Natural Gas Production in Russia - Research Study

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Release: August 2008
Volume: 366 pages, more than 270 charts and graphs
Price: 9500 euro
Languages: English, Russian

Natural Gas Production in Russia, the second study within RPI's Eurasian Gas Research Service 2008, gives a comprehensive and detailed analysis of the current status and development outlook for Russia's gas industry up to 2020.

Key issues Natural Gas Production in Russia addresses are:

• Evaluation of Russia's production potential to 2020
• Analysis of strategies of Russian gas producing companies
• Assessment of gas production capital expenditures needed to meet the growing gas demand locally and on global markets
• Analysis of the supply/demand scenarios

Key questions addressed in the study:

• What was the dynamics of natural gas production in Russia for the period of 2000-2007?
• What is the legal and tax regulation of the Russian gas industry's upstream segment?
• What is the production potential of Gazprom and independent gas producers at traditional gas fields up to 2020?
• What is Gazprom's strategy with regard to independent producers?
• What are the opportunities for Russian gas producing companies to sustain and increase current production rates?
• What capital expenditures are needed for further development of natural gas upstream segment?
• What is the calculated price of natural gas coming from different fields at the Russian border and how could it change?
• What are the key factors expected to influence natural gas production in Russia?

Natural Gas Production in Russia examines the current status and prospects for gas production by Gazprom's 17 subsidiaries, affiliated companies and 6 independent gas producers.

The study is unique in providing a cost-plus assessment of supplies from a field to the Russian border for major Russian gas assets forecasted to 2020. Combined with the netbacks for 42 importing countries to the Russian border to 2020 forecasted in the study Russian Gas on Global Markets: Potential, Strategies and Outlook (released by RPI in March 2008) it completes the picture of Russia's gas supplies competitive ability on global markets.

Key data in each producing company profile covers:

• Current reserves base
• Historical production
• Transportation routes for gas produced
• Production potential to 2020
• Capital expenditures for further development
• Cost plus assessment from field to current and/or potential exit points at Russian border (for major assets only)

Similarly structured is the examination of new gas fields and provinces:

• Yamal Peninsula: Bovanenkovskoye and Kharasaveiskoye fields
• Shtokmanovskoye field
• Ob-Taz Bay fields
• Eastern Siberia fields
• Russian Far East fields (including Sakhalin)

Cost plus assessments for some of these regions appear in published research for the first time.

Natural Gas Production in Russia develops two scenarios for gas production in Russia in 2008-2020 based on:

• Demand for natural gas in Europe, CIS, North-East Asia, North America
• Gazprom's contracted and supplied export volumes, current and projected
• Projected gas prices on export markets
• Economic feasibility of developing new fields
• Transportation capability for delivering gas from field to local and international consumers
• Gas producers' plans for tapping new fields

The scenarios also take into account forecasts of gas production capital expenditures by Gazprom and other producing companies.

Natural Gas Production in Russia is an essential analytical support tool for:

• energy policy-makers
• integrated energy companies
• gas producers
• gas transportation and trading companies
• financial and investment institutions
• contractors and equipment suppliers

Contents

• Author
• Chapter 1. Current State of Gas Production in Russia
• 1.1. Brief history of gas production in Russia before 1992
• 1.2. Formation of new gas production structure in Russia (1992-2007)
• 1.3. Modern structure of gas production in Russia. Classification of Russian gas
• companies in 2008
• 1.4. Russia's modern resource base
• 1.5. Distribution of the reserves among subsoil users
• Chapter 2. Current Natural Gas Production Policy of the State
• 2.1. Gas production in Russia's Energy Strategy until 2020
• 2.2. Subsoil-use laws in Russia
• 2.2.1. Subsoil Law
• 2.2.2. Gas Supply Law
• 2.2.3. Mineral Extraction Tax (MET)
• Chapter 3. Current and Prospective Production in Gazprom's Existing Fields
• 3.1. Gazprom's production in the Nadym-Pur-Taz Region
• 3.1.1. Urengoygazprom (Gazprom Dobycha Urengoy)
• 3.1.2. Nadymgazprom (Gazprom Dobycha Nadym)
• 3.1.3.Yamburggazdobycha (Gazprom Dobycha Yamburg)
• 3.1.4. Noyabrskgazdobycha (Gazprom Dobycha Noyabrsk)
• 3.1.5. Purgazdobycha
• 3.1.6. Severneftegazprom
• 3.1.7. Achimgaz
• 3.1.8. Purgaz
• 3.1.9. Northgas
• 3.2. Producing enterprises of OAO Gazprom outside the Nadym-Pur-Taz Region
• 3.2.1. Astrakhangazprom (Gazprom Dobycha Astrakhan)
• 3.2.2. Orenburggazprom (Gazprom Dobycha Orenburg)
• 3.2.3. Stimul
• 3.2.4. Severgazprom (Gazprom Dobycha Ukhta/ Gazprom Pererabotka)
• 3.2.5. Tomskgazprom (Vostokgazprom)
• 3.2.6. Sevmorneftegaz
• 3.3. Analysis of gas production potential in the current gas production regions
• of Gazprom until 2020
• 3.3.1. Production from the existing fields of the Nadym-Pur-Taz Region
• 3.3.2 Gas production from the existing fields outside the Nadym-Pur-Taz Region
• 3.3.3. Consolidated forecast of gas production from the existing fields controlled by Gazprom (NPTR and non-NPTR). Scenario 1
• 3.3.4. Scenario of inclusion of Enineftegaz and Sibneftegaz in Gazprom's portfolio Scenario 2
• 3.4. Gas production potential in the current gas production regions of Gazprom
• Chapter 4. Independent Gas Producers
• 4.1. Itera
• 4.2. NOVATEK
• 4.3. Gas production by oil companies
• 4.3.1. LUKOIL
• 4.3.2. Rosneft
• 4.3.3. TNK-
• 4.3.4. Surgutneftegas
• 4.3.5. Other producers
• 4.4. Production potential of independent producers
• Chapter 5. Promising Regions in Terms for Long-Term Gas Production Development Until 2020
• 5.1. Rationale for production in new areas
• 5.2. Yamal Peninsula: development prospects
• 5.3. Development of the Shtokmanovskoye field
• 5.4. Development of the Ob and Taz Bay fields
• 5.5. Eastern Siberia and Russian Far East
• Chapter 6. Factors Influencing Gas Production Growth in Russia
• 6.1. Demand factor
• 6.2. Import factor
• 6.3. Gas transportation system development
• Chapter 7. Russian Gas Production Growth Scenarios Out to 2020
• 7.1. Russian company production capacity and investment requirements
• 7.2. The Base Scenario (Blue Scenario)
• 7.3. Moderate Scenario (White Scenario)
• 7.4. Alternative scenarios
• Conclusions

Map

• Map 1.1. Main oil-and-gas provinces of Russia and Federal Districts
• Map 3.1. System for the transportation of gas produced by Gazprom Dobycha Urengoy
• Map 3.2. Fields licenses for which are held by Nadymgazprom and the adjacent gas transportation infrastructure
• Map 3.3. Fields licenses for which are held by Yamburggazdobycha and the adjacent gas transportation infrastructure
• Map 3.4. Fields with licenses held by Noyabrskgazdobycha and the adjacent gas transportation infrastructure
• Map 3.5. Gas transportation infrastructure for gas supplies from the South-Russkoye field
• Map 3.6. Nord Stream pipeline route
• Map 3.7. Astrakhanskoye field and gas transportation directions
• Map 3.8. Transportation routes for gas produced by Orenburggazprom
• Map 3.9. System for the transportation of gas from the fields of Tomskgazprom
• Map 3.10. Gas fields of Enineftegaz and Sibneftegaz
• Map 4.1. Fields of NOVATEK
• Map 4.2. System of gas transportation from NOVATEK's fields
• Map 4.3. NOVATEK's gas supplies to principal industrial regions
• Map 4.4. LUKOIL's gas reserves
• Map 4.5. LUKOIL's fields in Western Siberia
• Map 4.6. LUKOIL's Caspian fields
• Map 4.7. Model of gas and condensate transportation from the Bolshekhetskaya depression fields
• Map 4.8. Rosneft's fields in Russia
• Map 4.9. Kharampurskoye field with possible gas transportation directions
• Map 4.10. TNK-'s fields in Russia
• Map 4.11. Surgutneftegas's fields in Western Siberia
• Map 5.1. Gas fields of the Yamal Peninsula
• Map 5.2. Obskaya-Bovanenkovo railroad under construction
• Map 5.3. Principal and supplementary gas transportation routes from Yamal fields
• Map 5.4. Vidyaevo and Teriberka sites
• Map 5.5. Model for the pipeline transportation of gas from the Shtokmanovskoye field
• Map 5.6. Ob and Taz Bay fields
• Map 5.7. Transportation of gas from the Ob and Taz Bay fields
• Map 5.8. Kovyktinskoye gas and condensate field
• Map 5.9. Chayandinskoye field
• Map 5.10. Yurubcheno-Takhomskoye field
• Map 5.11. Sobinsk and Paiginskaya group of fields
• Map 5.12. Sakhalin-1 Project
• Map 5.13. Infrastructure of the Sakhalin-2 project
• Map 6.1. Trans-Caspian gas pipeline project
• Map 6.2. Central Asia-Center gas pipeline
• Map 6.3. South Stream pipeline
• Map 6.4. Plans to develop Eastern Siberia and Far East transportation routes

Charts

• Chart 1.1. Distribution of natural gas reserves in the USSR in the early fifties
• Chart 1.2. Gas production in the USSR from 1970 to 1990 (bcm)
• Chart 1.3. Production and reserves growth in Russia from 1991 to 2001 (bcm)
• Chart 1.4. Sales growth in the European market from 2001 to 2007 (USD billion)
• Chart 1.5. Dynamics of Gazprom's market capitalization (USD billion)
• Chart 1.6. Russian gas market in 2008
• Chart 1.7. Gas production in Russia from 2002 to 2007 (bcm)
• Chart 1.8. Structure of natural and associated gas production in Russia 1999-2007
• Chart 1.9. Distribution of proved gas reserves in the world as of 01.01.2007
• Chart 1.10. State of gas reserves development in Russia
• Chart 1.11. Distribution of proved gas reserves throughout North-Western Federal District
• Chart 1.12. Distribution of proved gas reserves throughout Southern Federal District
• Chart 1.13. Distribution of proved gas reserves throughout Volga Region Federal District
• Chart 1.14. Distribution of proved gas reserves throughout the Ural Federal District
• Chart 1.15. Distribution of proved gas reserves throughout Siberian Federal District
• Chart 1.16. Distribution of proved gas reserves throughout the Far Eastern Federal District
• Chart 1.17. Distribution of proved gas reserves throughout the Sea Shelf Plates
• Chart 1.18. Distribution of proved gas reserves of Russia
• Chart 1.19. Dynamics of Gazprom's natural gas reserves in 2002-2007 (tcm)
• Chart 1.20. International audit of selected Gazprom's gas reserves in comparison with the Russian classification system (tcm)
• Chart 1.21. Distribution of Gazprom's gas reserves throughout Federal Districts of Russia in 2007
• Chart 1.22. Gazprom's largest gas fields (1 category) as of 31.12.2007 (tcm)
• Chart 1.23. The number of licenses for exploration and development of hydrocarbones (units)
• Chart 1.24. Results and forecast of Gazprom's reserve increment based on the assets and as a result of exploration work in 2007-2010
• Chart 1.25. Development of proved reserves of independent gas companies (tcm)
• Chart 2.1. Oil, coal and natural gas production forecast figures in the Energy Strategy of Russia in 2010-2020 and actual figures in 2003-2007
• Chart 2.2. Actual (2001-2007) and forecast gas production by Gazprom and independent producers in 2010 and 2020
• Chart 2.3. Gas production forecast by region (bcm)
• Chart 2.4. Gas price forecasts in the Energy Strategy and Gazprom's current estimates from 2005 to 2010
• Chart 2.5. Natural gas MET changes in 2004-2007 (Russian Roubles)
• Chart 3.1. Gazprom's gas production from 2000 to 2007 (bcm)
• Chart 3.2. Gazprom's gas production within and beyond the Nadym-Pur-Taz region from 2000 to 2007 (bcm)
• Chart 3.3. Schedule of commissioning of IGPFs and gas production growth in the Urengoyskoye field (bcm)
• Chart 3.4. Gas production of Urengoygazprom from 2000 to 2007 (bcm)
• Chart 3.5. Gas and condensate processing by West Siberian integrated processing plant
• Chart 3.6. Production at Urengoy gas processing plant in 2007 (thousand tonnes)
• Chart 3.7. Production at Surgut gas processing plant in 2007 (thousand tonnes)
• Chart 3.8. Gas production potential of Gazprom Dobycha Urengoy from 2007 to 2020 (bcm) 83
• Chart 3.9. Percentage of old and new fields of Urengoygazprom from 2007 to 2020
• Chart 3.10. Prospects for changes in the wellhead prices of Gazprom Dobycha Urengoy (nominal USD per 1,000 cubic meters)
• Chart 3.11. Nadymgazprom's gas production from 2000 to 2007 (bcm)
• Chart 3.12. Gas production potential of Gazprom Dobycha Nadym from 2007 to 2020 (bcm)
• Chart 3.13. Prospects for changes in the wellhead prices of Gazprom Dobycha Nadym (USD per 1,000 cubic meters)
• Chart 3.14. Composition of gas from Cenomanian reservoir of the Yamburgskoye gas condensate field
• Chart 3.15. Composition of gas from the Zapolyarnoye field
• Chart 3.16. Gas production of Yamburggazdobycha from 2000 to 2007 (bcm)
• Chart 3.17. Gas production potential of Gazprom Dobycha Yamburg from 2007 to 2020 (bcm)
• Chart 3.18. Percentage of old and new fields of Gazprom Dobycha Yamburg from 2007 to 2020
• Chart 3.19. Prospects for changes in the wellhead prices of Gazprom Dobycha Yamburg (USD per 1,000 cubic meters)
• Chart 3.20. Gas production of Noyabrskgazdobycha from 2000 to 2007 (bcm)
• Chart 3.21. Gas production potential of Gazprom Dobycha Noyabrsk from 2007 to 2020 (bcm)
• Chart 3.22. Prospects for changes in the wellhead prices of Gazprom Dobycha Noyabrsk (USD per 1,000 cubic meters)
• Chart 3.23. Business model of operation of Purgazdobycha
• Chart 3.24. Gas production potential from the West-Tarkosalinskoye field from 2007 to 2020 (bcm)
• Chart 3.25. Model for the transfer of title to the South-Russkoye field development from 1993 to 2001
• Chart 3.26. Stakes in Severneftegazprom held by project participants in voting shares
• Chart 3.27. Business model of Severneftegazprom.
• Chart 3.28. Gas production potential in the South Russkoye field from 2007 to 2020 (bcm)
• Chart 3.29. Business model of Achimgaz from 2007
• Chart 3.30. Gas production potential of Achimgaz to 2020 (bcm)
• Chart 3.31. Business model of Purgaz
• Chart 3.32. Gas production potential from the Gubkinskoye field of Purgaz from 2007 to 2020 (bcm)
• Chart 3.33. Current allocation of shares in Northgas
• Chart 3.34. Gas production of Northgas from 2001 to 2007 (bcm)
• Chart 3.35. Gas production potential in the North-Urengoyskoye field from 2007 to 2020 (bcm)
• Chart 3.36. Composition of gas from the Astrakhanskoye field
• Chart 3.37. Gas production of Astrakhangazprom from 2000 to 2007 (bcm)
• Chart 3.38. Process flow chart of Astrakhan integrated plant
• Chart 3.39. Gas processing at Astrakhan GPP and production of hydrocarbon liquids
• Chart 3.40. Production potential of Gazprom Dobycha Astrakhan from 2007 to 2020 (bcm)
• Chart 3.41. Prospects for changes in the wellhead prices of Gazprom Dobycha Astrakhan (USD per 1,000 cubic meters)
• Chart 3.42. Composition of gas of the Orenburgskoye field
• Chart 3.43. Gas production of Orenburggazprom from 2000 to 2007 (bcm)
• Chart 3.44. Process flow chart of the Orenburg Gas Processing Plant
• Chart 3.45. Gas production potential for the Orenburgskoye field from 2007 to 2020 (bcm) . 144
• Chart 3.46. Gas production of Stimul from 2003 to 2007 (bcm)
• Chart 3.47. Gas production of Severgazprom from 2000 to 2007 (bcm)
• Chart 3.48. Processing at Sosnogorsk GPP
• Chart 3.49. Gas production potential from the fields of Severgazprom from 2007 to 2020 (bcm)
• Chart 3.50. Gas production potential of Tomskgazprom from 2000 to 2007 (bcm)
• Chart 3.51. Gas production potential of Tomskgazprom from 2007 to 2020 (bcm)
• Chart 3.52. Gas production of Kubangazprom from 2000 to 2007 (bcm)
• Chart 3.53. Gas production potential of Gazpromtransgas Kuban from 2007 to 2020 (bcm)
• Chart 3.54. Gas production potential of Gazprom's companies in the Nadym-Pur-Taz Region (wholly owned by Gazprom) from 2007 to 2020 (bcm)
• Chart 3.55. Gas production potential of Gazprom's companies in the Nadym-Pur-Taz Region (in which Gazprom holds 50 percent or more) from 2007 to 2020 (bcm)
• Chart 3.56. Total gas production potential of Gazprom's companies in the Nadym-Pur-Taz Region from 2007 to 2020 (bcm)
• Chart 3.57. Total gas production potential of Gazprom's companies outside the Nadym-Pur-Taz Region from 2007 to 2020 (bcm)
• Chart 3.58. Consolidated forecast of gas production from the existing fields controlled by Gazprom (NPTR and non-NPTR) from 2007 to 2020 (bcm)
• Chart 3.59. Gas production of Arcticgas, 2002-2007 (bcm)
• Chart 3.60. Gas production potential of Sever Energiya from 2010 to 2020 (bcm)
• Chart 3.61. Gas production potential of Sibneftegaz from 2007 to 2020 (bcm)
• Chart 3.62. Consolidated forecast of gas production from the existing fields of Gazprom according to Scenario 2 (NPTR and non- NPTR) from 2007 to 2020 (bcm)
• Chart 3.63. Share of enterprises in which Gazprom owns 50 percent or more in Gazprom's total production (NPTR and non- NPTR) according to Scenario 2 from 2007 to 2020
• Chart 3.64. Consolidated forecast of gas production from the existing fields of Gazprom according to Scenario 2 (NPTR and non- NPTR) from 2007 to 2020 (bcm)
• Chart 4.1. NOVATEK's equity structure as of December 31, 2007
• Chart 4.2. Natural gas reserves (bcm)
• Chart 4.3. NOVATEK's gas production 2000 to 2007 (bcm)
• Chart 4.4. Gas production in the Yurkharovskoye field (bcm)
• Chart 4.5. Gas production in the Vostochno-Tarkosalinskoye field (bcm)
• Chart 4.6. Gas production in the Khancheiskoye field (bcm)
• Chart 4.7. Production indicators of Purovsky Plant (thousand tonnes)
• Chart 4.8. NOVATEK's gas production potential from 2007 to 2020 (bcm)
• Chart 4.9. NOVATEK's capital expenditures in connection with exploration from 2008 to 2015 (USD million)
• Chart 4.10. Gas production by oil companies 2000 to 2007 (bcm)
• Chart 4.11. Regions of LUKOIL's gas production
• Chart 4.12. LUKOIL's gas production 2000 to 2007 (bcm)
• Chart 4.13. Gas production in the Nakhodkinskoye field from 2004 to 2007 (bcm)
• Chart 4.14. Gas production of the Bolshekhetskaya Depression fields from 2007 to 2020 (bcm)
• Chart 4.15. Gas production of North Caspian fields 2009 to 2020 (bcm)
• Chart 4.16. LUKOIL's gas production potential 2007 to 2020 (bcm)
• Chart 4.17. Regions of Rosneft's gas production
• Chart 4.18. Rosneft's gas production from 2000 to 2007 (bcm)
• Chart 4.19. Gas production potential of Rosneft from 2007 to 2020 (in European Russia) (bcm)
• Chart 4.20. Regional breakdown of TNK-BP's gas production
• Chart 4.21. TNK-'s gas production from 2002 to 2007 (bcm)
• Chart 4.22. Rospan's gas production from 2001 to 2007 (bcm)
• Chart 4.23. TNK-'s gas production potential from 2007 to 2020 (European Russia) (bcm)
• Chart 4.24. Surgutneftegas's gas production from 2001 to 2007 (bcm)
• Chart 4.25. Surgutneftegas's gas production potential from 2007 to 2020 (bcm)
• Chart 4.26. Gas production potential by asset of oil companies and independent gas producers (current boundaries of the UGSS) from 2007 to 2020 (bcm)
• Chart 5.1. Gas reserves of the Bovanenkovskoye and Shtokmanovskoye fields, the Ob and Taz Bays, the Achimov Formation of the NPTR (tcm)
• Chart 5.2. Gas production in Yamal to achieve 250 bcma as estimated by Gazprom (bcm)
• Chart 5.3. Schedule of gas production in the Bovanenkovskoye field from the date of its planned commissioning until 2020 (bcm)
• Chart 5.4. General schedule of development of the Kharasaveiskoye field reservoirs (bcm per year)
• Chart 5.5. Yamal field licensing phases
• Chart 5.6. Shareholders of Shtokman Development AG
• Chart 5.7. Forecast gas sales during the first phase of Shtokman project
• Chart 5.8. Business model of the first phase Shtokman project
• Chart 5.9. Model of subsea development of the Shtokmanovskoye field
• Chart 5.10. Two concepts of the Shtokmanovskoye field development (70 bcm and 95 bcm) 268
• Chart 5.11. The development schedule of phase one of the Shtokmanovskoye field
• Chart 5.12. Most attractive terminals for LNG delivery from Shtokman (cost components include shipping, regasification and local pipeline costs, as a percentage of the best option)
• Chart 5.13. General plan of development of the Ob and Taz Bay fields (bcm)
• Chart 5.14. Production potential of Eastern Siberia and the Far East from 2007 to 2020 (bcm)
• Chart 5.15. Resource base of the Kovyktinsky and Khandinsky license areas controlled by Rusia Petroleum (bcm)
• Chart 5.16. Current shareholding structure of Rusia Petroleum
• Chart 5.17. Potential distribution of gas from the Kovyktinskoye field under the international feasibility study project (bcm per year)
• Chart 5.18. Possible parameters of the Kovyktinskoye field development
• Chart 5.19. Regional scenario implementation schedule
• Chart 5.20. Gas supplies from the Kovyktinskoye field according to regional scenario (bcm) . 293
• Chart 5.21. Composition of gas from the Chayandinskoye field
• Chart 5.22. Possible options of gas production in Chayandinskoye (bcm)
• Chart 5.23. Proved crude oil, gas and condensate reserves of the Sobinskoye and Paiginskoye fields
• Chart 5.24. Possible annual gas production in Sobinskoye and Paiginskoye fields
• Chart 5.25. Current shareholders of the Sakhalin-1 project
• Chart 5.26. Composition of gas from Odoptu-More
• Chart 5.27. Composition of gas from the Chaivo field
• Chart 5.28. Sakhalin-1 gas production in 2005-2008 (bcm)
• Chart 5.29. Investment in Sakhalin-1 project (USD billion)
• Chart 5.30. Potential gas production under the Sakhalin-1 project until 2020 (bcm)
• Chart 5.31. Shares in Sakhalin Energy before negotiations with Gazprom
• Chart 5.32. Current owners of Sakhalin Energy
• Chart 5.33. Oil, gas and condensate reserves of the Sakhalin-2 project fields
• Chart 5.34. Piltun-Astokhskoye gas composition
• Chart 5.35. Lunsoye gas composition
• Chart 5.36. Sakhalin-2 gas annual production potential (bcm)
• Chart 5.37. Sakhalin-3 gas annual production potential (bcm)
• Chart 5.38. Forecast output in the current fields in operation in the Far East (bcm)
• Chart 6.1. Natural gas consumption in Russia in 2007 by sector (without transportation gas)
• Chart 6.2. Gas consumption growth trend and average gas prices for industry and households in 2000-2007
• Chart 6.3. Gas demand in Russia in 2008-2020 (bcm)
• Chart 6.4. Gazprom gas exports from Russia (bcm)
• Chart 6.5. Gazprom gas exports to Western and Central Europe in 2007 (bcm)
• Chart 6.6. Natural gas exports to CIS and Baltic States in 2007 (bcm)
• Chart 6.7. LNG self-contracting model
• Chart 6.8. Global market demand forecast for Russian gas, by scenario, in 2010-2020 (bcm) 334
• Chart 6.9. Global market and domestic demand forecast for Russian gas, by scenario, in 2008-2020 (bcm)
• Chart 6.10. Global market and domestic demand forecast for Russian gas, for Europe and Asia for the White scenario (bcm)
• Chart 6.11. Global market and domestic demand forecast for Russian gas, for Europe and Asia for the Blue scenario (bcm)
• Chart 6.12. Natural gas reserves of Kazakhstan, Turkmenistan and Uzbekistan (tcm)
• Chart 7.1. Russian gas production growth potential (bcm)
• Chart 7.2. Investments in production facilities by region (USD billion). Maximum case
• Chart 7.3. Investments in production by Gazprom and other producing companies (USD billion)
• Chart 7.4. Balance between demand under the Blue Scenario and production potential (bcm)
• Chart 7.5. Russian gas production (bcm). The Blue Scenario
• Chart 7.6. Investments in production assets by region (USD billion). The Blue Scenario
• Chart 7.7. Investments in production by Gazprom and other producing companies (USD billion). The Blue Scenario
• Chart 7.8. Balance between the demand under White Scenario and production potential (bcm)
• Chart 7.9. Russian gas production (bcm). The White Scenario
• Chart 7.10. Investments in production assets by region (USD billion). The White Scenario
• Chart 7.11. Investments in production by Gazprom and other producing companies (USD billion). The White Scenario

Tables

• Table 1.1. Short list of acquired or regained assets
• Table 1.2. History of Gazprom's credit rating as of the end of 2003 till 2007
• Table 1.3. Trend of natural gas and associated gas production by the independent gas producers and Oil Companies in Russia in 2000-2007 (bcm)
• Table 1.4. Classification of oil and gas reserves adopted in Russia and the USA
• Table 1.5. Distribution of natural gas reserves in Russia by Federal Districts
• Table 1.6. Ratio of gas production and gas reserve increment
• Table 2.1. Recoverable reserves of the federal category fields
• Table 2.2. Federal category gas fields
• Table 2.2. Federal category gas fields (continuation)
• Table 2.3. Federal and regional governments' powers
• Table 2.3. Federal and regional governments' powers (continuation)
• Table 2.3. Federal and regional governments' powers (continuation)
• Table 2.4. Subsoil blocks use periods
• Table 2.5. Gas resources auctions proposed for 2008
• Table 2.6. Current MET rates
• Table 3.1. Basic Fields of Urengoygazprom
• Table 3.2. Planned gas production from the new zones developed by Urengoygazprom from 2000 to 2007
• Table 3.3. Cost-plus from Urengoy field to the Belarus border, Ukrainian border, Nord Stream pipeline entry point, Blue Stream pipeline entry point (nominal USD per 1,000 cubic meters)
• Table 3.4. Basic fields of Nadymgazprom
• Table 3.5. Basic fields of the Yamburggazdobycha
• Table 3.6. Planned production from the Yamburggazdobycha fields
• Table 3.7. Cost-plus from Yamburg to the Ukrainian border and Blue Stream pipeline entry point (nominal USD per 1,000 cubic meters)
• Table 3.8. Basic fields of Noyabrskgazdobycha
• Table 3.9. Gas production from the fields of Noyabrskgazdobycha
• Table 3.10. Cost-plus from South-Urengoyskoye field to the Nord Stream pipeline entry point and Belarusian border (nominal USD per 1,000 cubic meters)
• Table 3.11. Geological reserves of the North-Urengoyskoye field
• Table 3.12. Cost-plus from Orenburgskoye field to the Ukrainian border and Blue Stream entry point (nominal USD per 1,000 cubic meters)
• Table 3.13. Basic fields of Severgazprom
• Table 3.14. Basic fields of Enineftegaz
• Table 4.1. Equity gas production of Itera Group in the early 2000s
• Table 4.2. Itera's reserves in the early 2000s (bcm)
• Table 4.3. Structure of the upstream and processing assets of NOVATEK (as of beginning of 2008)
• Table 4.4. Basic fields of NOVATEK
• Table 4.5. Owners of licenses for the principal fields of NOVATEK
• Table 4.6. Capital expenditures in NOVATEK's principal fields from 2008 to 2015 (USD million)
• Table 4.6. Capital expenditures in principal fields from 2008 to 2015 (USD million) (Continuation)
• Table 4.7. Cost-plus from Yurkharovskoye field to the Ukrainian border and Dzhubga (nominal USD per 1,000 cubic meters)
• Table 4.8. Basic fields of LUKOIL (Russian classification)
• Table 4.9. Rosneft basic fields (Russian classification)
• Table 4.10. Cost-plus* from Kharampurskoye field to the Ukrainian border and Dzhubga (nominal USD per 1,000 cubic meters)
• Table 4.11. Rospan basic fields (Russian classification)
• Table 4.12. Cost-plus from Vostochno-Urengoyskoye field to the Ukrainian border and Dzhubga (nominal USD per 1,000 cubic meters)
• Table 4.13. Surgutneftegas basic fields
• Table 5.1. Production potential of the basic groups of Yamal fields
• Table 5.2. Gas reserves of the Bovanenkovskoye field (bcm)
• Table 5.3. Composition of natural gas from the Bovanenkovskoye field
• Table 5.4. Cost-plus from Bovanenkovskoye field to the Nord Stream pipeline entry point and Belarusian border (nominal USD per 1,000 cubic meters)
• Table 5.5. Gas reserves of the Kharasaveiskoye field (bcm)
• Table 5.6. SWOT analysis of the Bovanenkovskoye and Kharasaveiskoye field development project
• Table 5.7. Yamal fields included in the list of non-licensed strategic fields
• Table 5.8. Resource base of Yamal blocks to be licensed in the future broken down by Group257
• Table 5.9. Cost-plus from Shtokman to the liquefaction plant loading arm and Nord Stream pipeline entry point (nominal USD per 1,000 cubic meters)
• Table 5.10. SWOT analysis of the Shtokman project
• Table 5.11. Reserves of the Ob and Taz Bay fields
• Table 5.12. Cost-plus from Ob and Taz Bay fields to the Ukrainian border and Dzhubga (nominal USD per 1,000 cubic meters)
• Table 5. 13. General characteristics of the Kovyktinskoye field
• Table 5.14. Composition of gas from the Kovyktinskoye field
• Table 5.15. Cost-plus from Kovyktinskoye field to the Ukrainian and China borders (nominal USD per 1,000 cubic meters)
• Table 5.16. Cost-plus from Sakhalin-1 to China border (nominal USD per 1,000 cubic meters) 307
• Table 5.17. Cost-plus from Sakhalin-2 to the liquefaction plant loading arm (nominal USD per 1,000 cubic meters)
• Table 5.18. Cost-plus from Sakhalin-3 to China border (nominal USD per 1,000 cubic meters)
• Table 6.1. Unified Gas Supply System in 2007

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