Over the past 20 years, RPI has carried out hundreds of studies on all major segments of the oil and gas industry of Russia, CIS and Eastern Europe.
RPI specialists are permanently in close connect with the industry and monitor its developments closely to provide best-in-class analytics and information support for industry players.
RPI specialists are permanently in close connect with the industry and monitor its developments closely to provide best-in-class analytics and information support for industry players.
Having enjoyed its record growth in 2006-2007 the OFS market in Russia is presently struggling to survive within the changed business environment caused by the global economic downturn.
To keep industry players informed of the latest structural developments in the Russian OFS RPI has prepared four reports which analyze key factors that shaped the market in 2009 with detailed examination of particular market segments, regions and key players.
Russian Oilfield Services Market: Latest Developments 2008-2009 examines factors that influenced the market development from 2008 year-end up to the end of the second quarter of 2009.
Russian Oilfield Services Market: Latest Developments 2008-2009 offers analysis of key market indicators by:
To keep industry players informed of the latest structural developments in the Russian OFS RPI has prepared four reports which analyze key factors that shaped the market in 2009 with detailed examination of particular market segments, regions and key players.
Russian Oilfield Services Market: Latest Developments 2008-2009 examines factors that influenced the market development from 2008 year-end up to the end of the second quarter of 2009.
Russian Oilfield Services Market: Latest Developments 2008-2009 offers analysis of key market indicators by:
- production regions
- operating companies
- oilfield services companies
- oil production
- drilling (exploration and production)
- well stock
- well workover
- hydraulic fracturing
- bottom-hole treatment
- artificial lift optimization
- oil production
- drilling
- capital costs
Introduction
Chapter 1. Oil Production in Russia
1.1 Production by vertically integrated companies (VIOCs) and independent operators
1.3 Capital costs by VIOC: volumes per ton of produced oil
Chapter 2. Drilling, well workover and well stock by VIOC
2.1 Production drilling and well stock
Chapter 3. Intensification methods by VIOC (2001-2008, H1 2009 compared to H1 2008, Q2 2009 compared to Q1 2009)
3.1 Hydraulic fracturing
Chapter 1. Oil Production in Russia
1.1 Production by vertically integrated companies (VIOCs) and independent operators
- production dynamics
- 2001-2008
- H1 2009 compared to H1 2008
- Q2 2009 compared to Q1 2009
- key current and prospective production projects
1.3 Capital costs by VIOC: volumes per ton of produced oil
- 2001-2008
- H1 2009 compared to H1 2008
- Q2 2009 compared to Q1 2009
- 2001-2008
- H1 2009 compared to H1 2008
Chapter 2. Drilling, well workover and well stock by VIOC
2.1 Production drilling and well stock
- key production projects in terms of drilling volumes
- capital costs efficiency per drilling footage
- 2001-2008
- H1 2009 compared to H1 2008
- Q2 2009 compared to Q1 2009
- drilling footage
- 2001-2008
- H1 2009 compared to H1 2008
- Q2 2009 compared to Q1 2009
- growth dynamics of new production wells
- 2001-2008
- H1 2009 compared to H1 2008
- production well stock: usage efficiency (% of active wells)
- 2001-2008
- H1 2009 compared to H1 2008
- estimated daily flow rates (by new wells and total well stock)
- 2001-2008
- H1 2009 compared to H1 2008
- key production projects in terms of drilling volumes; reserves growth indicators
- capital costs efficiency per drilling footage
- 2001-2008
- H1 2009 compared to H1 2008
- Q2 2009 compared to Q1 2009
- drilling footage
- 2001-2008
- H1 2009 compared to H1 2008
- Q2 2009 compared to Q1 2009
- dynamics of operations
- average cost of operation
- number of crews and their performance (number of operations per crew per year)
Chapter 3. Intensification methods by VIOC (2001-2008, H1 2009 compared to H1 2008, Q2 2009 compared to Q1 2009)
3.1 Hydraulic fracturing
- dynamics of operations
- efficiency of operations and average flow rate growth per operation
- dynamics of operations
- efficiency of operations and average flow rate growth per operation
- dynamics of operations
- efficiency of operations and average flow rate growth per operation
Figure 1.1. Oil production in Russia by company, from 2001 to 2008, thousand tons
Figure 1.2. Oil production in the Russian Federation, H1 2008 and H1 2009, thousand tons
Figure 1.3. Oil production in the Russian Federation by company, Q1and Q2 2009, thousand tons
Figure 1.4. The structure of aggregate oil production by VIOC in the Russian Federation, 2006 through 2008, thousand tons
Figure 1.5. The oil production structure in the Russian Federation in 2006 by VIOC, thousand tons
Figure 1.6. The structure of oil production in the Russian Federation in 2007 by VIOC, thousand tons
Figure 1.7. The structure of oil production in the Russian Federation in 2008 by VIOC, thousand tons
Figure 1.8. The structure of aggregate oil production of VIOCs in the Russian Federation, H1 2008 and H1 2009, thousand tons
Figure 1.9. The structure of oil production in the Russian Federation by VIOC in H1 2008, thousand tons
Figure 1.10. The structure of oil production in the Russian Federation by VIOC in H1 2009 thousand tons
Figure 1.11. Comparison of total investments in oil production in the Russian Federation by VIOC, H1 2008 and H1 2009, RUR million
Figure 1.12. Comparison of capital investments per extracted ton of oil in the Russian Federation by VIOC, H1 2008 and H1 2009
Figure 1.13. Comparison of total capital investments in oil production by VIOCs in the Russian Federation, Q1 and Q2 2009, RUR million
Figure 1.14. Comparison of capital investments per extracted ton in the Russian Federation by VIOC, Q1 and Q2 2009, RUR million
Figure 1-15. Crude oil export duty per ton from 2002 to 2009, $
Figure 2.1. Production drilling capital expenditures by Russian VIOC, RUR million, H1 2008 and 2009
Figure 2.2. Comparison of capital expenditures in production drilling per meter of drilling by Russian VIOC, RUR million, H1 2008 and H1 2009
Figure 2.3. Production drilling capital expenditures by Russian VIOC, RUR million, Q1 and Q2 2009
Figure 2.4. Comparison of capital investments per meter of production drilling by Russian VIOC, RUR million, Q1 and Q2 2009
Figure 2.5. Production drilling volumes by Russian company, thousand meters, from 2001 to 2008
Figure 2.6. Production drilling volumes by Russian company, thousand meters, H1 2008 and H1 2009
Figure 2.7. Production drilling volumes by Russian companies, thousand meters, Q1 and Q2 2009
Figure 2.8. Introduction of new production wells by Russian VIOC, wells, from 2001 to 2008
Figure 2.9. Introduction of new production wells by Russian VIOC, wells, H1 2008 and H1 2009
Figure 2.10. Dynamics of development well stocks by Russian VIOCs, wells, from 2001 to 2008
Figure 2.11. Dynamics of production well stocks by Russian VIOC, wells, from 2001 to 2008
Figure 2.12. Effectiveness of wells stocks usage by VIOC, %, from 2001 to 2008
Figure 2.13. Estimated flow rates at development wells by VIOC, tons per day, from 2001 to 2008
Figure 2.14. Estimated flow rates at development wells by VIOC, tons per day, first 6 months of 2008 and 2009
Figure 2.15. Estimated flow rates at new development wells by VIOC, tons per day, from 2001 to 2008
Figure 2.16. Estimated flow rates at new development wells by VIOCs, tons per day, H1 2008 and H1 2009
Figure 2.17. Capital expenditures in exploration drilling by Russian VIOCs, RUR million, first 6 months of 2008 and 2009
Figure 2.18. Capital investments in exploration drilling per meter of drilling by Russian VIOCs, RUR million, H1 2008 and 2009
Figure 2.19. Capital investments in exploration drilling by Russian VIOCs, RUR million, Q1 and Q2 2009
Figure 2.20. Capital investments ino exploration drilling per meter of drilling by Russian VIOC, RUR million, Q1 and Q2 2009
Figure 2.21. Exploration drilling volumes by Russian VIOC, thousand meters, from 2001 to 2008
Figure 2.22. Exploration drilling volumes by Russian VIOC, thousand meters, H1 2008 and 2009
Figure 2.23. Exploration drilling volumes by Russian VIOC, thousand meters, Q1 and Q2 2009
Figure 2.24. Number of WO operations by Russian VIOC, from 2001 to 2008
Figure 2.25. Cost of WO by Russian VIOC, RUR million, from 2001 to 2008
Figure 2.26. Average cost of WO operation by Russian VIOC, RUR thousand, from 2001 to 2008
Figure 2.27. Average number of operating workover teams by Russian VIOCs, from 2001 to 2008
Figure 2.28. Number of operations per workover team per year, from 2001 to 2008
Figure 3.1. Number of fracturing operations in the Russian Federation by VIOC, from 2001 to 2008
Figure 3.2. Efficiency of fracturing in the Russian Federation performed by VIOCs, thousand tons, from 2001 to 2008
Figure 3.3. Designed efficiency per fracturing operation by VIOC, thousand tons, from 2001 to 2008
Figure 3.5. Efficiency of fracturing operations in the Russian Federation by VIOC, thousand tons, H1 2008 and H1 2009
Figure 3.6. Designed efficiency per fracturing operation by VIOC, thousand tons, H1 2008 and H1 2009
Figure 3.7. Number of fracturing operations in the Russian Federation by VIOC, Q1 and Q2 2009
Figure 3.8. Efficiency of fracturing operations in the Russian Federation by VIOC, thousand tons, Q1 and Q2 2009
Figure 3.9. Specific efficiency of one fracturing operation by VIOC, thousand tons, Q1 and Q2 2009
Figure 3.10. Number of well operation optimization activities in the Russian Federation per VIOC, from 2001 to 2008
Figure 3.11. Efficiency of well operation optimization activities in the Russian Federation by VIOC, from 2001 to 2008
Figure 3.12. Designed efficiency of well operation optimization activities per well in the Russian Federation by VIOC, from 2001 to 2008
Figure 3.13. Number of well operation optimization activities in the Russian Federation by VIOC, H1 2008 and H1 2009
Figure 3.14. Efficiency of well operation optimization activities in the Russian Federation by VIOC, thousand tons, H1 2008 and H1 2009
Figure 3.15. Designed efficiency of well operation optimization activity per well in the Russian Federation by VIOC, thousand tons, fist half of 2008 and 2009
Figure 3.16. Number of operations on well optimization in the Russian Federation by VIOC, Q1 and Q2 2009
Figure 3.17. Efficiency of well operation optimization activities in the Russian Federation by VIOC, Q1 and Q2 2009
Figure 3.18. Designed efficiency of well operation optimization activities per well in the Russian Federation by VIOC, Q1 and Q2 2009
Figure 3.19. The number of bottom hole stimulation operations in the Russian Federation by VIOC, from 2001 to 2008
Figure 3.20. Total efficiency of bottom hole stimulation in the Russian Federation by VIOC, from 2001 to 2008
Figure 3.21. Designed efficiency of bottom hole stimulation per well in the Russian Federation by VIOC, from 2001 to 2008
Figure 3.22. The number of bottom hole stimulation operations in the Russian Federation by VIOC, H1 2008 and H12009
Figure 3.23. The total efficiency of bottom hole stimulation operations in the Russian Federation by VIOC, thousand tons, H1 2008 and 2009
Figure 3.24. Designed efficiency of bottom hole stimulation per well in the Russian Federation by VIOC, thousand tons, H1 2008 and H1 2009
Figure 3.25. The number of bottom hole stimulation operations in the Russian Federation by VIOC, Q1 and Q2 of 2009
Figure 3.26. Total efficiency of bottom hole stimulation operations in the Russian Federation by VIOC, thousand tons, Q1 and Q2 of 2009
Figure 3.27. Designed efficiency of bottom hole stimulation operations in the Russian Federation by VIOC, thousand tons, Q1 and Q2 of 2009
Figure 1.2. Oil production in the Russian Federation, H1 2008 and H1 2009, thousand tons
Figure 1.3. Oil production in the Russian Federation by company, Q1and Q2 2009, thousand tons
Figure 1.4. The structure of aggregate oil production by VIOC in the Russian Federation, 2006 through 2008, thousand tons
Figure 1.5. The oil production structure in the Russian Federation in 2006 by VIOC, thousand tons
Figure 1.6. The structure of oil production in the Russian Federation in 2007 by VIOC, thousand tons
Figure 1.7. The structure of oil production in the Russian Federation in 2008 by VIOC, thousand tons
Figure 1.8. The structure of aggregate oil production of VIOCs in the Russian Federation, H1 2008 and H1 2009, thousand tons
Figure 1.9. The structure of oil production in the Russian Federation by VIOC in H1 2008, thousand tons
Figure 1.10. The structure of oil production in the Russian Federation by VIOC in H1 2009 thousand tons
Figure 1.11. Comparison of total investments in oil production in the Russian Federation by VIOC, H1 2008 and H1 2009, RUR million
Figure 1.12. Comparison of capital investments per extracted ton of oil in the Russian Federation by VIOC, H1 2008 and H1 2009
Figure 1.13. Comparison of total capital investments in oil production by VIOCs in the Russian Federation, Q1 and Q2 2009, RUR million
Figure 1.14. Comparison of capital investments per extracted ton in the Russian Federation by VIOC, Q1 and Q2 2009, RUR million
Figure 1-15. Crude oil export duty per ton from 2002 to 2009, $
Figure 2.1. Production drilling capital expenditures by Russian VIOC, RUR million, H1 2008 and 2009
Figure 2.2. Comparison of capital expenditures in production drilling per meter of drilling by Russian VIOC, RUR million, H1 2008 and H1 2009
Figure 2.3. Production drilling capital expenditures by Russian VIOC, RUR million, Q1 and Q2 2009
Figure 2.4. Comparison of capital investments per meter of production drilling by Russian VIOC, RUR million, Q1 and Q2 2009
Figure 2.5. Production drilling volumes by Russian company, thousand meters, from 2001 to 2008
Figure 2.6. Production drilling volumes by Russian company, thousand meters, H1 2008 and H1 2009
Figure 2.7. Production drilling volumes by Russian companies, thousand meters, Q1 and Q2 2009
Figure 2.8. Introduction of new production wells by Russian VIOC, wells, from 2001 to 2008
Figure 2.9. Introduction of new production wells by Russian VIOC, wells, H1 2008 and H1 2009
Figure 2.10. Dynamics of development well stocks by Russian VIOCs, wells, from 2001 to 2008
Figure 2.11. Dynamics of production well stocks by Russian VIOC, wells, from 2001 to 2008
Figure 2.12. Effectiveness of wells stocks usage by VIOC, %, from 2001 to 2008
Figure 2.13. Estimated flow rates at development wells by VIOC, tons per day, from 2001 to 2008
Figure 2.14. Estimated flow rates at development wells by VIOC, tons per day, first 6 months of 2008 and 2009
Figure 2.15. Estimated flow rates at new development wells by VIOC, tons per day, from 2001 to 2008
Figure 2.16. Estimated flow rates at new development wells by VIOCs, tons per day, H1 2008 and H1 2009
Figure 2.17. Capital expenditures in exploration drilling by Russian VIOCs, RUR million, first 6 months of 2008 and 2009
Figure 2.18. Capital investments in exploration drilling per meter of drilling by Russian VIOCs, RUR million, H1 2008 and 2009
Figure 2.19. Capital investments in exploration drilling by Russian VIOCs, RUR million, Q1 and Q2 2009
Figure 2.20. Capital investments ino exploration drilling per meter of drilling by Russian VIOC, RUR million, Q1 and Q2 2009
Figure 2.21. Exploration drilling volumes by Russian VIOC, thousand meters, from 2001 to 2008
Figure 2.22. Exploration drilling volumes by Russian VIOC, thousand meters, H1 2008 and 2009
Figure 2.23. Exploration drilling volumes by Russian VIOC, thousand meters, Q1 and Q2 2009
Figure 2.24. Number of WO operations by Russian VIOC, from 2001 to 2008
Figure 2.25. Cost of WO by Russian VIOC, RUR million, from 2001 to 2008
Figure 2.26. Average cost of WO operation by Russian VIOC, RUR thousand, from 2001 to 2008
Figure 2.27. Average number of operating workover teams by Russian VIOCs, from 2001 to 2008
Figure 2.28. Number of operations per workover team per year, from 2001 to 2008
Figure 3.1. Number of fracturing operations in the Russian Federation by VIOC, from 2001 to 2008
Figure 3.2. Efficiency of fracturing in the Russian Federation performed by VIOCs, thousand tons, from 2001 to 2008
Figure 3.3. Designed efficiency per fracturing operation by VIOC, thousand tons, from 2001 to 2008
Figure 3.5. Efficiency of fracturing operations in the Russian Federation by VIOC, thousand tons, H1 2008 and H1 2009
Figure 3.6. Designed efficiency per fracturing operation by VIOC, thousand tons, H1 2008 and H1 2009
Figure 3.7. Number of fracturing operations in the Russian Federation by VIOC, Q1 and Q2 2009
Figure 3.8. Efficiency of fracturing operations in the Russian Federation by VIOC, thousand tons, Q1 and Q2 2009
Figure 3.9. Specific efficiency of one fracturing operation by VIOC, thousand tons, Q1 and Q2 2009
Figure 3.10. Number of well operation optimization activities in the Russian Federation per VIOC, from 2001 to 2008
Figure 3.11. Efficiency of well operation optimization activities in the Russian Federation by VIOC, from 2001 to 2008
Figure 3.12. Designed efficiency of well operation optimization activities per well in the Russian Federation by VIOC, from 2001 to 2008
Figure 3.13. Number of well operation optimization activities in the Russian Federation by VIOC, H1 2008 and H1 2009
Figure 3.14. Efficiency of well operation optimization activities in the Russian Federation by VIOC, thousand tons, H1 2008 and H1 2009
Figure 3.15. Designed efficiency of well operation optimization activity per well in the Russian Federation by VIOC, thousand tons, fist half of 2008 and 2009
Figure 3.16. Number of operations on well optimization in the Russian Federation by VIOC, Q1 and Q2 2009
Figure 3.17. Efficiency of well operation optimization activities in the Russian Federation by VIOC, Q1 and Q2 2009
Figure 3.18. Designed efficiency of well operation optimization activities per well in the Russian Federation by VIOC, Q1 and Q2 2009
Figure 3.19. The number of bottom hole stimulation operations in the Russian Federation by VIOC, from 2001 to 2008
Figure 3.20. Total efficiency of bottom hole stimulation in the Russian Federation by VIOC, from 2001 to 2008
Figure 3.21. Designed efficiency of bottom hole stimulation per well in the Russian Federation by VIOC, from 2001 to 2008
Figure 3.22. The number of bottom hole stimulation operations in the Russian Federation by VIOC, H1 2008 and H12009
Figure 3.23. The total efficiency of bottom hole stimulation operations in the Russian Federation by VIOC, thousand tons, H1 2008 and 2009
Figure 3.24. Designed efficiency of bottom hole stimulation per well in the Russian Federation by VIOC, thousand tons, H1 2008 and H1 2009
Figure 3.25. The number of bottom hole stimulation operations in the Russian Federation by VIOC, Q1 and Q2 of 2009
Figure 3.26. Total efficiency of bottom hole stimulation operations in the Russian Federation by VIOC, thousand tons, Q1 and Q2 of 2009
Figure 3.27. Designed efficiency of bottom hole stimulation operations in the Russian Federation by VIOC, thousand tons, Q1 and Q2 of 2009
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