Legacy Oil + Gas Inc. announces over 20% increase in 2013 year-end reserves and net asset value per share, top quartile recycle ratios and provides operational update

CALGARY, March 5, 2014 /CNW/ - Legacy Oil + Gas Inc. ("Legacy" or the "Company") (TSX: LEG) is pleased to announce its 2013 year-end reserves and provide an operational update.

The financial and operational information contained below is based on the Company's unaudited expected results for the year ended December 31, 2013.

HIGHLIGHTS

  • 2013 net asset value per share grew by 20 percent over 2012 to $11.71 per share
  • 2013 total proved plus probable finding and development costs ("F&D") (including changes in future development costs) decreased 12 percent from 2012 to $20.20 per Boe
  • 2013 total proved plus probable finding, development and acquisition costs ("FD&A") (including changes in future development costs) decreased 3 percent from 2012 to $22.01 per Boe
  • Generated a recycle ratio of 2.5 times (F&D) and 2.3 times (FD&A) based on estimated 2013 average netbacks of $49.86 per Boe
  • Total proved plus probable reserves grew by 24 percent to 117.2 MMBoe (84 percent oil and NGL's) at year end 2013 from 94.2 MMBoe (84 percent oil and NGL's) at year end 2012
  • Total proved reserves grew by 20 percent to 66.7 MMBoe at year end 2013 from 55.4 MMBoe at year end 2012
  • 2013 production averaged 19,013 Boe per day, an increase of 17 percent over 2012 average production of 16,301 Boe per day
  • Proved developed producing reserves comprise 71 percent of the total proved reserves
  • Total proved reserves comprise 57 percent of the total plus probable reserves
  • Replaced 276 percent of production on a total proved plus probable basis organically and 434 percent total including acquisitions
  • Total proved plus probable reserve life index equates to an industry-leading 15.2 years based on fourth quarter 2013 average production
  • Total future development costs represent approximately one year of cash flow for total proved reserves and two years for total proved plus probable reserves

RESERVES

In this press release, all references to reserves are to gross company reserves, meaning Legacy's working interest reserves before deductions of royalties and before consideration of Legacy's royalty interests.  The reserves were evaluated by Sproule Associates Limited ("Sproule") in accordance with National Instrument 51-101 - Standards of Disclosure for Oil and Gas Activities ("NI 51-101") effective December 31, 2013.  Legacy's annual information form for the year ended December 31, 2013 (the "AIF") will contain Legacy's reserves data and other oil and natural gas information as mandated by NI 51-101.  Legacy is required to file the AIF on SEDAR on or before March 31, 2014.

The following tables are a summary of Legacy's petroleum and natural gas reserves as evaluated by Sproule effective December 31, 2013 using forecast prices and costs.  It is important to note that the recovery and reserves estimates provided herein are estimates only.  Actual reserves may be greater or less than the estimates provided herein.  Reserves information may not add due to rounding.

Reserves Summary

                   
      Light and            Total Oil
      Medium Oil   Natural Gas   NGL's   Equivalent
      (MBbl)   (MMcf)   (MBbl)   (MBoe)
Proved Producing      32,431.9   49,080   6,663.0   47,275.0
Proved Developed Non-Producing      652.0   149   26.6   703.4
Proved Undeveloped      11,868.4   24,013   2,860.0   18,730.5
Total Proved      44,952.3   73,242   9,549.7   66,708.9
Probable      38,911.6   37,764   5,243.1   50,448.8
Total Proved plus Probable      83,863.9   111,006   14,792.7   117,157.7




Net Present Value of Future Net Revenue

    Before Future Income Tax Expenses and Discounted at
    0%   5%   10%   15%   20%
         
    (M$)   (M$)   (M$)   (M$)   (M$)
Proved                    
  Developed Producing   1,896,208   1,386,307   1,112,492   942,329   825,620
  Developed Non-Producing   26,698   22,567   19,514   17,184   15,357
  Undeveloped   589,932   383,770   269,767   196,746   145,954
Total Proved   2,512,839   1,792,644   1,401,773   1,156,259   986,930
Probable   2,391,482   1,403,279   953,826   702,682   543,765
Total Proved plus Probable   4,904,320   3,195,923   2,355,598   1,858,941   1,530,695
                     
                     
    After Future Income Tax Expenses and Discounted at
    0%   5%   10%   15%   20%
         
    (M$)   (M$)   (M$)   (M$)   (M$)
Proved                    
  Developed Producing   1,760,284   1,323,441   1,079,401   923,344   814,040
  Developed Non-Producing   19,628   17,684   16,079   14,727   13,572
  Undeveloped   437,402   282,124   196,328   141,205   102,668
Total Proved   2,217,313   1,623,249   1,291,808   1,079,277   930,280
Probable   1,778,073   1,036,521   698,509   509,580   390,201
Total Proved plus Probable   3,995,386   2,659,770   1,990,317   1,588,857   1,320,481




Pricing Assumptions - Forecast Prices and Costs

Sproule employed the following pricing, exchange rate and inflation rate assumptions as of December 31, 2013 in estimating reserves data using forecast prices and costs. For the year ended December 31, 2013, Legacy's average realized sales prices before hedging were $2.91/Mcf for natural gas and $87.40/bbl for crude oil and NGLs.

                         
Year   WTI
Cushing
Oklahoma
40° API
(US$/Bbl)
  Edmonton
Par Price
40° API
($/Bbl)
  Cromer
LSB
35° API
($/Bbl)
  AECO - C Spot
($/MMBtu)
  Pentanes
Plus
($/Bbl)
  Exchange
Rate
($US/$Cdn)
2013
(Actual)
  97.98   93.24   91.59   3.13   104.86   0.971
2014   94.65   92.64   90.64   4.00   103.50   0.940
2015   88.37   89.31   87.31   3.99   99.78   0.940
2016   84.25   89.63   87.63   4.00   100.14   0.940
2017   95.52   101.62   99.62   4.93   113.53   0.940
2018   96.96   103.14   101.14   5.01   115.24   0.940
2019   98.41   104.69   102.69   5.09   116.97   0.940
2020   99.89   106.26   104.26   5.18   118.72   0.940
2021   101.38   107.86   105.86   5.26   120.50   0.940
2022   102.91   109.47   107.47   5.35   122.31   0.940
2023   104.45   111.12   109.12   5.43   124.14   0.940
                         

Thereafter escalation rate of 1.5%

Reconciliation of Changes in Reserves

The following table sets forth a reconciliation of Legacy's gross reserves as at December 31, 2013 to the gross reserves as at December 31, 2012.

      Light and
Medium Crude
Oil
  Natural Gas
Liquids
  Natural Gas   Total Oil
Equivalent
Proved   (MBbls)   (MBbls)   (MMcf)   (MBoe)
  Balance at December 31, 2012   38,678.8   6,700.8   60,165.0   55,407.1
  Extensions and Improved Recovery   3,822.7   576.5   5,053.0   5,241.4
  Technical Revisions   151.7   1,664.2   3,570.0   2,410.8
  Infill Drilling   2,840.2   330.8   3,262.0   3,714.7
  Discoveries   -   -   -   -
  Acquisitions   5,600.6   914.5   6,135.0   7,537.6
  Dispositions   (907.8)   (19.6)   (182.0)   (957.7)
  Economic Factors   256.3   1.6   (158.0)   231.6
  Production   (5,490.2)   (619.1)   (4,603.0)   (6,876.5)
  Balance at December 31, 2013   44,952.3   9,549.7   73,242.0   66,709.0
                   
      Light and
Medium Crude
Oil
  Natural Gas
Liquids
  Natural Gas   Total Oil
Equivalent
Probable   (MBbls)   (MBbls)   (MMcf)   (MBoe)
  Balance at December 31, 2012   30,638.8   3,489.6   27,736.0   38,751.2
  Extensions and Improved Recovery   3,346.2   473.3   4,123.0   4,506.7
  Technical Revisions   (675.4)   676.0   1,441.0   240.9
  Infill Drilling   2,099.0   143.1   1,331.0   2,463.9
  Discoveries   -   -   -   -
  Acquisitions   3,938.7   462.1   3,073.0   4,913.0
  Dispositions   (570.3)   (12.5)   (116.0)   (602.1)
  Economic Factors   134.5   11.4   176.0   175.2
  Production   -   -   -   -
  Balance at December 31, 2013   38,911.6   5,243.0   37,764.0   50,448.7
                   
      Light and
Medium Crude
Oil
  Natural Gas
Liquids
  Natural Gas   Total Oil
Equivalent
Proved + Probable   (MBbls)   (MBbls)   (MMcf)   (MBoe)
  Balance at December 31, 2012   69,317.7   10,190.4   87,901.0   94,158.3
  Extensions and Improved Recovery   7,168.9   1,049.8   9,176.0   9,748.1
  Technical Revisions   (523.7)   2,340.2   5,011.0   2,651.7
  Infill Drilling   4,939.2   473.8   4,593.0   6,178.6
  Discoveries   -   -   -   -
  Acquisitions   9,539.3   1,376.6   9,208.0   12,450.6
  Dispositions   (1,478.1)   (32.1)   (298.0)   (1,559.9)
  Economic Factors   390.8   13.0   18.0   406.8
  Production   (5,490.2)   (619.1)   (4,603.0)   (6,876.5)
  Balance at December 31, 2013   83,863.9   14,792.7   111,006.0   117,157.6

Future Development Costs

The table below sets out the total future development costs ("FDC") deducted in the estimation by Sproule of the future net revenue attributable to proved reserves and proved plus probable reserves.

    Proved Reserves   Proved Plus
Probable Reserves
     
    (M$)   (M$)
2014   178,068   288,920
2015   139,920   286,848
2016   25,656   118,725
2017   5,254   56,157
2018   -   -
Remaining Years   -   -
Total Undiscounted   348,898   750,649

CAPITAL EXPENDITURES AND FINDING, DEVELOPMENT AND ACQUISITION COSTS

Legacy incurred capital expenditures of $508.3 million in 2013, of which $187.1 million was related to strategic net asset acquisitions and divestitures and $321.2 million on organic opportunities, including $4.7 million of capitalized general and administrative costs.

The Company's total proved plus probable finding, development and acquisition costs for 2013 were $22.01 per Boe (including change in FDC), which generated a 2.3 times recycle ratio based on Legacy's 2013 estimated average operating netback of $49.86 per Boe.

         
2013 Capital Expenditures                                     Total Proved plus Probable (1)   Total Proved (1)
Capital costs ($ thousands)        
  Exploration & development drilling & associated costs   307,129   307,129
  Land & seismic   13,639   13,639
  Net acquisitions and divestitures   187,086   187,086
  Change in FDC    149,752   83,828
2013 Reserve Additions (MBoe) (2)        
Exploration & development   18,986   11,599
Net acquisitions   10,891   6,580
         
Finding & Development Costs ($ per Boe) (3)        
           
2013 excluding change in FDC   16.90   27.66
2013 including change in FDC   20.20   30.77
         
2012 excluding change in FDC   26.22   35.82
2012 including change in FDC   23.05   28.79
         
3-year weighted average cost, excluding change in FDC   21.97   34.47
3-year weighted average cost, including change in FDC   25.88   36.40
         
Finding, Development & Acquisition Costs ($ per Boe) (4)        
         
2013 excluding change in FDC   17.00   27.94
2013 including change in FDC   22.01   32.55
         
2012 excluding change in FDC   25.85   35.07
2012 including change in FDC   22.72   28.17
         
3-year weighted average cost, excluding change in FDC   24.18   38.04
3-year weighted average cost, including change in FDC   28.76   40.86
         

(1)      The aggregate of the exploration and development costs incurred in the most recent financial period and the change during that period in estimated future development costs generally will not reflect total finding and development costs related to reserve additions for that period.
(2)      Boes may be misleading, particularly if used in isolation.  A Boe conversion ratio of 1 Boe: 6 Mcf natural gas has been used, which is based on an energy equivalency conversion method primarily applicable at the burner tip and does not necessarily represent a value equivalency at the wellhead.
(3)     Includes revisions. Determined by dividing the sum of exploration, development, land & seismic costs and, where indicated, changes to FDC by additions to reserves, other than additions through net acquisitions. Changes to FDC for the purposes of this calculation do not include $87.0 million on a total proved plus probable basis and $47.7 million on a total proved basis of changes in FDC attributable to reserve additions through net acquisitions.
(4)      Includes revisions. Determined by dividing the sum of exploration, development, land, seismic and acquisition costs and, where indicated, changes to FDC, by additions to reserves, including additions through net acquisitions. This supplemental measure has been included as Legacy believes it provides important information respecting the cost effectiveness of net acquisitions.

Net asset value ("NAV") per share

The following table outlines Legacy's NAV per basic common share (unaudited) using the Proved plus Probable reserve value at December 31, 2013, before tax and discounted at 10%, and forecast pricing and costs:

Proved Plus Probable Reserve Value NPV10 BT (incl. future capital) (MM$)     $2,355.6
Undeveloped Land (388,806 acres) (1) (unaudited) (MM$)     $137.9
Investment in LGX (unaudited) (MM$)     $14.0
Estimated Net Debt (unaudited) (MM$)     ($667.4)
Total Net Assets (basic)     $1,840.1
Basic Common Shares Outstanding (MM)     157.2
Estimated NAV per Basic Common Share     $11.71

(1) Represents carrying value of the Company's exploration and evaluation assets

Operational Update

The Company drilled 22 (17.8 net) wells in the fourth quarter of 2013, all targeting light oil, with a 100 percent success rate.  This total included 9 (8.5 net) Midale horizontal wells.  In the fourth quarter of 2013, Legacy significantly underspent its funds flow from operations for the quarter while commencing a number of key infrastructure projects that are forecast to be completed in the first quarter of 2014.

Legacy drilled 139 (114.2 net) wells in 2013, with a 99 percent success rate, The Company met its 2013 production guidance, averaging 19,013 Boe per day, an increase of 17 percent over 2012 average production of 16,301 Boe per day.  Total capital expenditures on organic opportunities for 2013 were $316.4 million (not including capitalized G&A, corporate fixed assets or net acquisitions and divestitures).

MIDALE PLAY

Legacy drilled 9 (8.5 net) Midale wells in the fourth quarter including a number of step-out and delineation wells over a wide area.  The wells have an average 30 day initial rate of 210 Boe per day per well.  The Company has proven up a substantial inventory of Midale locations. Based on recent pricing, Legacy expects payouts of less than 8 months and internal rates of return in excess of 100% on these wells.

SPEARFISH PLAY

The Company drilled 3 (2.2 net) wells in the fourth quarter of 2013.  A modified frac fluid was used on two wells in Pierson with encouraging results.  The wells have average 30 day initial rates of 160 Boe per day per well and average water cuts of 25 percent, both significant improvements over historical results.

BAKKEN PLAY

The Company drilled 3 (2.0 net) wells in Star Valley in the fourth quarter of 2013.  The wells have an average 30 day initial rate of 210 Boe per day per well.

TURNER VALLEY

Horizontal wells drilled in late 2012 and throughout 2013 continue to outperform.  Average cumulative production from these wells after six months is 122 percent higher than the wells drilled by the previous operator, improving the area internal rates of return, payouts and net present values.

SUMMARY

Operational momentum continued through 2013 with Legacy achieving cost effective per share growth in reserves, production and cash flow. Legacy met or exceeded its 2013 performance objectives while spending essentially within budget and demonstrating strong results:

F&D Costs $20.20 per Boe
P+P Recycle Ratio (F&D)(1)  2.5 X
FD&A Costs $22.01 per Boe
P+P Recycle Ratio (FD&A)(1)  2.3 X
NAV per share  $11.71 per share 
   
NAV per share growth (2012-2013) 20%
P+P Reserves per share growth (2012-2013) 14%

(1) Based on Legacy's 2013 estimated average operating netback of $49.86 per Boe. 

As a light oil weighted (89 percent oil and NGL's) company, Legacy's 2013 performance positions the Company for continued solid production growth with good capital efficiencies from its extensive inventory of 2,000 net light oil development locations and waterflood assets.

Conference call details

Legacy expects to release its 2013 year end operational and financial results Tuesday, March 25, 2014. Management will be holding a conference call for investors, financial analysts, media and any interested persons on Wednesday, March 26, 2014 at 9:00 a.m. (MDT) (11:00 a.m. EDT) to discuss the 2013 year end results.

The investor conference call details are as follows:

Participant Dial-In Number(s):

  • Operator Assisted Toll-Free Dial-In Number:  (888) 231-8191
  • Local Dial-In Number:  (403) 451-9838
  • Conference ID:  7724676

Note:  In order to join this conference call, you will be required to provide the Conference ID Number listed above.

Reserves Data

The determination of oil and natural gas reserves involves the preparation of estimates that have an inherent degree of associated uncertainty. Categories of proved and probable reserves have been established to reflect the level of these uncertainties and to provide an indication of the probability of recovery.  The estimation and classification of reserves requires the application of professional judgment combined with geological and engineering knowledge to assess whether or not specific reserves classification criteria have been satisfied. Knowledge of concepts including uncertainty and risk, probability and statistics, and deterministic and probabilistic estimation methods is required to properly use and apply reserves definitions.

The recovery and reserve estimates of oil, NGL and natural gas reserves provided herein are estimates only.  Actual reserves may be greater than or less than the estimates provided herein. The estimated future net revenue from the production of Legacy's natural gas and petroleum reserves does not represent the fair market value of Legacy's reserves.

The reserve data provided in this news release presents only a portion of the disclosure required under NI 51-101.  All of the required information will be contained in Legacy's AIF, which will be filed on SEDAR on or before March 31, 2014.

Caution Respecting BOE

In this press release, the abbreviation BOE means barrel of oil equivalent on the basis of 1 BOE to 6 Mcf of natural gas when converting natural gas to BOEs.  BOEs may be misleading, particularly if used in isolation.  A BOE conversion ratio of 6 Mcf to 1 BOE is based on an energy equivalency conversion method primarily applicable at the burner tip and does not represent a value equivalency at the wellhead.  Given that the value ratio of oil compared to natural gas based on currently prevailing prices is significantly different than the energy equivalency conversion ratio of 6 Mcf to 1 BOE, utilizing a conversion ratio of 6 Mcf to 1 BOE may be misleading as an indication of value.

Calculation of Netbacks

Netbacks are calculated by deducting royalties paid and operating costs, including transportation costs, from prices received, excluding the effects of hedging.

Forward Looking Statements

This press release contains forward-looking statements. More particularly, this press release contains statements concerning the expected average internal rates of return and average payout times for Midale wells and Legacy's total potential number of drilling locations. 

The forward-looking statements contained in this press release are based on certain key expectations and assumptions made by Legacy, including expectations and assumptions concerning the success of future drilling and development activities, the performance of existing wells, the performance of new wells, the viability of waterflood projects, the availability and cost of services and prevailing commodity prices, weather conditions and economic conditions.

Although Legacy believes that the expectations and assumptions on which the forward-looking statements are based are reasonable, undue reliance should not be placed on the forward-looking statements because Legacy can give no assurance that they will prove to be correct.  Since forward-looking statements address future events and conditions, by their very nature they involve inherent risks and uncertainties.  Actual results could differ materially from those currently anticipated due to a number of factors and risks.  These include, but are not limited to, risks associated with the oil and gas industry in general (e.g., operational risks in development, exploration and production; the uncertainty of reserve estimates; the uncertainty of estimates and projections relating to production, costs and expenses, and health, safety and environmental risks), constraint in the availability of services, commodity price and exchange rate fluctuations, adverse weather conditions and uncertainties resulting from potential delays or changes in plans with respect to exploration or development projects, waterflood projects or capital expenditures. Certain of these risks are set out in more detail herein  and in Legacy's annual information form for the year ended December 31, 2012 which has been filed on SEDAR and can be accessed at www.sedar.com

The forward-looking statements contained in this press release are made as of the date hereof and Legacy 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.

 

 

SOURCE Legacy Oil + Gas Inc.

For further information:

Trent J. Yanko, P.Eng.
President + CEO

Legacy Oil + Gas Inc.
4400 Eighth Avenue Place
525 - 8th Avenue SW
Calgary, AB T2P 1G1

Telephone: 403.441.2300
Fax: 403.441.2017

 
Matt Janisch, P.Eng.
Vice-President, Finance + CFO

Legacy Oil + Gas Inc.
4400 Eighth Avenue Place
525 - 8th Avenue SW
Calgary, AB T2P 1G1

Telephone: 403.441.2300
Fax: 403.441.2017