Natural Gas Production in Russia: 2008-2020
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Release date:
July 2008
Language:
English, Russian
Volume:
387 pages, over 270 figures, maps and tables
Format:
book and cd (print-out protected)
Delivery:
express mail (2-4 days)
Price:
9,500 ˆ
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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
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
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-ÂÐ
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
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 Group
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)
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
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-ÂÐ’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
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