Delphi Energy Increases Year End 2011 Reserves to Over 40 Million BOE with Finding and Development Costs of $12.46 per BOE

CALGARY, ALBERTA--(Marketwire - Feb. 29, 2012) -

Delphi Energy Corp. (TSX:DEE.TO - News) ("Delphi" or the "Company") is pleased to report its crude oil and natural gas reserves information for the year ended December 31, 2011.

2011 Highlights

--  Increased total proved reserves by ten percent to 25.1 million barrels

    of oil equivalent ("boe") and total proved plus probable reserves by 16

    percent to 40.2 million boe compared to 2010, with minimal change in

    future development costs ("FDC"); 

--  Increased proved developed producing liquids (light and medium crude

    oil, and natural gas liquids) reserves by 42 percent, total proved

    liquids reserves by 27 percent and total proved plus probable liquids

    reserves by 34 percent compared to 2010; 

--  Achieved finding, development and acquisition costs ("FD&A"), including

    changes in FDC, of $18.42 per boe for total proved reserves and $12.46

    per boe for total proved plus probable reserves; 

--  Improved three year average FD&A costs, including change in FDC, to

    $16.44 per boe for total proved reserves and $12.43 per boe for total

    proved plus probable reserves; 

--  Achieved a recycle ratio of 1.95 in 2011 compared to 1.63 in 2010 and

    consistent with the three year average of 1.95; 

--  Replaced 2011 production of 8,871 boe/d (29 percent oil and natural gas

    liquids) by 2.75 times with total proved plus probable reserve additions

    (net of all revisions and dispositions) of 8.9 million boe; 

--  Increased proved plus probable reserve life index ("RLI") to 12.4 years

    in 2011 compared to 11.7 years in 2010. 

Reserves at December 31                        2011        2010    % change 



Proved Developed Producing (mboe)            15,123      13,944           8 

Proved Reserves (mboe)                       25,074      22,721          10 

Proved Plus Probable Reserves (mboe)         40,182      34,521          16 



Proved FD&A including change in FDC                                         

 ($/boe)(1)                                   18.42       18.06           2 

Proved Plus Probable FD&A including                                         

 change in FDC ($/boe)(1)                     12.46       14.91         (16)



Operating Netback ($/boe)(1)                  24.25       24.35           - 

Proved Plus Probable Recycle Ratio(1)          1.95        1.63          19 



2011 Wells Drilled                            Gross         Net  % of Total 



Crude oil                                         9         6.0          25 

Liquids rich natural gas (greater than                                     

 40 bbl/mmcf NGL content)                        16        12.8          54 

Natural gas (less than 40 bbl/mmcf NGL                                      

 content)                                         5         5.0          21 


Total                                            30        23.8         100 

Success rate (%)                                100         100             


(1) Certain financial and operating information included in this press release for the quarter and year ended December 31, 2011, such as finding and development costs, production information, operating netbacks, recycle ratios and net asset value calculations are based on unaudited financial results for the year ended December 31, 2011 and are subject to the same limitations as discussed under forward-looking statements outlined at the end of this release. These estimate amounts may change upon completion of the audited financial statements for the year ended December 31, 2011 and those changes may be material.

Reserves Summary

GLJ Petroleum Consultants Ltd. ("GLJ"), the Company's independent petroleum engineering firm, has evaluated Delphi's crude oil, natural gas and natural gas liquids reserves as at December 31, 2011 and prepared a reserves report in accordance with National Instrument 51-101 "Standards of Disclosure for Oil and Gas Activities" and the "Canadian Oil and Gas Evaluation Handbook".

To view the image associated with this release, please visit the following link:

Following is summary information detailed in the GLJ reserves report at December 31, 2011 as compared to December 31, 2010.

                             December 31, 2011           December 31, 2010  


                                  Oil &                                     

                          Gas      NGLs     Total  % of    Total            

Reserves(1)             (mmcf)   (mbbls) (mboe)(2)  P+P (mboe)(2)  % Change 



 Developed Producing   69,297     3,573    15,123    38   13,944          8 

 Developed Non-                                                             

  producing            11,390       510     2,409     6    2,857        (16)

 Undeveloped           34,103     1,859     7,543    19    5,920         27 


Total Proved          114,790     5,942    25,075    63   22,721         10 

Probable               71,072     3,263    15,107    37   11,800         28 


Total Proved Plus                                                           

 Probable             185,862     9,205    40,182   100   34,521         16 


(1) Delphi's reserves represent the operated and non-operated working interest share of reserves before deduction of royalties and include any royalty interests of the Company.

(2) Oil equivalent amounts have been calculated using a conversion rate of six thousand cubic feet of natural gas to one barrel of oil (6:1).

Net Present Value of Reserves

In 2011, the value of the net reserve additions of 8.9 million boe largely offset the decrease in GLJ's forecast natural gas prices as of January 1, 2012 as compared to January 1, 2011. The estimated future net revenues associated with Delphi's reserves at December 31, 2011, based on the GLJ January 1, 2012 price forecast, are summarized in the following table.

                          Future net revenue before income taxes discounted 

                          at a rate of:                                     

($ thousands)(1)                  0%        5%       10%       15%       20%



 Developed Producing        316,018   249,550   206,872   177,479   156,111 

 Developed Non-producing     48,642    34,780    26,906    21,901    18,444 

 Undeveloped                139,091    83,516    53,798    36,063    24,613 


Total Proved                503,751   367,846   287,576   235,443   199,168 

Probable                    362,466   199,454   126,544    87,815    64,673 


Total Proved Plus Probable  866,217   567,300   414,120   323,257   263,841 


(1) The estimated future net revenues are before the deduction of estimated future site restoration costs but are reduced for estimated future abandonment costs for reserve wells and estimated capital for future development associated with the reserves. The estimated values disclosed do not necessarily represent fair market value.

Reserves Reconciliation

The following reconciliation of Delphi's reserves compares changes in the Company's reserves at December 31, 2010 to the reserves at December 31, 2011, each evaluated in accordance with National Instrument 51-101 definitions.

                                                                Proved Plus 

                                           Proved     Probable     Probable 

                                            (mboe)       (mboe)       (mboe)


Reserves at December 31, 2010              22,721       11,800       34,521 

Extensions and Improved Recovery            5,530        4,753       10,283 

Technical Revisions                         1,371       (1,344)          27 

Dispositions                                 (291)        (260)        (551)

Economic Factors                           (1,019)         159         (860)

Production                                 (3,238)           -       (3,238)


Reserves at December 31, 2011              25,074       15,108       40,182 


Finding and Development Costs

Finding and development costs in 2011 and over the past three years were as follows:

                                            2011             2009 - 2011    

                                                 Proved              Proved 

                                                   Plus                Plus 

                                       Proved  Probable    Proved  Probable 


Capital ($ thousands)                                                       

 Exploration and Development Costs    115,272   115,272   255,010   255,010 

 Change in Future Development Costs       311     8,177    37,634    65,250 


 Total Development Costs              115,583   123,449   292,644   320,260 


 Acquisition Costs                        273       273    47,178    47,178 

 Disposition Costs                    (12,873)  (12,873)  (33,838)  (33,838)


 Total Costs                          102,984   110,850   305,984   333,600 


Reserves (mboe)                                                             

 Reserve Additions (1)                  5,882     9,450    16,160    23,268 

 Acquisitions and Dispositions           (291)     (551)    2,452     3,573 


 Total Reserve Additions                5,591     8,899    18,612    26,841 


Finding and Development Costs                                               


 Exploration and Development,                                               

  excluding change in FDC           $   19.60 $   12.20 $   15.78 $   10.96 

 Exploration and Development,                                               

  including change in FDC           $   19.65 $   13.06 $   18.11 $   13.76 

 Exploration, Development,                                                  

  Acquisitions and Dispositions,                                            

  including change in FDC           $   18.42 $   12.46 $   16.44 $   12.43 


Total 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 the total cost of reserve additions in that year.

(1) Includes extensions and improved recovery, technical revisions, and economic factors.

Future Development Costs

Future development costs (inclusive of $132.3 million for development of locations and $10.8 million of non-drilling related capital) in the Company's proved plus probable reserves consists of:


                                                     FDC     Gross       Net


Hythe                                             66,461        28      22.2

Wapiti                                            29,647        18      12.4

Bigstone Cretaceous                               18,274        15       8.6

Bigstone Montney                                  16,860         2       1.7

Other                                             11,852         8       3.2


                                                 143,094        71      48.1


Net Asset Value

The estimated net asset value of the Company at December 31, 2011 has been calculated using before tax, net present value of reserves discounted at ten percent as follows:

($ thousands except per share                                               

 value)                                     2011          2010     % Change 


Estimated future net revenues of                                            

 proved plus probable reserves (1)       414,120       399,454            4 

Undeveloped land (2)                      68,676        27,650          148 

Mark-to-market value of hedging                                             

 contracts                                (2,678)          650         (512)

In-the-money option proceeds (3)           9,973         9,248            8 


Total assets value                       490,091       437,002           12 

Bank debt plus working capital                                              

 deficiency (unaudited) (4)             (104,935)     (108,054)          (3)


Net asset value                          385,156       328,948           17 


Common shares outstanding and in-                                           

 the-money options                   137,734,798   119,632,109           15 

Net asset value per share                   2.80          2.75            2 


(1) Discounted at 10 percent and before deducting future income tax expenses and reclamation costs. The Company estimates it has approximately $300 million of tax deductions available to offset future taxable income.

(2) Undeveloped land was determined by an independent land valuation report by Seaton-Jordan & Associates Ltd. At December 31, 2011 Delphi had an interest in 239,186 net acres of undeveloped land versus 244,475 net acres at the end of 2010.

(3) In-the-money option proceeds are based on the closing December 31, 2011 share price of $2.14.

(4) December 31, 2011 net debt of $95.4 million plus carrying value of net assets held for sale of $9.5 million.

Delphi anticipates releasing its audited financial statements for the year ended December 31, 2011 on March 14, 2012 and its Annual Information Form by March 30, 2012, which will include all required National Instrument 51-101 reserves disclosure.

Delphi Energy is a Calgary-based company that explores, develops and produces oil and natural gas in Western Canada. The Company is managed by a proven technical team. Delphi trades on the Toronto Stock Exchange under the symbol DEE.

Forward-Looking Statements. This management discussion and analysis contains forward-looking statements and forward-looking information within the meaning of applicable securities laws. The use of any of the words "expect", "anticipate", "continue", "estimate", may", "will", "should", believe", "intends", "forecast", "plans", "guidance" and similar expressions are intended to identify forward-looking statements or information.

More particularly and without limitation, this management discussion and analysis contains forward looking statements and information relating to the Company's risk management program, petroleum and natural gas production, future funds from operations, capital programs, commodity prices, costs and debt levels. The forward-looking statements and information are based on certain key expectations and assumptions made by Delphi, including expectations and assumptions relating to prevailing commodity prices and exchange rates, applicable royalty rates and tax laws, future well production rates, the performance of existing wells, the success of drilling new wells, the capital availability to undertake planned activities and the availability and cost of labour and services.

Although the Company believes that the expectations reflected in such forward-looking statements and information are reasonable, it can give no assurance that such expectations will prove to be correct. Since forward-looking statements and information address future events and conditions, by their very nature they involve inherent risks and uncertainties. Actual results may differ materially from those currently anticipated due to a number of factors and risks. These include, but are not limited to, the risks associated with the oil and gas industry in general such as 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 estimates and projections relating to production rates, costs and expenses, commodity price and exchange rate fluctuations, marketing and transportation, environmental risks, competition, the ability to access sufficient capital from internal and external sources and changes in tax, royalty and environmental legislation. Additional information on these and other factors that could affect the Company's operations or financial results are included in reports on file with the applicable securities regulatory authorities and may be accessed through the SEDAR website ( The forward-looking statements and information contained in this press release are made as of the date hereof for the purpose of providing the readers with the Company's expectations for the coming year. The forward-looking statements and information may not be appropriate for other purposes. Delphi undertakes no obligation to update publicly or revise any forward-looking statements or information, whether as a result of new information, future events or otherwise, unless so required by applicable securities laws.

Basis of Presentation. For the purpose of reporting production information, reserves and calculating unit prices and costs, natural gas volumes have been converted to a barrel of oil equivalent (boe) using six thousand cubic feet equal to one barrel. A boe conversion ratio of 6:1 is based upon an energy equivalency conversion method primarily applicable at the burner tip and does not represent a value equivalency at the wellhead. This conversion conforms with the Canadian Securities Administrators' National Instrument 51-101 when boes are disclosed. Boes may be misleading, particularly if used in isolation.

Non-GAAP Measures. The MD&A contains the terms "funds from operations", "funds from operations per share", "net debt", "cash operating costs" and "netbacks" which are not recognized measures under Canadian generally accepted accounting principles. The Company uses these measures to help evaluate its performance. Management considers netbacks an important measure as it demonstrates its profitability relative to current commodity prices. Management uses funds from operations to analyze performance and considers it a key measure as it demonstrates the Company's ability to generate the cash necessary to fund future capital investments and to repay debt. Funds from operations is a non-GAAP measure and has been defined by the Company as net earnings plus the addback of non-cash items (depletion, depreciation and accretion, stock-based compensation, future income taxes and unrealized gain/(loss) on risk management activities) and excludes the change in non-cash working capital related to operating activities and expenditures on asset retirement obligations and reclamation. The Company also presents funds from operations per share whereby amounts per share are calculated using weighted average shares outstanding consistent with the calculation of earnings per share. Delphi's determination of funds from operations may not be comparable to that reported by other companies nor should it be viewed as an alternative to cash flow from operating activities, net earnings or other measures of financial performance calculated in accordance with Canadian GAAP. The Company has defined net debt as the sum of long term debt plus working capital excluding the current portion of future income taxes and risk management asset/liability. Net debt is used by management to monitor remaining availability under its credit facilities. Cash operating costs have been defined as the sum of operating expenses, transportation expenses, general and administrative expenses and interest costs. Operating netbacks have been defined as revenue less royalties, transportation and operating costs. Cash flow netbacks have been defined as operating netbacks less interest and general and administrative costs. Netbacks are generally discussed and presented on a per boe basis.