Alexander's Gas & Oil Connections - Russian Oilfield Services Market 2007: Analysis and Outlook

Russian Oilfield Services Market 2007: Analysis and Outlook

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Russian Oilfield Services Market: Analysis and Outlook

Release: November 2007
Languages: Russian, English
Price: 13500 EURO

2006 was a great year for the oilfield service (OFS) companies working on the Russian market. While in 2005 drilling volumes showed a healthy 9 percent year-on-year increase, in 2006 the dynamics continued with accelerating speed finally setting a smashing record of 25 percent year-on-year growth.

Upstream operators in Russia have been enjoying healthy revenues due to hovering oil prices. However, they find themselves confronted with the challenge of ensuring sustainable production growth under increasingly acute under-supply of drilling and oilfield service capacities. This shortage has been a major contributor to the escalation of prices for oilfield services, as well as the reason behind the recent string of declines on the part of OFS contractors to provide capacity to operators - an occurrence unheard of in previous years. For the first time in post-Soviet history, the OFS sector finds itself in a condition that allows it to pour investment into expansion and modernization programs.

Performance shown by the market leaders in the past several years has been exceptional. Between 1999 and 2006 Schlumberger grew its Russian operations from $50 million to an estimated $1.25 billion, an average of 50 percent increase annually. For the period of 2002-2006, Eurasia Drilling Company (former LUKOIL Drilling) had revenues grow organically from $177 million to $988 million (an average annual growth of 53 percent) and net income from $1 million to $95 million. Between 2003 and 2006 Austria-registered C.A.T. oil AG grew in operations from 80 million Euro to 194 million Euro, showing a 25 percent average annual growth. The market witnessed a number of success stories involving newly organized ventures growing to annual turnovers of $100 million after only several years of operations.

The publish of the report projects that the Russian OFS market will grow to $35 billion by 2015. However, different segments of the market will be each in its own way influenced by oil industry fundamentals, as well as structural developments, and will thus have their own individual growth patterns. Taken as examples, conventional drilling, hi-tech services and fracturing will differ significantly in their growth potential, performance and attractiveness for institutional and strategic investors.

The second edition of Russian Oilfield Services Market: Analysis and Outlook is probably the most comprehensive publicly available examination of this exciting and challenging market. The study analyzes the key factors shaping the OFS scene, and goes further into detailed research of particular market segments, regions and key players. Russian Oilfield Services Market 2007: Analysis and Outlook contains growth forecasts to 2015 for the main market segments, developed based on extensive in-house research experience in this field. The study is based on 2006 year-end data, with data for the first half of 2007 used when available.

Highlights of the study:

Oil and gas upstream - Russian output has been growing at a significant pace in spite of low investment in new capacity. The study addresses such key questions as:
- What were key drivers of recent production growth? What factors have historically favored achieving this without major investment?
- How did technology newly introduced to Russia reshape production practices?
- What were the key developments and trends in particular producing regions and companies?
- Is the strong growth of recent years sustainable for the short and mid-term future? What will be the key drivers of production growth in the next five to ten years?
- What are the areas and volumes of investment required to support production growth?
Demand for oilfield services - The Russian oil industry has been lately undergoing another structural change with the government assuming a leading role in the oil and gas industry. The study examines the following issues:
- What will be the implications of state-driven consolidation of production assets for the oilfield service industry?
- What is the size and segmentation of the market for oilfield services?
- What are the largest oilfield service consumers and how do they manage oilfield services today and in the future?
- What criteria do oil companies use in selecting oilfield service contractors?
- What opportunities does the market hold for newcomers, both Russian and international?
Oilfield service companies - The sector is developing very dynamically, driven by consolidation and outsourcing of oilfield services from within oil companies. After a period that saw an under-invested and under-developed market, the sector is now demonstrating strong growth and more maturity:
- Who are the sector's key players by segment and region?
- What are the results and longer-term impact of recent consolidation across the sector? What is the further structural evolution of the oilfield services sector and how does it affect the market players?
- What opportunities does the growing market hold and what corporate strategies are expected to work best for both Russian and international companies?
- Will 'energy nationalism' extend to the oilfield service and supply sector?
Oilfield equipment manufacturers and suppliers - Slow demand for domestically-manufactured equipment, along with high inflation and the strong Ruble, have been decreasing the competitiveness of Russian equipment. At the same time, Western manufacturers have had their own set of difficulties in selling equipment to the Russian market. The study explores the following issues:
- What are the competitive advantages of the main groups of equipment suppliers competing for their share of the uprising market?
- What types of equipment will be in demand and why?
- How can equipment manufacturers benefit from the replacement of the aging current inventory of production assets?
- What methods for reaching the potential consumer are expected to be most efficient?

Russian Oilfield Services Market 2007: Analysis and Outlook Volume I.

CONTENTS

1 Key Findings
2 Oil and gas industry's development in the recent five years
2.1 A brief description of the industry's development
2.2 Hydrocarbons production
2.2.1 Oil production
2.2.2 Gas production
2.2.3 Oil industry
2.2.4 Balance of gas distribution
3 Development of the market of oilfield services in Russia
3.1 Drilling and wells completion in Russia
3.2 Dynamics in well workover/well servicing operations
3.3 Effectiveness of well servicing/well workover operations
3.4 Hydro fracs and effectiveness of operations
3.5 Impact on the bottom-hole area, optimization of artificial lift and their performance
3.6 Water injection
3.7 Manufacturing of main types of OFS equipment in Russia
4 Market size estimates for key oilfield service segments
4.1 Market size estimates
4.1.1 Sidetracking
4.1.2 Geophysical surveys (logging)
4.2 Oilfield market in key producing regions
4.3 Market size for main groups of equipment
5 Oilfield services in key crude oil producing regions
5.1 Crude oil production by region
5.2 Production drilling and production well completions
5.3 Workover operations by key regions
5.4 Western Siberia
5.5 Khanty-Mansiysk Autonomous District
5.5.1 Climate and geology
5.5.2 Key players' share in crude oil production and consumption of key oilfield services
5.6 Yamal-Nenets Autonomous District
5.6.1 Climate and geology
5.6.2 Key players' share in crude oil production and consumption of key oilfield services
5.7 Volga-Urals region
5.7.1 Climate and geology
5.7.2 Key players' share in crude oil production and consumption of key oilfield services
5.8 Timan-Pechora
5.8.1 Climate and geology
5.8.2 Key players' share in crude oil production and consumption of key oilfield services
5.9 North Caucasus
5.9.1 Climate and geology
5.9.2 Key players' share in crude oil production and consumption of key oilfield services
5.10 Eastern Siberia
5.10.1 Climate and geology
5.10.2 Key players' share in crude oil production and consumption of key oilfield services
5.11 Far East
5.11.1 Climat and geology
5.11.2 Key players' share in crude oil production and consumption of key oilfield services
6 Analysis of oilfield services customers (major companies)
6.1 Analysis of oilfield services customers (major companies)
6.2 Multi-regional vertically-integrated oil companies (VIOCs)
6.2.1 Rosneft
6.2.2 LUKOIL
6.2.3 TNK-BP
6.2.4 Gazprom neft
6.2.5 Russneft
6.3 Mono-regional vertically integrated oil companies (VIOC) and Gazprom
6.3.1 Surgutneftegas
6.3.2 Slavneft
6.3.3 Tatneft
6.3.4 Bashneft
6.3.5 Gazprom
6.4 Criteria for selecting oilfield services suppliers

LIST OF FIGURES AND TABLES

Figure 2-1. Structure of oil production in Russia in 2000
Figure 2-2. Structure of oil production in Russia in 2006
Figure 2-3. Crude oil production and production drilling in Russia, 1990-2006
Table 2-4. Dynamics of oil production in Russia, 2000-2006 (millions of tons)
Figure 2-5. Oil production and production drilling in Russia and global oil prices, 1990-2006
Figure 2-6. Oil production and production drilling in Russia and global oil prices, 1990-2015
Figure 2-7. Dynamics of oil production in 1991-2006 (% vs. previous year)
Table 2-8. Dynamics of gas production in Russia, 2000-2006 (billions of cubic meters)
Table 2-9. Distribution of gas production in Russia among individual groups of producers (billions of cubic meters)
Figure 2-10. Balance of oil distribution in Russia, 2000-2006 (millions of tons)
Figure 2-11. Balance of gas distribution in Russia, 2000-2006 (billions of cubic meters)
Figure 3-1. Drilling in key regions, 2001-2006 (thousands of meters)
Figure 3-2. Prospecting and exploratory drilling, 2001-2006 (thousands of meters)
Figure 3-3. Prospecting and exploratory drilling in key regions in 2006 (%)
Figure 3-4. Production drilling in key regions, 2001-2006 (thousands of meters)
Figure 3-5. Effect of production drilling in Russia per 1,000 meters of drilling in 1,000 tons, 2000-2006
Figure 3-6. Estimated daily flow of new oil wells in Russia, 2000-2006 (tons per day)
Figure 3-7. Additional production from production drilling and intensification methods in Russia, 2004-2006
Figure 3-8. Daily production and daily drilling footage, 2002-2007
Figure 3-9. Daily drilling meterage by month, 2002-2007 (1,000 meters per day)
Table 3-10. Dynamics of daily drilling in Russia by month, 2002-mid 2007
Figure 3-11. Horizontal drilling in Russia, 2001-2006 (thousands of meters)
Figure 3-12. Volumes of well servicing/well workovers in Russia, 2001-2006 (operations)
Figure 3-13. Structure of the well servicing/well workover portfolio in Russia, 2001-2006, (%)
Figure 3-14. Coverage of the total producing wells stock with well servicing/well workover operations in Russia, 2001-2006 (thousands of wells)
Figure 3-15. The coverage of producing well stock with well servicing/well workover operations in Russia, 2001-2006 (thousands of wells)
Figure 3-16. Market size in million of hours (the left-hand side index line) and the average duration of light workovers (the right-hand side index line) in Russia, 2001-2006 (crew-hours)
Figure 3-17. Market size in million hours (left-hand side index line) and the average duration (the right-hand side index line) of heavy workovers in Russia, 2001-2006 (crew-hours)
Figure 3-18. Number of well servicing/well workover crews in Russia, 2001-2006
Figure 3-19. Operations per 1 well-servicing crew (left-hand side) and well-workover crew (the right-hand side) in Russia, 2001-2006 (operations per year)
Figure 3-20. Operations per 1 well-servicing crew in 1,000 hours (left-hand side) and capacity-utilization rate of a well-servicing crew (right-hand) in Russia, 2001-2006
Figure 3-21. 1,000 hours per 1 heavy workover crew (left-and side) and the capacity-utilization rate of a well workover crew (right-hand side index line) in Russia, 2001-2006
Figure 3-22. Additional production due to activities of well servicing/well workover and the contribution of the activities into additional production, 2004-2006 (thousands of tons)
Figure 3-23. Number of operations of production intensification in Russia, 2001-2006 (thousands of operations and %)
Figure 3-24. Number of hydraulic fracturing operations in existing well stock in Russia, 2001-2006
Figure 3-25. Effectiveness of hydro fracs operations in existing well stock in Russia, 2004-2006
Figure 3-26. Number of operations impacting the effective drainage area and their effectiveness in Russia, 2001- 2006
Figure 3-27. Number of operations for optimization of artificial lift and their effectiveness in Russia, 2001-2006
Figure 3-28. Water injection in reservoirs and water injection per ton of lifted oil in Russia, 2000-2006
Figure 3-29. Active injection wells stock and water injection per injection well in Russia, 2000-2006
Figure 3-30. Evaluation of main oilfield services equipment production in current prices (Rosstat) (left-hand side index line - millions US dollars) and cumulative inflation (right-hand side index line - %)
Figure 3-31. Estimated dynamics of production of main equipment in standard prices of 2005 (2005 = 100%)
Figure 3-32. Production of drilling rigs and well workover/well servicing units, 2000-2006 (units)
Figure 3-33. Production of cementing units and pumping units for hydro fracs, 2000-2006 (units)
Figure 3-34. Production of wellhead and Christmas tree fittings, 2000-2006 (units)
Figure 3-35. Production of artificial lift pumps in Russia, 2001-2006 (units)
Figure 3-36. Production of deep well sucker-rod pumps and ESP Systems in Russia, 2001-2006 (units)
Figure 3-37. Stock of producing wells by type of artificial lift, 2001-2006 (units)
Figure 3-38. Production of rod pump surface units in Russia, 2001-2006 (units)
Figure 3-39. Production of well logging aggregates, 2002-2006 (units)
Figure 4-1. Oilfield services market structure in 2006
Figure 4-2. Oilfield services market dynamics, 2001-2006, (millions of US dollars)
Table 4-3. Oilfield market dynamics in key segments, 2001-2006
Figure 4-4. Input of key segments in incremental market growth, 2001-2006 (millions of US dollars)
Figure 4-5. Average annual growth in key industry segments
Figure 4-6. Change in market structure, 2001-2006
Figure 4-7. Sidetracking market estimates, 2001-2006 (millions of US dollars)
Figure 4-8. Geophysical surveys (logging) market, 2001-2006 (millions of US dollars)
Figure 4-9. Regional structure of oilfield service market, 2001-2006 (excluding seismic)
Figure 4-10. Production of key equipment categories in Russia in 2001-2006 in real $ `000 at average exchange rate for corresponding year
Figure 4-11. Apparent market shares for oilfield services equipment in 2006
Figure 5-1. Oil production by region, 2001-2006 (millions of tons)
Figure 5-2. Share in production by region (2006 versus 2001)
Table 5-3. Incremental production by region (2006 versus 2001)
Figure 5-4. Regional shares in key activities in 2006 (%)
Figure 5-5. Production drilling in key regions, 2001-2006 (thousands of meters)
Figure 5-6. Production drilling by key region (as % of total)
Figure 5-7. Commissioning of production wells by key region (tons/day)
Figure 5-8. Production wells completions in key regions, 2001-2006 (units)
Figure 5-9. Horizontal drilling by region, 2001-2006 (thousands of meters)
Figure 5-10. Well servicing and workover jobs by key region, 2001-2006 (thousands of operations)
Figure 5-11. Production wells, 2001-2006
Table 5-12. Coverage of production wells with workovers and well services, 2001-2006
Figure 5-13. Hydraulic fracturing jobs on the current declining well stock by region, 2004-2006 (%)
Figure 5-14. Oil production in KMAD by company, 2001-2006 (thousands of tons)
Figure 5-15. Oil production in KMAD � Key production activities, 2001-2006 (thousands of tons)
Figure 5-16. Production drilling in KMAD by company, 2001-2006 (thousands of meters)
Figure 5-17. Commissioning of new production wells in KMAD, 2001-2006 (wells)
Figure 5-18. Estimates of daily flow rates from new wells and average depths in KMAD, 2001-2006
Figure 5-19. Apparent average well depth in KMAD, 2001-2006, exclusive of horizontal drilling (thousands of meters)
Figure 5-20. Horizontal drilling in KMAD by company, 2001-2006 (thousands of meters)
Figure 5-21. Exploration drilling in KMAD by company, 2001-2006 (thousands of meters)
Figure 5-22. Production well stock and injection well stock, 2001-2006
Figure 5-23. Active wells in the total well stock in KMAD, 2001-2006 (%)
Figure 5-24. Well servicing operations jobs in KMAD, 2001-2006
Figure 5-25. Well workover jobs in KMAD by company, 2001-2006 (heavy workovers)
Table 5-26. Well workovers in KMAD by key player and growth rates, 2003-2006 (units)
Figure 5-27. Artificial lift optimization jobs in KMAD by company, 2001-2006 (units)
Figure 5-28. Effectiveness of artificial lift optimization activities in KMAD, 2001-2006 (incremental flow rate-- tons per day)
Figure 5-29. Bottom-hole zone treatment jobs in KMAD by company, 2001-2006 (operations)
Figure 5-30. Effectiveness of bottom-hole zone treatment activities in KMAD, 2001-2006 (flow rate- tons per day)
Figure 5-31. Number of hydraulic fracturing jobs in KMAD by company, 2004-2006 (units)
Figure 5-32. Effectiveness of hydraulic fracturing activities in KMAD, 2004-2006 (flow rate- tonsper day)
Figure 5-33. Water injection in KMAD by company, 2001-2006 (thousands of cubic meters)
Figure 5-34. Water injection per ton of production in KMAD, 2001-2006 (tons of water per ton of oil)
Figure 5-35. Gas production in YNAD by company, 2002-2006 (billions of cubic meters)
Figure 5-36. Production of crude oil and gas condensate in YNAD by company, 2001-2006 (thousands of tons)
Figure 5-37. Oil production in YNAD � Key production activities, 2001-2006 (thousands of tons)
Figure 5-38. Production drilling in YNAD by company, 2001-2006 (thousands of meters)
Figure 5-39. Commissioning of new production wells in YNAD by company, 2001-2006 (units)
Figure 5-40. Estimates of flow rates from new wells and average depths in YNAD, 2001-2006
Figure 5-41. Commissioning of horizontal wells in YNAD by company, 2001-2006 (units)
Figure 5-42. Exploration drilling in YNAD by company, 2001-2006 (thousands of meters)
Figure 5-43. Production and injection well stock in YNAD, 2001-2006
Figure 5-44. Producing wells and operational water injection wells versus total production wells in YNAD, 2001- 2006 (%)
Figure 5-45. Well-servicing jobs in YNAD by company, 2001-2006 (light workovers)
Figure 5-46. Well-workover jobs in YNAD by company, 2001-2006 (heavy workovers)
Table 5-47. Well workovers in YNAD by key player and growth rates, 2001-2006 (units)
Figure 5-48. Artificial lift optimization jobs in YNAD by company, 2001-2006 (units)
Figure 5-49. Effectiveness of artificial lift optimization activities in YNAD, 2001-2006 (incremental daily flow rate- tons per day)
Figure 5-50. Bottom-hole zone treatment jobs in YNAD by company, 2001-2006 (operations)
Figure 5-51. Effectiveness of Bottom-hole zone treatment activities in YNAD, 2001-2006 (incremental daily flow rate- tons per day)
Figure 5-52. Number of hydraulic fracturing jobs in YNAD by company, 2004-2006 (units)
Figure 5-53. Effectiveness of hydraulic fracturing activities in YNAD, 2004-2006 (flow rate- tons per day)
Figure 5-54. Water injection in YNAD by company, 2001-2006 (thousands of cubic meters)
Figure 5-55. Water injection per ton of production in YNAD, 2001-2006 (tons of water per ton of oil)
Figure 5-56. Oil and gas condensate production in the Volga-Urals region by company, 2001-2006 (thousands of tons)
Figure 5-57. Oil production in the Volga-Urals region � Key production activities, 2001-2006 (thousands of tons)
Figure 5-58. Production drilling in the Volga-Urals region by company, 2001-2006 (thousands of meters)
Figure 5-59. Completion of new production wells in the Volga-Urals region by company, 2001-2006 (units)
Figure 5-60. Estimates of flow rates from new wells and average depths in the Volga-Urals region, 2001-2006
Figure 5-61. Completion of horizontal wells in the Volga-Urals region by company, 2001-2006 (units)
Figure 5-62. Exploration drilling in the Volga-Urals region by company, 2001-2006 (thousands of meters)
Figure 5-63. Operating well stock in the Volga-Urals region, 2001-2006 (units)
Figure 5-64. Active wells as percentage of total operating wells in the Volga-Urals region, 2001-2006 (units)
Figure 5-65. Well-servicing jobs in the Volga-Urals region by company, 2001-2006 (light workovers � number of operations)
Figure 5-66. Well-workover jobs in the Volga-Urals region, 2001-2006 (heavy workovers � number of operations)
Figure 5-67. Artificial lift optimization jobs in the Volga-Urals region by company, 2001-2006 (units)
Figure 5-68. Effectiveness of artificial lift optimization activities in the Volga-Urals region, 2001-2006 (incremental flow rate- tons per day)
Figure 5-69. Bottom-hole zone treatment jobs in the Volga-Urals region by company, 2001-2006 (units)
Figure 5-70. Effectiveness of bottom-hole zone treatment activities in the Volga-Urals region, 2001-2006 (incremental flow rates--tons per day)
Figure 5-71. Number of hydraulic fracturing jobs in the Volga-Urals region by company, 2004-2006 (number of operations)
Figure 5-72. Effectiveness of hydraulic fracturing activities in the Volga-Urals region, 2004-2006 (incremental flow rate- tons per day)
Figure 5-73. Effectiveness of hydraulic fracturing activities by key company in the Volga-Urals region by company, 2004-2006 (incremental flow rate - tons per day)
Figure 5-74. Water injection in the Volga-Urals region by company, 2001-2006 (thousands of cubic meters)
Figure 5-75. Water injection per ton of production in the Volga-Urals region, 2001-2006 (tons of water per ton of oil)
Figure 5-76. Oil and gas condensate production in Timan-Pechora by company, 2001-2006 (thousands of tons)
Figure 5-77. Oil production in Timan-Pechora � Key production activities, 2001-2006 (thousands of tons)
Figure 5-78. Production drilling in Timan-Pechora by company, 2001-2006 (thousands of meters)
Figure 5-79. New production wells completion in Timan-Pechora by company, 2001-2006 (units)
Figure 5-80. Estimates of flow rates from new wells and average depths in Timan-Pechora, 2001-2006
Figure 5-81. Commissioning of horizontal wells in Timan-Pechora by company, 2001-2006 (units)
Figure 5-82. Exploration drilling in Timan-Pechora by company, 2001-2006 (thousands of meters)
Figure 5-83. Production well stock and water injection wells stock in Timan-Pechora, 2001-2006 (units)
Figure 5-84. Producing wells as percentage of total operating wells in Timan-Pechora, 2001-2006 (%)
Figure 5-85. Well-servicing jobs in Timan-Pechora by company, 2001-2006 (light workovers � number of operations)
Figure 5-86. Well-workover jobs in Timan-Pechora by company, 2001-2006 (heavy workovers � number of operations)
Figure 5-87. Artificial lift optimization jobs in Timan-Pechora by company, 2001-2006 (units)
Figure 5-88. Effectiveness of artificial lift optimization activities in Timan-Pechora, 2001-2006 (incremental flow rate- tons per day)
Figure 5-89. Bottom-hole zone treatment jobs in Timan-Pechora by company, 2001-2006 (units)
Figure 5-90. Effectiveness of bottom-hole zone treatment activities in Timan-Pechora, 2001-2006 (flow rate- tons per day)
Figure 5-91. Number of hydraulic fracturing jobs in Timan-Pechora by company, 2004-2006 (units)
Figure 5-92. Effectiveness of hydraulic fracturing activities in Timan-Pechora, 2004-2006 (incremental flow rate- tons per day)
Figure 5-93. Water injection in Timan-Pechora by company, 2002-2006 (thousands of cubic meters)
Figure 5-94. Water injection per ton of production in Timan-Pechora, 2002-2006 (tons of water per ton of oil)
Figure 5-95. Oil production in the North Caucasus by company, 2001-2006 (thousands of tons)
Figure 5-96. Oil production in the North Caucasus � Key production activities, 2001-2006 (thousands of tons)
Figure 5-97. Production drilling in the North Caucasus by company, 2001-2006 (thousands of meters)
Figure 5-98. New production wells completions in the North Caucasus by company, 2001-2006 (units)
Figure 5-99. Estimates of flow rates from new wells and average depths in the North Caucasus, 2001-2006
Figure 5-100. Exploration drilling in the North Caucasus by company, 2001-2006 (thousands of meters)
Figure 5-101. Total operating well stock in the North Caucasus, 2001-2006 (units)
Figure 5-102. Active wells as percentage of the total operating well stock in the North Caucasus (%)
Figure 5-103. Well-servicing jobs in the North Caucasus by company, 2001-2006
Figure 5-104. Well-workover jobs in the North Caucasus by company, 2001-2006
Figure 5-105. Artificial lift optimization jobs in the North Caucasus by company, 2001-2006 (units)
Figure 5-106. Effectiveness of artificial lift optimization activities in the North Caucasus, 2001-2006 (flow rate- tons per day)
Figure 5-107. Bottom-hole zone treatment jobs in the North Caucasus by company, 2001-2006 (units)
Figure 5-108. Effectiveness of bottom-hole zone treatment activities in the North Caucasus, 2001-2006 (incremental flow rate- tons per day)
Figure 5-109. Number of hydraulic fracturing jobs in the North Caucasus by company, 2004-2006 (units)
Figure 5-110. Effectiveness of hydraulic fracturing activities in the North Caucasus, 2004-2006 (incremental flow rate- tons per day)
Figure 5-111. Water injection in the North Caucasus by company (thousands of cubic meters)
Figure 5-112. Water injection per ton of production in the North Caucasus, 2001-2006 (tons of water per ton of oil)
Figure 5-113. Oil production in Eastern Siberia by company, 2001-2006 (thousands of tons)
Figure 5-114. Oil production in the Far East by company, 2001-2006 (thousands of tons)
Figure 5-115. Oil production in the Far East � Key production activities, 2001-2006 (thousands of tons)
Figure 5-116. Production drilling in the Far East by company, 2001-2006 (thousands of meters)
Figure 5-117. Commissioning of new production wells in the Far East by company, 2001-2006 (units)
Figure 5-118. Estimates of flow rates from new wells and average depths in the Far East, 2001-2006
Figure 5-119. Estimates of flow rates from new wells and average depths at Sakhalinmorneftegas, 2001-2006
Figure 5-120. Exploration drilling in the Far East by company, 2001-2006 (thousands of meters)
Figure 5-121. Total producing well stock in the Far East, 2001-2006 (units)
Figure 5-122. Active wells as percentage of the total operating well stock in the Far East, 2001-2006 (%)
Figure 5-123. Well-servicing jobs in the Far East by company, 2001-2006 (light workovers � number of operations)
Figure 5-124. Well-workover jobs in the Far East by company, 2001-2006 (heavy workovers � number of operations)
Figure 5-125. Artificial lift optimization jobs in the Far East by company, 2001-2006 (units)
Figure 5-126. Effectiveness of artificial lift optimization activities in the Far East, 2001-2006 (flow rate- tons/day)
Figure 5-127. Bottom-hole zone treatment jobs in the Far East by company, 2001-2006 (units)
Figure 5-128. Effectiveness of bottom-hole zone treatment activities in the Far East, 2001-2006 (incremental flow rate- tons/day)
Figure 5-129. Water injection in the Far East by company, 2001-2006 (thousands of cubic meters)
Figure 5-130. Water injection per ton of production in the Far East, 2001-2006 (tons of water per ton of oil)
Figure 6-1. Oil production by VIOCs and independent producers in Russia, 2001-2006 (millions of tons per year)
Figure 6-2. Estimates on core oilfield services cost by companies in 2006 (millions of dollars)
Figure 6-3. Structure of companies' core oilfield services expenditures in 2006 (millions of dollars)
Figure 6-4. Apparent costs of core oilfield services in 2006 (US dollars per 1 ton of produced oil)
Table 6-5. Summary indices of production activity of Rosneft, 2001-2006
Figure 6-6. Rosneft's oil production by region in current asset structure, 2000- 2006 (millions of tons)
Figure 6-7. Main financial indices of Rosneft adjusted per 1 ton of produced oil, 2000-2006 ($/t)
Table 6-8. Main financial indices of Rosneft, 2001-2006 (millions of US dollars)
Figure 6-9. Rosneft's drilling and equipment costs, 2001-2006 (millions of US dollars)
Figure 6-10. Scope of production drilling by Rosneft by region, 2001-2006 (thousands of meters)
Figure 6-11. Scope of exploratory drilling by Rosneft by region, 2000-2006 (thousands of meters)
Figure 6-12. Horizontal drilling by Rosneft by region, 2001-2006 (thousands of meters)
Figure 6-13. Rosneft's estimated daily flow rate of new wells, 2000-2006 (tons per day)
Figure 6-14. Rosneft's estimated daily flow rate caused by the impact on the effective drainage area, 2000-2006 (tons per day)
Figure 6-15. Rosneft's estimated daily flow rate caused by hydro fracs, 2004-2006 (tons per day)
Figure 6-16. Rosneft's estimated daily flow rate caused by artificial lift optimization, 2000-2006 (tons per day)
Table 6-17. Summary indices of LUKOIL's production activity, 2001-2006
Figure 6-18. LUKOIL's oil production by region, 2001-2006 (millions of tons)
Figure 6-19. Main financial indices of LUKOIL, 2001-2006 adjusted per 1 ton of oil produced ($/t)
Table 6-20. Main financial indices of LUKOIL, 2000-2006 (millions of US dollars)
Figure 6-21. Reported drilling and equipment expenses of LUKOIL, 2001-2006 (millions of US dollars)
Figure 6-22. Reported seismic exploratory works, carried out by LUKOIL, 2001-2006
Figure 6-23. Scope of development drilling by LUKOIL by region, 2001-2006 (thousands of meters)
Figure 6-24. Scope of exploratory drilling by LUKOIL by region, 2001-2006 (thousands of meters)
Figure 6-25. Scope of horizontal drilling by LUKOIL by region, 2001-2006 (thousands of meters)
Figure 6-26. Prospecting and exploration drilling by LUKOIL in Northern Caspian, 2000-2006 (thousands of meters)
Figure 6-27. The share of third-party and in-house contractors of LUKOIL in carrying out service works (%)
Figure 6-28. LUKOIL's estimated daily flow rate on new wells, 2000-2006 (tons per day)
Figure 6-29. LUKOIL's estimated daily flow rate caused by impact on the effective drainage area, 2000-2006 (tons per day)
Figure 6-30. LUKOIL's estimated daily flow rate with hydro fracs, 2004-2006 (tons per day)
Figure 6-31. LUKOIL's estimated daily flow rate due to artificial lift optimization, 2000-2006 (tons per day)
Table 6-32. Summary indices of production activity of TNK-BP, 2001-2006
Figure 6-33. Oil production by TNK-BP by region, 2000-2006 (millions of tons)
Figure 6-34. Main financial indices of TNK-BP*, 2002-2006 adjusted per 1 ton of produced oil
Table 6-35. Main financial indices of TNK-BP*, 2002-2006 (millions ofUS dollars)
Figure 6-36. TNK-BP's drilling and equipment expenses, 2001-2006 (millions of US dollars)
Figure 6-37. Production drilling performed by TNK- by region, 2000-2006 (thousands of meters)
Figure 6-38. Scope of exploratory drilling by TNK-BP by region, 2000-2006 (thousands of meters)
Figure 6-39. The scope of horizontal drilling by TNK-BP by region, 2002-2006 (thousands of meters)
Figure 6-40. TNK-BP estimated daily flow rate on new wells, 2000-2006 (tons per day)
Figure 6-41. TNK-BP estimated daily flow rate caused by impact on the effective drainage area, 2000-2006 (tons per day)
Figure 6-42. TNK-BP estimated daily flow rate caused by hydro fracs, 2004-2006 (tons per day)
Figure 6-43. TNK-BP estimated daily flow rate caused by artificial lift optimization, 2000-2006 (tons per day)
Table 6-44. Summary indices of Gazprom neft production activity assets, 2001-2006
Figure 6-45. Oil production by Sibneft by region, 2000-2006 (millions of tons)
Figure 6-46. Main financial indices of Sibneft, 2001-2006 as adjusted per 1 ton of produced oil
Table 6-47. Main financial* indices of Sibneft, 2001-2006 (millions of US dollars)
Figure 6-48. Sibneft's drilling and equipment expenses, 2001-2006 (millions of US dollars)
Figure 6-49. The scope of seismic work carried out by Sibneft, 2000-2005
Figure 6-50. The scope of production drilling by Sibneft by region, 2000- 2006 (thousands of meters)
Figure 6-51. Scope of exploratory drilling by Sibneft by region, 2000-2006 (thousands of meters)
Figure 6-52. Scope of horizontal drilling by Sibneft by region, 2001-2006 (thousands of meters)
Figure 6-53. Gazprom neft's estimated daily flow rate of new wells, 2000-2006 (tons /day)
Figure 6-54. Gazprom neft's estimated daily flow rate caused by the impact on the effective drainage area, 2000- 2006 (tons per day)
Figure 6-55. Gazprom neft's estimated daily flow rate caused by hydro fracs, 2004-2006 (tons per day)
Figure 6-56. Gazprom neft's estimated daily flow rate caused by artificial lift optimization, 2000-2006 (tons perday)
Table 6-57. Summary indices of production activity of Russneft, 2001-2006
Figure 6-58. Oil production by Russneft by region in 2006 asset structure, 2000-2006 (millions of tons)
Figure 6-59. Main financial indices of Russneft, 2003-2006, adjusted per 1 ton of produced oil (RAS)
Table 6-60. Main financial* indices of Russneft, 2003-2006 (millions of US dollars)
Figure 6-61. Scope of production drilling by Russneft by region, 2000-2006 (thousands of meters)
Figure 6-62. Scope of exploratory drilling by Russneft by region, 2000-2006 (thousands of meters)
Figure 6-63. Scope of horizontal drilling by Russneft by region, 2003-2006 (thousands of meters)
Figure 6-64. Russneft estimated daily flow rate at new wells, 2000-2006 (tons per day)
Figure 6-65. Russneft apparent daily flow rate caused by the impact on the effective drainage area, 2000-2006 (tons per day)
Figure 6-66. Russneft estimated daily flow rate due to hydro fracs, 2000-2006 (tons per day)
Figure 6-67. Russneft estimated daily flow rate due to optimization of artificial lift, 2000-2006 (tons per day)
Table 6-68. Summary indices of production activity of Surgutneftegas, 2001-2006
Figure 6-69. Oil production by Surgutneftegas in key regions, 2000-2006 (millions of tons)
Figure 6-70. Main financial indices of Surgutneftegas, 2001-2006, adjusted per 1 ton of produced oil (RAS)
Table 6-71. Main financial* indices of Surgutneftegas, 2000-2006 (millions od US dollars)
Figure 6-72. Drilling and equipment expenses of Surgutneftegas, 2001-2006 (millions of US dollars)
Figure 6-73. Production drilling by Surgutneftegas by region, 2000-2006 (thousands of meters)
Figure 6-74. Exploratory drilling by Surgutneftegas by region, 2001-2006 (thousands of meters)
Figure 6-75. Horizontal drilling by Surgutneftegas by region, 2000-2006 (thousands of meters)
Figure 6-76. Surgutneftegas' estimated daily flow rate at new wells, 2000-2006 (tons per day)
Figure 6-77. Surgutneftegas' estimated daily flow rate caused by the impact on the effective drainage area, 2000- 2006 (tons per day)
Figure 6-78. Surgutneftegas' estimated incremental daily flow rate from hydro fracs, 2000-2006 (tons per day)
Figure 6-79. Surgutneftegas' estimated incremental daily flow rate due to artificial lift optimization, 2000-2006 (tons per day)
Table 6-80. Summary indices of production activity of Slavneft, 2001-2006
Figure 6-81. Oil production by Slavneft, 2000-2006 (millions of tons)
Figure 6-82. Main financial indices of Slavneft, 2005-2006, adjusted per 1 ton of produced oil
Table 6-83. Main financial* indices of Slavneft, 2005-2006 (millions of US dollars)
Figure 6-84. Scope of 2D and 3D exploration seismology carried out by Slavneft, 2000-2005
Figure 6-85. Slavneft's production drilling, 2001-2006 (thousands of meters)
Figure 6-86. Slavneft's exploratory drilling, 2001-2006 (thousands of meters)
Figure 6-87. Horizontal drilling by Slavneft by region, 2000-2006 (thousands of meters)
Figure 6-88. Slavneft's estimated flow rate on new wells, 2000-2006 (tons per day)
Figure 6-89. Slavneft's estimated daily flow rate caused by the impact on the effective drainage area, 2000-2006 (tons per day)
Figure 6-90. Slavneft's estimated daily flow rate caused by hydro fracs, 2000-2006 (tons per day)
Figure 6-91. Slavneft's estimated daily flow rate caused by artificial lift optimization, 2000-2006 (tons per day)
Table 6-92. Summary indices of production activity of Tatneft, 2001-2006
Figure 6-93. Oil production by Tatneft by region, 2000-2006 (millions of tons)
Figure 6-94. Main financial indices of Tatneft, 2000-2006, adjusted per 1 ton of produced oil
Table 6-95. Financial indices of Tatneft, 2002-2006 (millions of US dollars)
Figure 6-96. Production drilling by Tatneft by region, 2001-2006 (thousands of meters)
Figure 6-97. Scope of exploratory drilling by Tatneft by region, 2000-2006 (thousands of meters)
Figure 6-98. Scope of horizontal drilling by Tatneft by region, 2000-2006 (thousands of meters)
Figure 6-99. Tatneft's estimated daily flow rate on new wells, 2000-2006 (tons per day)
Figure 6-100. Tatneft's estimated daily flow rate caused by the impact on the effective drainage area, 2000-2006 (tons per day)
Figure 6-101. Tatneft's estimated daily flow rate caused by hydro fracs, 2004-2006 (tons per day)
Figure 6-102. Tatneft's estimated daily flow rate caused by artificial lift optimization, 2000-2006 (tons per day) .222
Table 6-103. Summary indices of production activity of Bashneft, 2001-2006
Figure 6-104. Oil production by Bashneft by region, 2000-2006 (millions of tons)
Figure 6-105. Main financial indices of Bashneft, 2002-2006, adjusted per 1 ton of produced oil
Table 6-106. Main financial* indices of Bashneft, 2002-2006 (millions of US dollars)
Figure 6-107. Production drilling by Bashneft by region, 2001-2006 (thousands of meters)
Figure 6-108. Exploratory drilling by Bashneft by region, 2001-2006 (thousands of meters)
Figure 6-109. Horizontal drilling by Bashneft by region, 2000-2006 (thousands of meters)
Figure 6-110. Bashneft estimated flow rate on new wells, 2000-2006 (tons per day)
Figure 6-111. Bashneft estimated flow rate caused by the impact on the effective drainage area, 2000-2006 (tons per day)
Figure 6-112. Bashneft estimated daily flow rate caused by hydro fracs, 2000-2006 (tons per day)
Figure 6-113. Bashneft estimated daily flow rate caused by artificial lift optimization, 2000-2006 (tons per day)
Table 6-114. Summary indices of production activity of Gazprom, 2002-2006
Figure 6-115. Crude oil and condensate production by Gazprom, 2001-2006 (millions of tons)
Figure 6-116. Financial indices of Gazprom, 2001-2006, adjusted per ton of produced oil equivalent
Table 6-117. Main financial indices of Gazprom, 2000-2006 (millions of US dollars)
Figure 6-118. Production drilling by Gazprom, 2000-2006 (thousands of meters)
Figure 6-119. Exploratory drilling by Gazprom, 2000-2006 (thousands of meters)

Russian Oilfield Services Market 2007: Analysis and Outlook Volume II.

CONTENTS

7 Analysis of the competitive environment in the oilfield services sector in Russia
7.1 Overview of the competitive environment
7.2 Types of key players in the market and the dynamics of their future development
7.2.1 Services divisions of OAO Surgutneftegas
7.2.2 Service divisions of OAO Tatneft
7.2.3 Service divisions of OAO Bashneft
7.2.4 Schlumberger Ltd.
7.2.5 OAO PetroAlliance
7.2.6 Eurasia Drilling Company Limited (EDC) (formerly LUKOIL-Drilling)
7.2.7 ZAO SSK
7.2.8 ZAO Nizhnevartovskburneft
7.2.9 OOO Burneft
7.2.10 Orenburgburneft
7.2.11 Halliburton
7.2.12 Baker Hughes
7.2.13 Integra Group of Companies
7.2.14 OOO Service Drilling Company (former Sibneft-Bureniye)
7.2.15 OOO RN-Bureniye
7.2.16 Usinskgeoneft
7.2.17 Spets UBR UVAT
7.2.18 TNG-Lenburneft
7.2.19 L-Burenie
7.2.20 Burgaz
7.2.21 KCA Deutag Ltd. (Deutsche Tiefbohr-Aktiengesellschaft)
7.2.22 Orenburg drilling company
7.2.23 Tomskburneftegaz
7.2.24 OAO Slavneft-Megionneftegazgeologiya
7.2.25 Megionskoye UBR
7.2.26 Udmurtneft-burenie
7.2.27 MPK Aganneftegazgeologiya
7.2.28 Slavneft-Obneftegazgeologiya
7.2.29 Udmurtgeologiya
7.2.30 Sintez Group and ZAO Nizhnevartovsk Major Well Workovers
7.2.31 OOO Mamontovsky KRS
7.2.32 Oil Technology Overseas (OTO)
7.2.33 Neftserviceholding
7.2.34 OOO CATKoneft
7.2.35 ZAO MeKaMineft
7.2.36 Newco Well Service (Newco)
7.2.37 BJ Services Company
7.2.38 OAO Khantymansiyskgeofizika
7.2.39 OAO Bashneftegeofizika
7.2.40 OAO Sibneftegeofizika
7.2.41 OAO Krasnoyarskgeofizika
7.2.42 OAO Yeniseygeofizika
7.3 Estimates of the number of drill rigs
7.4 Comparative costs of workovers for largest oil companies
8 Key equipment suppliers
8.1 Drilling rig and hoist unit manufacturers
8.1.1 ZAO Uralmash
8.1.2 OOO Volgograd Drilling Equipment Plant
8.1.3 Mobile Drilling Systems
8.1.4 OAO Mashzavod
8.1.5 OAO Geomash
8.2 Manufacturers of pumps and drives for extraction of oil and gas
8.2.1 MC Borets
8.2.1 OAO ALNAS
8.2.2 ZAO Novomet-Perm and OOO Novomet-Servis
8.2.3 OAO Izhneftemash
8.2.4 Perm Oilfield Machinery Company
8.2.5 OAO Reduktor
8.3 Manufacturers of X-tree equipment for extraction of oil and gas (wellhead equipment, gate valves, etc.) 114
8.3.1 OAO Korvet
8.3.2 Yugokama
8.4 Cementing unit producers
8.4.1 Pervomayskkhimmash
9 Key factors influencing competitive environment
9.1 Oil industry regulation and taxation
9.1.1 Regulation
9.1.2 Taxation
9.2 Oil prices
10 Market forecast: physical volumes of oilfield services
10.1 Methodology
10.2 Forecast of physical volumes of the market of oilfield services
10.3 Forecast of requirements applied to capacities
11 Assessment of the volume of the oilfield services market
11.1 Assessment of the volume of the oilfield services market
11.1.1 Forecast of drilling segment development and its key components
11.1.2 Assessment of the fracturing treatment segment of the market
11.1.3 Assessment of sidetracking market segment
11.1.4 Assessment of the geophysical logging and seismic segments of the market
11.2 Market forecast by key regions
11.3 Anticipated growth of the market of key equipment
11.4 Assessment of specific expenditures for oilfield services

LIST OF FIGURES AND TABLES

Figure 7-1. Competitive environment in the oilfield service sector in Russia
Figure 7-2. Unit cost of services, 2005-2006 (US dollars per ton of produced oil)
Table 7-3. Key service contractors of Russian VIOCs
Figure 7-4. Market shares estimate for 2006
Table 7-5. Main capacities of Surgutneftegas in 2006
Figure 7-6. Horizontal wells drilled by Surgutneftegas and effect, 1995-2006 (units per year)
Figure 7-7. Fracturing operations by Surgutneftegas, 1995-2006 (units per year)
Figure 7-8. Fracturing treatment application by Surgutneftegas at existing wells and at new wells, 2001-2006 (units per year)
Figure 7-9. Effectiveness of coiled tubing units use at Surgutneftegas, 1995-2004 (thousands of tons)
Figure 7-10. Effects of well rehabilitation and sidetracking in Surgutneftegas, 1995-2005 (thousands of tons)
Table 7-11. Drilling performance of Tatneft-burenie, 2005-9/2007
Table 7-12. Recovery enhancement data for Tatneft-burenie, 2005-9/2007
Figure 7-13. Organizational structure of OAO Tatneft in 2005 (annual report)
Figure 7-14. Organizational structure of the well-workover and oil recovery enhancement service of Tatneft in 2005
Table 7-15. Main performance indices in the area of well servicing by Tatneft, 2004-2006
Table 7-16. Financial performance of Tatneft-burenie, 2002-2006 (thousands of US dollars)
Table 7-17. Main oilfield services capacities of BurKan at the beginning of 2007
Table 7-18. Financial performance of BurKan, 2002-2006 (thousands of US dollars)
Table 7-19. Main capacities of Ufa UBR in 2006
Table 7-20. Main assets of Neftekamsk UBR in 2006
Table 7-21. Financial performance of Neftekamsk UBR, 2002-2006 (thousands of dollars)
Table 7-22. Main assets used in service operations for Bashneft in 2006.
Figure 7-23. Revenues of Schlumberger and the share of the Russian business in the revenues of the company, 2002- 2005 (millions of US dollars on the left, and the share in % on the right)
Table 7-24. Schlumberger's main assets in 2007
Table 7-25. Drilling by Schlumberger in 2007 (thousands of meters)
Table 7-26. Main capacities of the PetroAlliance company in 2006
Figure 7-27. Number of well completions by drilling operations performed by PetroAlliance, 2002-2006
Table 7-28. Main capacities of the EDC at the beginning of 2007
Figure 7-29. Actual and estimated drill footage of EDC, 2001-2006 (thousands of meters)
Table 7-30. EDC's financial performance, 2002-2006 (thousands of US dollars)
Table 7-31. Main capacities of SSK at the beginning of 2006
Table 7-32. Financial performance of Siberian Service Company, 2003-2005 (thousands of US dollars)
Figure 7-33. Main assets of Nizhnevartovskburneft in 2006
Table 7-34. Financial performance of Nizhnevartovskburneft, 2002-2006 (thousands of US dollars)
Table 7-35. Main capacities of Burneft in 2006
Table 7-36. Financial performance of Burneft, 2001-2003 (thousands of US dollars)
Table 7-37. Main oil service assets of Orenburgburneft in 2007
Table 7-38. Financial performance of Orenburgburneft, 2002-2006 (thousands of US dollars)
Table 7-39. Estimated capacities of Halliburton in 2006
Figure 7-40. Published revenues data Baker Hughes in Russia and CIS , 2002-2007 (millions of US dollars)
Table 7-41. Financial performance of Integra group, 1H 2006-1H 2007 (thousands of US dollars)
Table 7-42. Operating data for Integra, 2005-1H 2007
Figure 7-43. Drilling by SBK, 2005-2007 (thousands of meters)
Table 7-44. Main oilfield services capacities of the Service Drilling Company at the beginning of 2006
Table 7-45. Financial performance of Service Drilling Company, 2002-2006 (thousands of US dollars)
Figure 7-46. Drilling by RN-Burenie, 2005-2007 (thousands of meters)
Table 7-47. Main oilfield service assets of RN-Burenie, 2006-2007
Table 7-48. Main oilfield services capacities of Purneftegaz-Bureniye in 2005
Table 7-49. Main oilfield services capacities of Krasnodarneftegaz-Siberia in 2005
Table 7-50. Main oilfield services capacities of Noglig UBR in 2005
Figure 7-51. Exploration drilling of Usinskgeoneft, 1988-2006 (thousands of meters)
Table 7-52. Financial performance of Usinskgeoneft, 2006-1Q 2007 (thousands of US dollars)
Figure 7-53. Spets UBR Uvat's stock of orders, 2004-2005
Figure 7-54. Spets UBR Uvat's drilling activities, 1995-2006 (thousands of meters)
Table 7-55. Main oilfield service assets of Spets UBR Uvat in 2006
Table 7-56. Main oilfield service assets of TNG-Lenburneft in 2006
Table 7-57. Drilling conducted by Burgaz through subsidiaries over the first 11 months of 2006
Figure 7-58. Drilling by Burgaz, 2002-2006 (thousands of meters)
Table 7-59. Main oilfield service capacities of Burgaz in 2006
Table 7-60. Main oilfield services capacities of KCA Deutag Ltd in 2007
Table 7-61. Operating drilling rigs of KCA Deutag for September 2007
Table 7-62. Main oilfield service capacities of Orenburg drilling company in 2007
Table 7-63. Financial performance of Orenburg Drilling Company, 2002-2006 (thousands of dollars)
Table 7-64. Main oilfield service assets of Tomskburneftegaz in 2007
Table 7-65. Financial performance of Tomskburneftegaz, 2004-9/2006 (thousands of US dollars)
Table 7-66. Operating data of Slavneft-Megioneftegazgeologiya, 2005-Q1 2007
Table 7-67. Main oilfield service capacities of Slavneft-Megionneftegazgeologiya in 2007
Table 7-68. Financial performance of Slavneft-Megionneftegazgeologiya, 2002-Q1 2007 (thousands of dollars)
Table 7-69. Main oilfield service assets of Megionskoye UBR in 2007
Table 7-70. Financial performance of Megionsk UBR, 2004-2006 (thousands of US dollars)
Table 7-71. Main oilfield service capacities of Udmurtneft-burenie in 2007
Table 7-72. Financial performance of Udmurtneft-burenie, 2002-2006 (thousands of US dollars)
Table 7-73. Drilling footage of Aganneftegazgeologiya, 2002-Q1 2007 (thousands of meters)
Table 7-74. Main oilfield service capacities of Aganneftegazgeologiya in 2007
Table 7-75. Financial performance of Aganneftegazgeologiya, 2002-2006 (thousands of US dollars)
Table 7-76. Financial performance of Slavneft-Obneftegazogeologiya, 2002-1H 2007 (thousands of US dollars)
Figure 7-77. Drilling volumes of OAO Udmurtgeologiya, 2001-2005 (thousands of meters)
Table 7-78. Financial performance of OAO Udmurtgeologiya, 2002-2006 (thousands of US dollars)
Table 7-79. Financial performance of Nizhnevartovskiy KRS, 2002-2006 (thousands of US dollars)
Table 7-80. Main oilfield services capacities of the OTO company in 2005
Table 7-81. Financial performance of Mamontovskiy KRS, 2002-2006 (thousands of US dollars)
Table 7-82. Main oilfield services capacities of the OTO company in 2005
Table 7-83. Main oilfield services capacities of Neftserviceholding at the beginning of 2006
Table 7-84 Main financial indices of the companies members of OOO Neftserviceholding, 2004-2005 (thousands of rubles)
Table 7-85. Main capacities of CATKoneft in 2005
Figure 7-86. Hydraulic fracturing performed by CATkoneft for main clients, 1991-2006 (number of operations)
Table 7-87. Financial performance of CATCOneft, 2002-2006 (thousands of US dollars)
Table 7-88. Main capacities of MeKaMineft in 1997
Table 7-89. Actual reported and estimated number of fracs performed by MeKaMineft, 1993-2004 (number of operations)
Table 7-90. Financial performance of MeKaMineft, 2002-2006 (thousands of dollars)
Figure 7-91. Performed operations by Newco Well Service, 2000-9/2006 (number of operations)
Table 7-92. Main capacities of Newco Well Service, 2004-2007
Table 7-93. Main capacities of BJ Service as in 2006
Table 7-94. Main financial indices of OAO Khantymansiyskgeofizika, 2000-2004 (thousands of US dollars)
Table 7-95. Main financial indices of OAO Bashneftegeofizika, 2000-2004 (thousands of US dollars)
Table 7-96. Main financial indices of OAO Sibneftegeofizika, 2000-2004 (thousands of US dollars)
Table 7-97. Main financial indices of OAO Krasnoyarskgeofizika, 2000-2004 (thousands of US dollars)
Table 7-98. Main financial indices of OAO Yeniseygeofizika, 2000-2004 (thousands of US dollars)
Table 7-99. Performance indices of the use of drilling capacities in 2006
Figure 7-100. Footage per drilling crew by companies in 2006
Figure 7-101. Costs of one crew-hour on well servicing by companies (light workovers), 2002-2006 (dollars per hour)
Figure 7-102. Cost of one crew-hour on well workover by companies, 2002-2006 (US dollars per hour)
Figure 7-103. Apparent revenues per well-servicing crew, 2002-2006 (thousands of US dollars per hour)
Figure 7-104. Apparent revenues per well-workover crew, 2002-2006 (thousands of US dollars per hour)
Figure 8-1. Production of drilling rigs as per Rosstat statistics, 2001-2006 (numbers of units)
Figure 8-2. Production of workover rigs as per Rosstat statistics, 2001-2006 (number of units)
Figure 8-3. Production of drilling rigs by Uralmash as reported to Rosstat, 2001-2006 (number of units)
Table 8-4. Stationery drilling rigs manufactured by the Volgograd Drilling Equipment Plant
Table 8-5. Mobile drilling rigs manufactured by the Volgograd Drilling Equipment Plant
Figure 8-6. Production of drilling rigs by Volgograd Drilling Equipment Plant as reported to Rosstat, 2001-2006 (number of units)
Table 8-7. Gains and losses of the Volgograd Plant of Drilling Equipment, 2002-2006 (thousands of US dollars)
Figure 8-8. Production of hoist systems by Kungur Machine-Building Equipment Plant as reported to Rosstat, 2001- 2006 (number of units)
Table 8-9. Financial performance of Kungur Machine Building Plant, 2002-2006 (thousands of US dollars)
Figure 8-10. Production of hoist systems by Ishimbai machine building plant as reported to Rosstat, 2001-2006 (number of units)
Table 8-11. Financial performance of Ishimbai machine building plant,2002-2006 (thousands of US dollars)
Figure 8-12. Production of workover rigs by OAO Mashzavod as reported to Rosstat, 2001-2006 (number of units)
Table 8-13. OAO Mashzavod profits and losses, 2001-2005 (millions of US dollars)
Figure 8-14. Production of workover rigs by OAO Geomash as reported to Rosstat, 2001-2006 (number of units)100
Table 8-15. Financial performance of Geomash, 2002-2006 (thousands of US dollars)
Figure 8-16. ESP production by major manufacturers in the Russian Federation as per Rosstat statistics, 2001-2006 (number of units)
Figure 8-17. ESP production by major manufacturers in the Russian Federation as per Rosstat statistics and production wells equipped with ESP, 2001-2006
Figure 8-18 Official reporting and estimated production of ESP, 2001-2006 (number of units)
Figure 8-19. Bottom-hole pump production in Russia as reported to Rosstat, 2001-2006 (number of units)
Figure 8-20. Bottom-hole pump production by main Russian manufacturers as reported to Rosstat and production wells with bottom-hole pumps, 2000-2006 (number of units)
Figure 8-21. Jack-up production by main manufacturers in Russia as reported to Rosstat, 2001-2006 (number of units)
Figure 8-22. Production of ESP by Borets as reported to Rosstat, 2001-2006 (number of units)
Table 8-23. Gains and losses of Borets, 2002-2006 (thousands of dollars)
Figure 8-24. Production ESP by Lemaz as reported to Rosstat, 2001-2006 (number of units)
Table 8-25. Key customers for Lemaz core products in, 2000-2003 (%)
Table 8-26. Financial performance of Lemaz, 2002-2006 (thousands of US dollars)
Figure 8-27. Production of electrical submersible pumps by ALNAS as reported to Rosstat, 2001-2006 (number of units)
Table 8-28. Gains and losses of ALNAS, 2001-1half 2007 (thousands of US dollars)
Figure 8-29. Deep seated sucker rod pump production at Izhneftemash as reported to Rosstat, 2001-2006 (number of units)
Figure 8-30. Cementing unit and jack-up rig production at Izhneftemash as reported to Rosstat, 2001-2006 (number of units)
Table 8-31. Financial performance of Izhneftemash, 2001-2006 (thousands of US dollars)
Figure 8-32. Deep seated sucker rod production at Perm Oilfield Machinery Company as reported to Rosstat, 2002- 2006 (number of units)
Table 8-33. Financial performance of the Perm Oilfield Machinery Company, 2001-2006 (thousands of US dollars)
Figure 8-34. Production of the beam pump surface units by Reduktor as reported to Rosstat, 2001-2006 (number of units)
Table 8-35. Financial performance of Reduktor, 2001-2006 (thousands of US dollars)
Figure 8-36. Major manufacturers of Christmas trees for the oil industry as reported to Rosstat, 2001-2006 (number of units)
Figure 8-37. Commissioning of new wells and apparent wellhead assembly replacement, 2001-2006 (number of units)
Figure 8-38. Korvet pipe valves production data as reported to Rosstat, 2001-2006 (number of units)
Table 8-39. Financial performance of Korvet, 2002-2006 (thousands of US dollars)
Table 8-40. Financial performance of Yugokama, 2004-2006 (thousands of US dollars)
Figure 8-41. Cementing unit production by main producers as reported to Rosstat, 2001-2006 (number of units)
Figure 8-42. Cementing unit production at Pervomaiskkhimmash as reported to Rosstat, 2001-2006 (number of units)
Table 8-43. Financial performance of Pervomaiskkhimmash, 2001-2006 (thousands of US dollars)
Figure 9-1. Urals price, mineral resource extraction tax (NDPI), export duty for oil (dollars per ton, left scale) and the share of the NDPI and export duty in the Urals price (% right scale), 2003-(10 months)2005
Figure 9-2. Oil price projections under the EIA scenario, 2006-2015 (US dollars per barrel)
Table 10-1. Key forecast parameters for 2005-2015 (excluding offshore)
Figure 10-2. Oil and gas condensate production in Russia, 2006-2015 (millions of tons)
Figure 10-3. Incremental production by key regions, 2007-2015, millions tons (2006 base year)
Figure 10-4. Estimated decline rate of the base production in key regions in, 2004-2006
Figure 10-5. Forecast of the number of fracturing-treatment operations in Russia, 2007-2015 (number of units)
Figure 10-6. Forecast of the number and flow rates of sidetracking in Russia, 2006-2015 (number of units)
Figure 10-7. Forecast of the effectiveness of the activities aimed at an impact on the effective drainage area and artificial lift optimization, 2007-2015 (thousands of tons)
Figure 10-8. Forecast of growth due to drilling (tons a year) and the average flow rate of new wells, 2007-2015 (tons per day)
Figure 10-9. Forecast of the number of well-servicing and workover operations and the dynamics of the producing well stock, 2007-2015
Figure 10-10. Forecast of the annualized growth in the sources of growth in production (excluding offshore), 2007- 2015 (millions of tons)
Figure 10-11. Forecasts of drill footage and production wells completions in Russia, 2006-2015
Figure 10-12. Forecast of drill footage in the major production regions, 2007-2015 (thousands of meters)
Figure 10-13. Forecast of the growth in the number of drill crews and footage per one crew, 2006-2015
Figure 10-14. Forecast of drilling rigs stock, 2007-2015 (number of units)
Figure 10-15. Forecast of drill rigs procurement, 2007-2015 (number of units)
Figure 10-16. Forecast of the growth in well-servicing and workover crews and incremental annual supply of workover rigs, 2007-2015
Figure 10-17. Forecast of the needs for workover rigs, 2007-2015
Figure 10-18. Forecast of producing wells with ESP Systems and ESP Systems sales, 2006-2015
Figure 10-19. Forecast of need in wellhead and Christmas tree fittings, 2006-2015 (number of units)
Figure 11-1. Anticipated dynamics of the oilfield services market in Russia, 2006-2015 (millions of US dollars nominal)
Figure 11-2. Anticipated contribution of the major segments into the oilfield services market increase in Russia, 2007-2015 (%)
Figure 11-3. Anticipated annual average growth in different segments of the market, 2006-2015 (%)
Figure 11-4. Anticipated dynamics of key segments in drilling in Russia, 2006-2015 (millions of US dollars)
Figure 11-5. Anticipated dynamics of the fracturing treatment segment of the market in Russia, 2006-2015 (millions of US dollars)
Figure 11-6. Anticipated dynamics of the market segment for sidetracking of idle wells in Russia, 2006-2015 (millions of US dollars)
Figure 11-7. Anticipated dynamics of the logging and seismic segments of the market in Russia, 2006-2015 (millions of US dollars)
Figure 11-8. Anticipated dynamics of the market by the major regions, 2006-2015 (millions of US dollars)
Figure 11-9. Anticipated shares of the market of the major regions, 2006-2015 (%)
Figure 11-10. Anticipated incremental to the market level of 2006 by major categories
Figure 11-11. Anticipated oilfield services expenses per ton of production (left hand scale) and per barrel (right hand scale), 2006-2015 (US dollars per ton)

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