter stations on the NGTL and the effect of such restrictions on Longview's production and its ability to ship natural gas produced at its Nevis property; Longview's plans to exploit its assets in a financially disciplined manner and to acquire additional long-life oil and gas assets of a similar nature; the Corporation's expectations as to an increased 2014 drilling program and the focus of such drilling program;  Longview's expectations that the wells in its 2014 drilling program will qualify for reduced royalty rates and will be directed towards areas where the Corporation existing infrastructure in place and the effect on operating costs and rates of return; anticipated allocation of the Corporation's total capital budget to waterflood enhancement and facility improvements at seven project areas designed to increase reservoir pressures and establish additional drilling locations; anticipated effect of reduction in dividend on cash flow per share, operating netbacks, crude oil production and the Corporation's payout ratio and base decline rate; and the Corporation's anticipated drilling, development and recompletion activities. In addition, statements relating to "reserves" are deemed to be forward looking statements, as they involve the implied assessment, based on certain estimates and assumptions, that the reserves described can be profitably produced in the future.

These forward-looking statements are subject to numerous risks and uncertainties, certain of which are beyond the Corporation's control, including, but not limited to, the impact of general economic conditions; volatility in market prices for crude oil and natural gas; industry conditions; volatility of commodity prices; currency fluctuation; imprecision of reserve estimates; liabilities inherent in crude oil and natural gas operations; environmental risks; incorrect assessments of the value of acquisitions and exploration and development programs; competition from other producers; the lack of availability of qualified personnel or management; changes in tax laws, royalty regimes and incentive programs relating to the oil and gas industry; changes to legislation and regulations and how they are interpreted and enforced; hazards such as fire, explosion, blowouts, cratering, and spills, each of which could result in substantial damage to wells, production facilities, other property and the environment or in personal injury; unexpected drilling results; changes or fluctuations in production levels; risk that the expected restrictions on the south meter stations on the NGTL will affect Longview's production and its ability to ship natural gas produced at its Nevis property; delays in anticipated timing of drilling and completion of wells; stock market volatility; ability to access sufficient capital from internal and external sources and the other risks considered under "Risk Factors" in Longview's Annual Information Form, which is available on www.sedar.com and www.longviewoil.com.

With respect to forward-looking statements contained in this press release, Longview has made assumptions regarding, among other things: current commodity prices and royalty regimes; availability of skilled labour; timing and amount of capital expenditures; future exchange rates; the price of oil and natural gas; the impact of increasing competition; conditions in general economic and financial markets; availability of drilling and related equipment; effects of regulation by governmental agencies; royalty rates;  future operating costs; that the Corporation will have sufficient cash flow, debt or equity sources or other financial resources required to fund its capital and operating expenditures and requirements as needed; availability of funds for the payment of dividends and our capital program; that the Corporation's conduct and results of operations will be consistent with its expectations; that the Corporation will have the ability to develop the Corporation's properties in the manner currently contemplated; that current or, where applicable, proposed assumed industry conditions, laws and regulations will continue in effect or as anticipated; and the estimates of the Corporation's production and reserves volumes and the assumptions related thereto (including commodity prices and development costs) are accurate in all material respects.

Management has included the above summary of assumptions and risks related to forward-looking information provided in this press release in order to provide shareholders with a more complete perspective on Longview's future operations and such information may not be appropriate for other purposes. Longview's actual results, performance or achievement could differ materially from those expressed in, or implied by, these forward-looking statements and, accordingly, no assurance can be given that any of the events anticipated by the forward-looking statements will transpire or occur, or if any of them do so, what benefits that the Corporation will derive there from. Readers are cautioned that the foregoing lists of factors are not exhaustive. These forward-looking statements are made as of the date of this press release and the Corporation disclaims any intent or obligation to update publicly any forward-looking statements, whether as a result of new information, future events or results or otherwise, other than as required by applicable securities laws.

Advisory

Any references in this news release to test rates or initial production rates ("IP"), including IP rates of 30 days or less, are useful in confirming the presence of hydrocarbons, however, such rates are not necessarily indicative of long-term performance or ultimate recovery and such rates are not determinative of the rates at which such wells will continue production and decline thereafter. Additionally, such rates may also include recovered "load oil" fluids used in well completion stimulation. While encouraging, readers are cautioned not to place reliance on such rates in calculating the aggregate production for the Corporation.

Non-GAAP Measures, Definitions and Abbreviations

The Corporation discloses several financial measures in this press release that do not have any standardized meaning prescribed by International Financial Reporting Standards ("IFRS" or "GAAP"), such as funds from operations and payout ratio. Management believes that these financial measures are useful supplemental information to analyze operating performance and provide an indication of the results generated by the Corporation's principal business activities. Longview's method of calculating these measures may differ from other companies, and accordingly, they may not be comparable to similar measures used by other companies. Please see the Corporation's most recent management's discussion and analysis, which is available on www.sedar.com for additional information about these financial measures.

"Boe" may be misleading, particularly if used in isolation. A boe conversion ratio of six thousand cubic feet of natural gas to one barrel of oil equivalent (6 Mcf: 1 bbl) 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 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.

"Funds from operations" represents cash provided by operating activities, adjusted for expenditures on decommissioning liability, changes in non-cash working capital and interest on bank indebtedness.

"Payout ratio" is calculated as cash dividends declared and capital expenditures divided by funds from operations.

"Working capital deficit" includes trade and other receivables, prepaid expenses and deposits, trade and other accrued liabilities and due to parent.

The following abbreviations used in this press release have the meanings set forth below:

bbls   barrels   mcf   thousand cubic feet
bbls/d   barrels per day   mcf/d   thousand cubic feet per day
boe   barrels of oil equivalent, on the basis of
1 bbl of oil for 6 mcf of natural gas
       
boe/d   barrels of oil equivalent per day        
             

 

 

 

 

 

SOURCE Longview Oil Corp.

For further information:

Investor Relations
Toll free: 1-855-813-0313

LONGVIEW OIL CORP.
700, 400 -3rd Avenue SW
Calgary, Alberta
T2P 4H2
Phone:  (403) 718-8100
Fax:      (403) 718-8300
Web Site: www.longviewoil.com
E-mail:  ir@longviewoil.com