Raging River Exploration Inc. Announces 215% Increase in 2012 Year End Reserves and an Operational Update

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CALGARY, ALBERTA--(Marketwire - Jan 28, 2013) - Raging River Exploration Inc. ("Raging River" or the "Company") (TSX VENTURE:RRX) is pleased to announce its 2012 year-end oil and gas reserves evaluation. The material increase in reserves reflects exceptional organic reserves growth in addition to several accretive acquisitions completed throughout 2012.

Reserve Report Highlights:

  • Increased proven plus probable reserves by 215% to 17.2 mmboe (95% oil) and proven reserves by 201% to 11.5 mmboe (95% oil). Proven reserves represent 67% of proven plus probable reserves as at December 31, 2012.
  • Increased net asset value per share calculated on a present value before tax of 10% ("PVBT10") to an estimated $2.75 per share at December 31, 2012.
  • Maintained an enviable reserves life index of 12 years based on our December 2012 exit production rate of 4,000 boepd.
  • Finding, development and acquisition ("FD&A") costs including a $167 million change in future development capital are $26.05 per boe on a proven plus probable basis.
  • Finding, development and acquisition costs including a $130 million change in future development capital are $33.81 per boe on a total proven basis.
  • Generated an FD&A recycle ratio of 2.0 times based on our estimated 2012 operating netback of $53.00 per boe.
  • Reserve additions replaced 2012 production by greater than 12 times on a proven basis and 17 times on a proven plus probable basis.
  • Increased proven plus probable reserves per fully diluted share by 105% to 97 boe per 1,000 shares from 44 boe per 1,000 shares
  • Raging River''s development drilling inventory has increased to in excess of 1,300 risked locations as at January 1, 2013 of which in excess of 1,000 are currently unbooked.

The following tables summarize certain information contained in the independent reserves report prepared by Sproule Associates Ltd. ("Sproule") as of December 31, 2012. The report was prepared in accordance with definition, standards and procedures contained in the Canadian Oil and Gas Evaluation Handbook ("COGE Handbook") and National Instrument 51-101 Standards of Disclosure for Oil and Gas Activities ("NI 51-101"). Additional reserve information as required under NI 51-101 will be included in the Company''s Annual Information Form which will be filed on SEDAR by April 30, 2013. 

December 31, 2012        
Reserves Category
Gross Working Interest
Oil
Mbbl
Gas
MMcf
Oil
Equivalent
mBOE
PVBT
10%
$M
Future
Development
Capital
$M
Net
Undeveloped
Wells
Booked
Proven Developed Producing 4,241 1,395 4,474 152,711 - -
Proven Undeveloped 6,774 1,782 7,071 127,242 185,233 201
Total Proven 11,014 3,177 11,544 279,952 185,233 201
Proven Plus Probable Developed Producing 5,922 2,018 6,258 202,684 - -
Proven Plus Probable Undeveloped 10,405 3,006 10,906 220,253 226,454 246
Total Proven Plus Probable 16,327 5,024 17,164 422,936 226,454 246

Notes:

  1. Gross Company reserves are the Company''s total working interest share before the deduction of any royalties and without including any royalty interests owned by the Company.
  2. Based on Sproule''s December 31, 2012 escalated price forecast.
  3. It should not be assumed that the present worth of estimated future cash flow presented in the tables above represents the fair market value of the reserves. There is no assurance that the forecast prices and costs assumptions will be attained and variances could be material. The recovery and reserve estimates of Raging River''s crude oil, natural gas liquids and natural gas reserves provided herein are estimates only and there is no guarantee that the estimated reserves will be recovered. Actual crude oil, natural gas and natural gas liquids reserves may be greater than or less than the estimates provided herein.
  4. All future net revenues are stated prior to provision for interest, general and administrative expenses and after deduction of royalties, operating costs and estimated future capital expenditures. Future net revenues have been presented on a before tax basis. Estimated values of future net revenue disclosed herein do not represent fair market value.
  5. FD&A costs have been presented because acquisitions and dispositions can have a significant impact on the Company''s ongoing reserve replacement costs. The presented FD&A are calculated using all capital expenditures and reserve additions as defined in NI 51-101. The calculation includes all development and acquisition capital and all future development capital associated with the acquisitions and with future development of the existing assets.
  6. Figures are subject to audit.
  7. The capital expenditures include the announced purchase price of corporate acquisitions rather than the amounts allocated to property, plant and equipment for accounting purposes. The capital expenditures also exclude capitalized administration costs and transaction costs.
  8. The numbers presented below in regards to additions/revisions represent a comparison to the opening reserves balance which were the reserves acquired from Wild Stream Exploration Inc. by RRX on March 16, 2012. RRX AIF filings in April will show all reserves in 2012 as being acquired by RRX as RRX commenced business on March 16, 2012 with an acquisition of reserves from Wild Stream Exploration.
2012 FD&A Costs  
2012 Capital Expenditures ($000s) Total Proven   Proven Plus Probable
Development 55,000   55,000
Net Acquisitions 101,000   101,000
Change in FDC 129,698   166,435
Total Capital 285,698   322,435
2012 Reserve Additions Mboe      
Acquisitions 2,496   3,980
Additions/Revisions 5,955   8,400
Total 8,451   12,380
2012 FD&A ($/boe) 33.81   26.05

Operations Update

The Company has not released its audited 2012 results and accordingly the numbers included below are currently estimates and are unaudited.

  • Based on field estimates, fourth quarter 2012 average production increased 46% from the third quarter average to 3,100 boepd (96% oil) which is 10% ahead of previous guidance of 2,800 boepd.
  • Based on field estimates, exit production for the period of December 15 to 31 was greater than 4,000 boepd which exceeded our previous exit guidance of 3,700 boepd by 8%.

Raging River is in the midst of a very active first quarter in which we anticipate drilling 30-32 net wells. We currently have three drilling rigs operating and have drilled 20 gross (17.5 net) wells at 100% success in January. Thirteen of these wells have been completed and placed on production. Despite winter operations which typically marginally increase costs, the average on-stream costs in January have been approximately $910 thousand, equivalent to summer 2012 costs.

The Kindersley area is prone to early break-up and operations typically shut down on or before March 15th. We plan to have all first quarter operations completed by March 6th and we are on schedule to complete this. The winter has seen significant snowfall to date increasing the probability of a pro-longed break-up. We have accounted for this in 2013 planning and have factored in no drilling activity between March 7th and June 1, 2013.

2013 production to date is exceeding expectations and we are confident we will meet or exceed our average first quarter estimates of 4,300 boepd (95% oil).

Raging River''s experienced management team remains committed to operational and executional excellence to continue delivering per share value growth to our shareholders while maintaining balance sheet strength.