NOVATEK ranks amongst the top ten companies globally in terms of proven natural gas reserves and is the second largest holder of natural gas reserves in Russia under the Petroleum Resource Management System (PRMS)1 reserve reporting methodology.
Our proved reserves estimates are appraised by the Group’s independent petroleum engineers, DeGolyer and MacNaughton (D&M). The Group’s total proved reserves, comprised of proved developed and proved undeveloped reserves as of 31 December 2009 and 2008, were appraised using both reporting and disclosure requirements promulgated by the US SEC2 and the recently issued PRMS reserves reporting classification. Proved reserves disclosed in NOVATEK’s Unaudited Supplemental Oil and Gas Disclosures in its IFRS consolidated financial statements are presented under the SEC reserve reporting methodology.
Since inception, NOVATEK has consistently grown its reserve base through prudent capital investments and successful exploratory activities. According to D&M’s comprehensive appraisal of the Company’s oil and gas reserves as of 31 December 2009, the Company added approximately 2,127 million barrels of oil equivalent (boe) of proved reserves under SECreserves reporting methodology (SEC standards), inclusive of 2009 production, and produced approximately 237 million boe3 during the year.
Estimated total proved reserves (according to SEC standards) as of 31 December 2009 increased to 6,853 million boe from 4,963 million boe as of year-end 2008. Total proved reserves of natural gas increased from 690 billion cubic meters (bcm) in 2008 to 967 bcm in 2009, an increase of 310 bcm, inclusive of the Company’s 2009 production. The growth in proved reserves was mainly attributable to organic reserves growth through development drilling and the finding of new layers at the Yurkharovskoye field as well as the positive impact of the South Tambeyskoye field acquisition on the Company’s total reserves base.
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In 2009, on a barrel of oil equivalent basis, NOVATEK recorded an approximately nine-fold (898%) reserves replacement rate4 for its appraised fields under the SEC standards, and at year-end 2009, the Company’s reserve to production ratio (or R/P ratio) was 29 years. The Company also recorded a greater than nine-fold (958%) reserves replacement rate for natural gas while increasing the R/P ratio to approximately 30 years.
As part of management’s continued efforts to improve investor confidence and provide transparency regarding the Group’s oil and gas reserves, we have provided additional information about our hydrocarbon reserves based on the widely-industry accepted PRMS reserves reporting classification, which in addition to total proved reserves discloses information on the Company’s probable and possible reserves. Under the PRMS reserves reporting methodology, the Company’s total proved reserves increased by 2,594 million boe, inclusive of 2009 production, and totaled 7,711 million boe, while proved plus probable reserves totaled 10,589 million boe as of 31 December 2009.
The tables below provide a comparison of NOVATEK’s estimated reserves under SEC and PRMS classifications based on its equity ownership interest in the respective fields.
Natural gas reserves, bcm
|
|
2009
|
2008
|
2007
|
2006
|
2005
|
|
Proved
|
SEC
|
967
|
690
|
653
|
651
|
641
|
|
PRMS
|
1,080
|
734
|
704
|
-
|
-
|
|
Proved plus Probable
|
1,462
|
1,017
|
1,029
|
-
|
-
|
|
SPE
|
-
|
-
|
-
|
1,015
|
1,006
|
Liquids reserves, mmt
|
|
2009
|
2008
|
2007
|
2006
|
2005
|
|
Proved
|
SEC
|
63
|
55
|
49
|
50
|
46
|
|
PRMS
|
79
|
67
|
61
|
-
|
-
|
|
Proved plus Probable
|
124
|
104
|
102
|
-
|
-
|
|
SPE
|
-
|
-
|
-
|
100
|
95
|
Total reserves, mm boe
|
|
2009
|
2008
|
2007
|
2006
|
2005
|
|
Proved
|
SEC
|
6,853
|
4,963
|
4,678
|
4,664
|
4,573
|
|
PRMS
|
7,711
|
5,354
|
5,100
|
-
|
-
|
|
Proved plus Probable
|
10,589
|
7,498
|
7,562
|
-
|
-
|
|
SPE
|
-
|
-
|
-
|
7,445
|
7,358
|
1 The appraisal reports were conducted under the PRMS reserves reporting methodology, which was approved in March 2007 by the Society of Petroleum Engineers, the World Petroleum Council, the American Association of Petroleum Geologist, and the Society of Petroleum Evaluation Engineers. The Company’s 2009 reserves are based on appraisal reports for the East-Tarkosalinskoye, Khancheyskoye, North Khancheyskoye, Yurkharovskoye, West Yurkharovskoye, South Tambeyskoye, Yarudeyskoye and Termokarstovoye fields, as well as the Olimpiysky and West Urengoiskiy license areas.
2 The Company’s 2009 net proved reserves are based on appraisal reports for the East-Tarkosalinskoye, Khancheyskoye, North Khancheyskoye, Yurkharovskoye, West Yurkharovskoye, South Tambeyskoye, Yarudeyskoye and Termokarstovoye fields, as well as the Olimpiysky license area. The appraisal reports were conducted under the reserves estimation, reporting and disclosures rules promulgated by the U.S. Securities and Exchange (“SEC”) reserves reporting methodology provided that due to a lack of clear and definitive SEC guidance, D&M has relied on management representations that we intend to (i) extend the term of our licenses to the end of the economic lives of the fields, where applicable, and (ii) proceed accordingly with the development and operation of the fields, in order to include certain volumes of reserves estimated to be producible beyond the primary terms of the licenses. The appraisal reports under the SEC reserves standards do not include estimates for probable and possible reserves.
On 31 December 2008, the SEC issued its final rule, Modernization of Oil and Gas Reporting (the “Final Rule”), which revises the disclosures required by oil and gas companies and certain definitions used in those disclosures. The Final Rule also changes the requirement for determining quantities of oil and gas reserves and certain accounting requirements under the Full Cost Method of accounting for oil and gas activities. NOVATEK uses the Successful Method for accounting for oil and gas activities in its consolidated IFRS financial statements.
On 6 January 2010, the FASB issued Accounting Standards Update 2010-03 – Extractive Activities – Oil and Gas (Topic 932), Oil and Gas Reserve Estimation and Disclosure, which substantially aligns the reserve estimation, disclosure requirements, and definitions of Topic 932 with the disclosure requirements of the Final Rule issued by the SEC.
3 Marketable (or sales) production for appraised fields totaled 237 million boe. Total gross production, including fields not appraised by D&M, totaled approximately 240 million boe.
4 The reserves replacement rate is calculated by taking the difference between the opening balance of reserves and the ending balance of reserves plus production for the period and dividing it by production for the period.
Conversion factors:
1,000 cubic meters equals 6.54 barrels of oil equivalent. Liquids have been converted from tons to barrels using D&M’s estimates from the reserve appraisal reports for the years ended 31 December 2005 through 2009.
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