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.
Oilfield Services Market of the Volga-Urals Region 2009 report examines current development trends in the oilfield services segment of one of the oldest oil provinces characterized by high reserves depletion and burning demand for service technologies to preserve sustainable crude output.
Oilfield Services Market of the Volga-Urals Region 2009 offers analysis of key market segments:
The report offers a year-by-year (2001-2008) and half-year (H1 2008 and H1 2009) comparisons of:
Oilfield Services Market of the Volga-Urals Region 2009 offers analysis of key market segments:
- on a regional basis
- by operating companies
The report offers a year-by-year (2001-2008) and half-year (H1 2008 and H1 2009) comparisons of:
- oil production
- drilling (exploration and production)
- well stock
- well workover
- hydraulic fracturing
- bottom-hole treatment
- artificial lift optimization
1 Introduction
2 Oilfield Service Operations in the Volga-Urals
2.1 Oil production
2.2 Capital expenditures in oil production
2.3 Oil production structure
2.4 Production drilling
2.5 Well stocks
2.6 Well flow rates
2.7 Production drilling capital expenditures
2.8 Exploration drilling
2.9 Capital expenditures in exploration drilling
2.10 Well workover
2.11 Hydraulic fracturing
2.12 Bottomhole stimulation
2.13 Artificial lift optimization
3 Oil Producer’s Operations in the Region
3.1 Tatneft
3.1.1 Regional oil production
3.1.2 Capital expenditures in oil production
3.1.3 Oil production structure
3.1.4 Production drilling and well stocks
3.1.5 Well flow rates
3.1.6 Exploration drilling
3.1.7 Capital expenditures in drilling
3.1.8 Well workover
3.1.9 Hydraulic fracturing
3.1.10 Bottomhole stimulation
3.1.11 Artificial lift optimization
3.1.12 Production effect from jobs
3.2 LUKOIL
3.2.1 Regional oil production
3.2.2 Capital expenditures in oil production
3.2.3 Oil production structure
3.2.4 Production drilling and well stocks
3.2.5 Well flow rates
3.2.6 Exploration drilling
3.2.7 Capital expenditures in drilling
3.2.8 Well workover
3.2.9 Hydraulic fracturing
3.2.10 Bottomhole stimulation
3.2.11 Artificial lift optimization
3.2.12 Production effect from jobs
3.3 TNK-BP
3.3.1 Regional oil production
3.3.2 Capital expenditures in oil production
3.3.3 Oil production structure
3.3.4 Production drilling and well stocks
3.3.5 Well flow rates
3.3.6 Exploration drilling
3.3.7 Capital expenditures in drilling
3.3.8 Well workover
3.3.9 Hydraulic fracturing
3.3.10 Bottomhole stimulation
3.3.11 Artificial lift optimization
3.3.12 Production effect from jobs
3.4 Rosneft
3.4.1 Regional oil production
3.4.2 Capital expenditures in oil production
3.4.3 Oil production structure
3.4.4 Production drilling and well stocks
3.4.5 Well flow rates
3.4.6 Exploration drilling
3.4.7 Capital expenditures in drilling
3.4.8 Well workover
3.4.9 Hydraulic fracturing
3.4.10 Bottomhole stimulation
3.4.11 Artificial lift optimization
3.4.12 Production effect from jobs
3.5 Bashneft
3.5.1 Regional oil production
3.5.2 Capital expenditures in oil production
3.5.3 Oil production structure
3.5.4 Production drilling and well stocks
3.5.5 Well flow rates
3.5.6 Exploration drilling
3.5.7 Capital expenditures in drilling
3.5.8 Well workover
3.5.9 Hydraulic fracturing
3.5.10 Bottomhole stimulation
3.5.11 Artificial lift optimization
3.5.12 Production effect from jobs
3.6 Russneft
3.6.1 Regional oil production
3.6.2 Capital expenditures in oil production
3.6.3 Oil production structure
3.6.4 Production drilling and well stocks
3.6.5 Well flow rates
3.6.6 Exploration drilling
3.6.7 Capital expenditures in drilling
3.6.8 Well workover
3.6.9 Hydraulic fracturing
3.6.10 Bottomhole stimulation
3.6.11 Artificial lift optimization
3.6.12 Production effect from jobs
3.7 Independent companies
3.7.1 Regional oil production
3.7.2 Capital expenditures in oil production
3.7.3 Oil production structure
3.7.4 Production drilling and well stocks
3.7.5 Well flow rates
3.7.6 Exploration drilling
3.7.7 Capital expenditures in drilling
3.7.8 Well workover
3.7.9 Hydraulic fracturing
3.7.10 Bottomhole stimulation
3.7.11 Artificial lift optimization
3.7.12 Production effect from jobs
2 Oilfield Service Operations in the Volga-Urals
2.1 Oil production
2.2 Capital expenditures in oil production
2.3 Oil production structure
2.4 Production drilling
2.5 Well stocks
2.6 Well flow rates
2.7 Production drilling capital expenditures
2.8 Exploration drilling
2.9 Capital expenditures in exploration drilling
2.10 Well workover
2.11 Hydraulic fracturing
2.12 Bottomhole stimulation
2.13 Artificial lift optimization
3 Oil Producer’s Operations in the Region
3.1 Tatneft
3.1.1 Regional oil production
3.1.2 Capital expenditures in oil production
3.1.3 Oil production structure
3.1.4 Production drilling and well stocks
3.1.5 Well flow rates
3.1.6 Exploration drilling
3.1.7 Capital expenditures in drilling
3.1.8 Well workover
3.1.9 Hydraulic fracturing
3.1.10 Bottomhole stimulation
3.1.11 Artificial lift optimization
3.1.12 Production effect from jobs
3.2 LUKOIL
3.2.1 Regional oil production
3.2.2 Capital expenditures in oil production
3.2.3 Oil production structure
3.2.4 Production drilling and well stocks
3.2.5 Well flow rates
3.2.6 Exploration drilling
3.2.7 Capital expenditures in drilling
3.2.8 Well workover
3.2.9 Hydraulic fracturing
3.2.10 Bottomhole stimulation
3.2.11 Artificial lift optimization
3.2.12 Production effect from jobs
3.3 TNK-BP
3.3.1 Regional oil production
3.3.2 Capital expenditures in oil production
3.3.3 Oil production structure
3.3.4 Production drilling and well stocks
3.3.5 Well flow rates
3.3.6 Exploration drilling
3.3.7 Capital expenditures in drilling
3.3.8 Well workover
3.3.9 Hydraulic fracturing
3.3.10 Bottomhole stimulation
3.3.11 Artificial lift optimization
3.3.12 Production effect from jobs
3.4 Rosneft
3.4.1 Regional oil production
3.4.2 Capital expenditures in oil production
3.4.3 Oil production structure
3.4.4 Production drilling and well stocks
3.4.5 Well flow rates
3.4.6 Exploration drilling
3.4.7 Capital expenditures in drilling
3.4.8 Well workover
3.4.9 Hydraulic fracturing
3.4.10 Bottomhole stimulation
3.4.11 Artificial lift optimization
3.4.12 Production effect from jobs
3.5 Bashneft
3.5.1 Regional oil production
3.5.2 Capital expenditures in oil production
3.5.3 Oil production structure
3.5.4 Production drilling and well stocks
3.5.5 Well flow rates
3.5.6 Exploration drilling
3.5.7 Capital expenditures in drilling
3.5.8 Well workover
3.5.9 Hydraulic fracturing
3.5.10 Bottomhole stimulation
3.5.11 Artificial lift optimization
3.5.12 Production effect from jobs
3.6 Russneft
3.6.1 Regional oil production
3.6.2 Capital expenditures in oil production
3.6.3 Oil production structure
3.6.4 Production drilling and well stocks
3.6.5 Well flow rates
3.6.6 Exploration drilling
3.6.7 Capital expenditures in drilling
3.6.8 Well workover
3.6.9 Hydraulic fracturing
3.6.10 Bottomhole stimulation
3.6.11 Artificial lift optimization
3.6.12 Production effect from jobs
3.7 Independent companies
3.7.1 Regional oil production
3.7.2 Capital expenditures in oil production
3.7.3 Oil production structure
3.7.4 Production drilling and well stocks
3.7.5 Well flow rates
3.7.6 Exploration drilling
3.7.7 Capital expenditures in drilling
3.7.8 Well workover
3.7.9 Hydraulic fracturing
3.7.10 Bottomhole stimulation
3.7.11 Artificial lift optimization
3.7.12 Production effect from jobs
Figure 2-1 Oil production in the Volga-Urals region by company, 2001 to 2008, thousand tons per year
Figure 2-2 Oil production in the Volga-Urals region by company, 1H 2008 and 1H 2009, thousand tons
Figure 2-3 VIOCs’ capital expenditures in oil production in the Volga-Urals region, 1H 2008 and 1H 2009, million RUR
Figure 2-4 Capital expenditures per ton of oil produced in the Volga-Urals region by VIOCs, 1H 2008 and 1H 2009, RUR per ton
Figure 2-5 Oil production structure in the Volga-Urals region by VIOCs and independent companies, 2001 to 2008, thousand tons
Figure 2-6 Oil production structure in the Volga-Urals region by VIOCs and independent companies, 2001 to 2008, %
Figure 2-7 Oil production structure in the Volga-Urals region by VIOCs and independent companies, 1H 2008 and 1H 2009, thousand tons
Figure 2-8 Oil production structure in the Volga-Urals region by VIOCs and independent company, 1H 2008 and 1H 2009, %
Figure 2-9 Oil production structure in the Volga-Urals region by VIOCs, 2008, thousand tons
Figure 2-10 Oil production structure in the Volga-Urals region by VIOCs, 2007, thousand tons
Figure 2-11 Oil production structure in the Volga-Urals region by VIOC, 2008, %
Figure 2-12 Oil production structure in the Volga-Urals region by VIOC, 2007, %
Figure 2-13 Annual volumes of VIOC and independent company production drilling in the Volga-Urals region, 2001 to 2008, thousand meters
Figure 2-14 VIOC and independent company production drilling volumes in the Volga-Urals region, 1H 2008 and 1H 2009, thousand meters
Figure 2-15 Commissioning of new development wells in the Volga-Urals region by VIOCs and independent producers, 2001 to 2008, wells per year
Figure 2-16 Production effect from newly drilled wells in the Volga-Urals region, 2001 to 2008, thousand tons per year
Figure 2-17 Commissioning of new development wells in the Volga-Urals region by VIOC and independent producers, 1H 2008 and 1H 2009, wells
Figure 2-18 Production effect from newly drilled wells in the Volga-Urals region, 1H 2008 and 1H 2009, thousand tons
Figure 2-19 VIOCs and independent producer development well stocks in the Volga-Urals region, 2001 to 2008, wells
Figure 2-20 VIOC and independent producer production well stocks in the Volga-Urals region, 2001 to 2008, wells
Figure 2-21 VIOC and independent producer development well stocks in the Volga-Urals region, 1H 2008 and 1H 2009, wells
Figure 2-22 VIOC and independent producer production well stocks in the Volga-Urals region, 1H 2008 and 1H 2009, wells
Figure 2-23 VIOC and independent company production wells within development well stocks in the Volga-Urals region, 2001 to 2008, %
Figure 2-24 VIOC and independent company production wells within development well stocks in the Volga-Urals region, 1H 2008 and 1H 2009, %
Figure 2-25 Average flow rate of wells in the Volga-Urals region, 2001 to 2008, tons per day
Figure 2-26 Average flow rates for VIOC and independent producer wells in the Volga-Urals region, 1H 2008 and 1H 2009, tons per day
Figure 2-27 Average flow rates of newly drilled wells in the Volga-Urals region, 2001 to 2008, tons per day
Figure 2-28 Average flow rates of VIOC and independent producer newly drilled wells in the Volga-Urals region, 1H 2008 and 1H 2009, tons per day
Figure 2-29 Capital expenditures for production drilling in the Volga-Urals region, 1H 2008 and 1H 2009, million RUR
Figure 2-30 Capital expenditures for production drilling per meter drilled in the Volga-Urals region, 1H 2008 and 1H 2009, RUR per meter
Figure 2-31 Annual exploration drilling volume in the Volga-Urals region by VIOCs and independent producers, 2001 to 2008, thousand meters
Figure 2-32 Exploration drilling volume in the Volga-Urals region by VIOCs and independent producers, 1H 2008 and 1H 2009, thousand meters
Figure 2-33 Capital expenditures for exploration drilling in the Volga-Urals region, 1H 2008 and 1H 2009, million RUR
Figure 2-34 Capital expenditure per meter drilled for exploration drilling in the Volga-Urals region, 1H 2008 and 1H 2009, RUR per meter
Figure 2-35 VIOC and independent company workover history in the Volga-Urals region, 2001 to 2008, jobs per year
Figure 2-36 Average annual number of workover crews worked against VIOC and independent company orders in the Volga-Urals region, 2001 to 2008, crews
Figure 2-37 Average workover duration by VIOC and independent company orders in the Volga-Urals region, 2001 to 2008, hours
Figure 2-38 Average workover cost by VIOC and independent company orders in the Volga-Urals region, 2001 to 2008, RUR
Figure 2-39 Productivity of workover crews in the Volga-Urals region, 2001 to 2008, operations per year
Figure 2-40 Fracturing history in the Volga-Urals region, 2001 to 2008, jobs per year
Figure 2-14 Fracturing history in the Volga-Urals region, 1H 2008 and 1H 2009, jobs per year
Figure 2-42 Overall hydraulic fracturing production effect in the Volga-Urals region, 2001 through 2008, thousand tons per year
Figure 2-43 Overall hydraulic fracturing production effect in the Volga-Urals region, 1H 2008 and 1H 2009, thousand tons
Figure 2-44 Average flow rate growth per fracturing job, 2001 to 2008, thousand tons per year
Figure 2-45 Average flow rate growth per fracturing job, 1H 2008 and 1H 2009, thousand tons
Figure 2-46 Bottomhole stimulation history in the Volga-Urals region, 2001 to 2008, jobs per year
Figure 2-47 Bottomhole stimulation history in the Volga-Urals region, 1H 2008 and 1H 2009, jobs
Figure 2-48 Total bottomhole stimulation production effect in the Volga-Urals region, 2001 to 2008, thousand tons per year
Figure 2-49 Total bottomhole stimulation production effect in the Volga-Urals region, 1H 2008 and 1H 2009, thousand tons
Figure 2-50 Average flow rate growth per bottomhole stimulation job in the Volga-Urals region, 2001 to 2008, thousand tons per year
Figure 2-51 Average flow rate growth per bottomhole stimulation job in the Volga-Urals region, 1H 2008 and 1H 2009, thousand tons
Figure 2-52 History of artificial lift optimization activities in the Volga-Urals region, 2001 to 2008, jobs per year
Figure 2-53 History of artificial lift optimization activities in the Volga-Urals region, 1H 2008 and 1H 2009, jobs
Figure 2-54 Total production effect from artificial lift optimization jobs in the Volga-Urals region, 2001 to 2008, thousand tons per year
Figure 2-55 Total production effect of artificial lift optimization in the Volga-Urals region, 1H 2008 and 1H 2009, thousand tons
Figure 2-56 Average flow rate growth of artificial lift optimization per job in the Volga-Urals region, 2001 to 2008, thousand tons per year
Figure 2-57 Average flow rate growth of artificial lift optimization per job in the Volga-Urals region, 1H 2008 and 1H 2009, thousand tons
Figure 3-1 Tatneft’s oil production in the Volga-Urals region, 2001 to 2008, thousand tons per year
Figure 3-2 Tatneft’s oil production in the Volga-Urals region, 1H 2008 and 1H 2009, thousand tons Figure 3-3 Tatneft’s capital expenditures in oil production (million RUR) and per ton of oil, 1H 2008 and 1H 2009, RUR per ton
Figure 3-4 Tatneft’s oil production structure in the Volga-Urals region, 2001 to 2008, thousand tons Figure 3-5 Tatneft’s oil production structure in the Volga-Urals region, 2001 to 2008, %
Figure 3-6 Tatneft’s oil production structure in the Volga-Urals region, 1H 2008 and 1H 2009, thousand tons
Figure 3-7 Tatneft’s oil production structure in the Volga-Urals region, 1H 2008 and 1H 2009, %
Figure 3-8 Tatneft’s production drilling in the Volga-Urals region, 2001 to 2008, thousand meters per year
Figure 3-9 Tatneft’s production drilling in the Volga-Urals region, 1H 2008 and 1H 2009, thousand meters
Figure 3-10 Tatneft’s development well stocks and production well stocks in the Volga-Urals region, 2001 to 2008, wells
Figure 3-11 Tatneft’s development well stocks and production well stocks in the Volga-Urals region, 1H 2008 and 1H 2009, wells
Figure 3-12 Tatneft’s well flow rates in the Volga-Urals region, 2001 to 2008, tons per day
Figure 3-13 Tatneft’s well flow rates in the Volga-Urals region, 1H 2008 and 1H 2009, tons per day
Figure 3-14 Tatneft’s exploration drilling volumes in the Volga-Urals region, 2001 to 2008, thousand meters per year
Figure 3-15 Tatneft’s exploration drilling volumes in the Volga-Urals region, 1H 2008 and 1H 2009, thousand meters
Figure 3-16 Tatneft’s capital expenditures in production and exploration drilling in the Volga-Urals region, 1H 2008 and 1H 2009, million RUR
Figure 3-17 Tatneft’s workover history, number of crews and average number of workover jobs per crew in the Volga-Urals region, 2001 to 2008
Figure 3-18 Average duration of Tatneft’s workovers in the Volga-Urals region, 2001 to 2008, hours
Figure 3-19 Tatneft’s fracturing history (jobs per year) and average flow rate growth per fracturing job (thousand tons) in the Volga-Urals region, 2004 to 2008
Figure 3-20 Tatneft’s fracturing history (jobs) and average flow rate growth per fracturing job (thousand tons) in the Volga-Urals region, 1H 2008 and 1H 2009
Figure 3-21 Bottomhole stimulation history (jobs per year) and average flow rate growth (production effect) of Tatneft’s bottomhole stimulation per job (thousand tons) in the Volga-Urals region, 2001 to 2008
Figure 3-22 Bottomhole stimulation history (jobs) and average flow rate growth (production effect) of Tatneft’s bottomhole stimulation per job (thousand tons) in the Volga-Urals region, 1H 2008 and 1H 2009
Figure 3-23 History of Tatneft’s artificial lift optimization activities (jobs per year) and average flow rate growth (production effect) per job (thousand tons) in the Volga-Urals region, 2001 to 2008
Figure 3-24 History of Tatneft’s artificial lift optimization activities (jobs) and average flow rate growth (production effect) per job (thousand tons) in the Volga-Urals region, 1H 2008 and 1H 2009
Figure 3-25 Overall production effect from Tatneft’s jobs (fracturing, bottomhole stimulation and artificial lift optimization) in the Volga-Urals region, 2001 to 2008, thousand tons per year
Figure 3-26 Overall production effect from Tatneft’s jobs (fracturing, bottomhole stimulation and artificial lift optimization) in the Volga-Urals region, 1H 2008 and 1H 2009, thousand tons
Figure 3-27 LUKOIL’s oil production in the Volga-Urals region, 2001 to 2008, thousand tons per year
Figure 3-28 LUKOIL’s oil production in the Volga-Urals region, 1H 2008 and 1H 2009, thousand tons
Figure 3-29 LUKOIL’s capital expenditures in oil production (million RUR) and per ton of oil produced, 1H 2008 and 1H 2009, RUR per ton
Figure 3-30 LUKOIL’s oil production structure in the Volga-Urals region, 2001 to 2008, thousand tons
Figure 3-31 LUKOIL’s oil production structure in the Volga-Urals region, 2001 to 2008, %
Figure 3-32 LUKOIL’s oil production structure in the Volga-Urals region, 1H 2008 and 1H 2009, thousand tons
Figure 3-33 LUKOIL’s oil production structure in the Volga-Urals region, 1H 2008 and 1H 2009, %
Figure 3-34 LUKOIL’s production drilling in the Volga-Urals region, 2001 to 2008, thousand meters per year
Figure 3-35 LUKOIL’s production drilling in the Volga-Urals region, 1H 2008 and 1H 2009, thousand meters
Figure 3-36 LUKOIL’s development well stock and production well stock in the Volga-Urals region, 2001 to 2008, wells
Figure 3-37 LUKOIL’s development well stock and production well stock in the Volga-Urals region, 1H 2008 and 1H 2009, wells
Figure 3-38 LUKOIL’s well flow rates in the Volga-Urals region, 2001 to 2008, tons per day
Figure 3-39 LUKOIL’s well flow rates (tons per day) in the Volga-Urals region, 1H 2008 and 1H 2009, tons per day
Figure 3-40 LUKOIL’s exploration drilling volumes in the Volga-Urals region, 2001 to 2008, thousand meters per year
Figure 3-41 LUKOIL’s exploration drilling volumes in the Volga-Urals region, 1H 2008 and 1H 2009, thousand meters
Figure 4-42 LUKOIL’s capital expenditures in production and exploration drilling in the Volga-Urals region in 1H 2008 and 1H 2009, million RUR
Figure 3-43 LUKOIL’s workover history (jobs per year), number of crews and average number of workover jobs per crew in the Volga-Urals region, 2001 to 2008
Figure 3-44 Average duration of LUKOIL’s workover jobs (hours) and average costs per workover (RUR) in the Volga-Urals region, 2001 to 2008
Figure 3-45 LUKOIL’s fracturing history (jobs per year) and average flow rate growth per fracturing job (thousand tons) in the Volga-Urals region, 2004 to 2008
Figure 3-46 LUKOIL’s fracturing history (jobs) and average flow rate growth per fracturing job (thousand tons) in the Volga-Urals region, 1H 2008 and 1H 2009
Figure 3-47 Bottomhole stimulation history (jobs per year) and average flow rate growth (production effect) per LUKOIL bottomhole stimulation job (thousand tons) in the Volga-Urals region, 2001 to 2008
Figure 3-48 Bottomhole stimulation history (jobs) and average flow rate growth (production effect) per LUKOIL bottomhole stimulation job (thousand tons) in the Volga-Urals region, 1H 2008 and 1H 2009
Figure 3-49 LUKOIL’s artificial lift optimization activities history (jobs per year) and average flow rate growth (production effect) per job (thousand tons) in the Volga-Urals region, 2001 to 2008
Figure 3-50 LUKOIL’s artificial lift optimization activities history (jobs) and average flow rate growth (production effect) per job (thousand tons) in the Volga-Urals region, 1H 2008 and 1H 2009
Figure 3-51 Overall production effect from LUKOIL’s jobs (fracturing, bottomhole stimulation and artificial lift optimization) in the Volga-Urals region, 2001 to 2008, thousand tons per year
Figure 3-52 Overall production effect from LUKOIL’s jobs (fracturing, bottomhole stimulation and artificial lift optimization) in the Volga-Urals region, 1H 2008 and 1H 2009, thousand tons
Figure 3-53 TNK-BP’s oil production in the Volga-Urals region, 2001 to 2008, thousand tons per year
Figure 3-54 TNK-BP’s oil production in the Volga-Urals region, 1H 2008 and 1H 2009, thousand tons
Figure 3-55 TNK-BP’s oil production structure in the Volga-Urals region, 2001 to 2008, thousand tons
Figure 3-56 TNK-BP’s oil production structure in the Volga-Urals region, 2001 to 2008, %
Figure 3-57 TNK-BP’s oil production structure in the Volga-Urals region, 1H 2008 and 1H 2009, thousand tons
Figure 3-58 TNK-BP’s oil production structure in the Volga-Urals region, 1H 2008 and 1H 2009, %
Figure 3-59 TNK-BP’s production drilling in the Volga-Urals region, 2001 to 2008, thousand meters per year
Figure 3-60 TNK-BP’s production drilling in the Volga-Urals region, 1H 2008 and 1H 2009, thousand meters
Figure 3-61 TNK-BP’s development well stock and production well stock in the Volga-Urals region, 2001 to 2008, wells
Figure 3-62 TNK-BP’s development well stock and production well stock in the Volga-Urals region, 1H 2008 and 1H 2009, wells
Figure 3-63 TNK-BP’s well flow rates in the Volga-Urals region, 2001 to 2008, tons per day
Figure 3-64 TNK-BP’s well flow rates in the Volga-Urals region, 1H 2008 and 1H 2009, tons per day
Figure 3-65 TNK-BP’s exploration drilling volumes in the Volga-Urals region, 2001 to 2008, thousand meters per year
Figure 3-66 TNK-BP’s exploration drilling volumes in the Volga-Urals region, 1H 2008 and 1H 2009, thousand meters
Figure 3-67 TNK-BP’s workover history (jobs per year), number of crews and average number of workover jobs per crew in the Volga-Urals region from 2001 to 2008
Figure 3-68 Average duration of TNK-BP’s workover operations (hours) and average costs of well workovers (RUR) in the Volga-Urals region, 2001 to 2008
Figure 3-69 TNK-BP’s fracturing history (jobs per year) and average flow rate growth (production effect) per fracturing job (thousand tons) in the Volga-Urals region, 2004 to 2008
Figure 3-70 TNK-BP’s fracturing history (jobs) and average flow rate growth (production effect) per fracturing job (thousand tons) in the Volga-Urals region, 1H 2008 and 1H 2009
Figure 3-71 TNK-BP’s bottomhole stimulation history (jobs per year) and average flow rate growth (production effect) of bottomhole stimulation per job (thousand tons) in the Volga-Urals region, 2001 to 2008
Figure 3-72 TNK-BP’s bottomhole stimulation history (jobs) and average flow rate growth (production effect) per bottomhole stimulatiion job (thousand tons) in the Volga-Urals region, 1H 2008 and 1H 2009
Figure 3-73 TNK-BP’s artificial lift optimization activities (jobs per year) and average flow rate growth (production effect) per job (thousand tons) in the Volga-Urals region, 2001 to 2008
Figure 3-74 TNK-BP’s artificial lift optimization activities (jobs) and average flow rate growth (production effect) per job (thousand tons) in the Volga-Urals region, 1H 2008 and 1H 2009
Figure 3-75 Overall production effect from TNK-BP’s jobs (fracturing, bottomhole stimulation and artificial lift optimization) in the Volga-Urals region, 2001 to 2008, thousand tons per year
Figure 3-76 Overall production effect from TNK-BP’s jobs (fracturing, bottomhole stimulation and artificial lift optimization) in the Volga-Urals region, 1H 2008 and 1H 2009, thousand tons
Figure 3-77 Rosneft’s oil production in the Volga-Urals region, 2006 to 2008, thousand tons per year
Figure 3-78 Rosneft’s oil production in the Volga-Urals region, 1H 2008 and 1H 2009, thousand tons
Figure 3-79 Rosneft’s capital expenditures in oil production (million RUR) and per ton of oil produced, 1H 2008 and 1H 2009, RUR per ton
Figure 3-80 Rosneft’s oil production structure in the Volga-Urals region, 2006 to 2008, thousand tons
Figure 3-81 Rosneft’s oil production structure in the Volga-Urals region, 2006 to 2008, %
Figure 3-82 Rosneft’s oil production structure in the Volga-Urals region, 1H 2008 and 1H 2009, thousand tons
Figure 3-83 Rosneft’s oil production jobs in the Volga-Urals region, 1H 2008 and 1H 2009, %
Figure 3-84 Rosneft’s production drilling in the Volga-Urals region, 2006 to 2008, thousand meters per year
Figure 3-85 Rosneft’s production drilling in the Volga-Urals region, 1H 2008 and 1H 2009, thousand meters
Figure 3-86 Rosneft’s development well stock and productiion well stock in the Volga-Urals region, 2006 to 2008, wells
Figure 3-87 Rosneft’s development well stock and production well stock in the Volga-Urals region, 1H 2008 and 1H 2009, wells
Figure 3-88 Rosneft’s well flow rates in the Volga-Urals region, 2006 to 2008, tons per day
Figure 3-89 Rosneft’s well flow rates in the Volga-Urals region, 1H 2008 and 1H 2009, tons per day
Figure 3-90 Rosneft’s exploration drilling volumes in the Volga-Urals region, 2007 to 2008, thousand meters per year
Figure 3-91 Rosneft’s exploration drilling volumes in the Volga-Urals region, 1H 2008 and 1H 2009, thousand meters
Figure 3-92 Rosneft’s capital expenditures in production and exploration drilling in the Volga-Urals region, 1H 2008 and 1H 2009, million RUR
Figure 3-93 Rosneft’s workover history (jobs per year), effective average number of crews and average number of workover jobs per crew in the Volga-Urals region, 2006 to 2008
Figure 3-94 Average duration of Rosneft's workover jobs (hours) and average cost of well workovers (RUR) in the Volga-Urals region, 2006 to 2008
Figure 3-95 Rosneft’s fracturing history (jobs per year) and average flow rate growth (production effect) perfracturing job (thousand tons) in the Volga-Urals region, 2006 to 2008
Figure 3-96 Rosneft’s fracturing history (jobs) and average flow rate growth (production effect) per fracturing job (thousand tons) in the Volga-Urals region, 1H 2008 and 1H 2009
Figure 3-97 Rosneft’s bottomhole stimulation history (jobs per year) and average flow rate growth (production effect) of bottomhole treatment per job (thousand tons) in the Volga-Urals region, 2006 to 2008
Figure 3-98 Rosneft’s bottomhole stimulation history (jobs) and average flow rate growth (production effect) of bottomhole treatment per job (thousand tons) in the Volga-Urals region,, 1H 2008 and 1H 2009
Figure 3-99 History of Rosneft’s artificial lift optimization activities (jobs per year) and average flow rate growth (production effect) per job (thousand tons) in the Volga-Urals region, 2006 to 2008
Figure 3-100 History of Rosneft’s artificial lift optimization activities (jobs per year) and average flow rate growth (production effect) per job (thousand tons) in the Volga-Urals region, 1H 2008 and 1H 2009
Figure 3-101 Overall production effect from Rosneft’s jobs (fracturing, bottomhole stimulation and artificial lift optimization) in the Volga-Urals region, 2006 to 2008, thousand tons per year
Figure 3-102 Overall production effect from Rosneft’s jobs (fracturing, bottomhole stimulation and artificial lift optimization) in the Volga-Urals region, 1H 2008 and 1H 2009, thousand tons
Figure 3-103 Bashneft’s oil production in the Volga-Urals region, 2001 to 2008, thousand tons per year
Figure 3-104 Bashneft’s oil production in the Volga-Urals region, 1H 2008 and 1H 2009, thousand tons
Figure 3-105 Bashneft’s capital expenditures in oil production (million RUR ) and per ton of oil produced, 1H 2008 and 1H 2009, RUR per ton
Figure 3-106 Bashneft’s oil production structure in the Volga-Urals region, 2001 to 2008, thousand tons
Figure 3-107 Bashneft’s oil production structure in the Volga-Urals region, 2001 to 2008, %
Figure 3-108 Bashneft’s oil production structure in the Volga-Urals region, 1H 2008 and 1H 2009, thousand tons
Figure 3-109 Bashneft’s oil production structure in the Volga-Urals region, 1H 2008 and 1H 2009, %
Figure 3-110 Bashneft’s production drilling in the Volga-Urals region, 2001 to 2008, thousand meters per year
Figure 3-111 Bashneft’s production drilling in the Volga-Urals region, 1H 2008 and 1H 2009, thousand meters
Figure 3-112 Bashneft’s development well and production well stocks in the Volga-Urals region, 2001 to 2008, wells
Figure 3-113 Bashneft’s development well and production well stocks in the Volga-Urals region, 1H 2008 and 1H 2009, wells
Figure 3-114 Bashneft’s well flow rates in the Volga-Urals region, 2001 to 2008, tons per day
Figure 3-115 Bashneft’s well flow rates in the Volga-Urals region, 1H 2008 and 1H 2009, tons per day
Figure 3-116 Bashneft’s exploration drilling volumes in the Volga-Urals region, 2001 to 2008, thousand meters per year
Figure 3-117 Bashneft’s exploration drilling volumes in the Volga-Urals region, 1H 2008 and 1H 2009, thousand meters
Figure 3-118 Bashneft’s capital expenditures in production and exploration drilling in the Volga-Urals region, 1H 2008 and 1H 2009, million RUR
Figure 3-119 Bashneft’s workover history (jobs per year), number of crews and average number of workover operations per crew in the Volga-Urals region, 2001 to 2008
Figure 3-120 Average duration of Bashneft’s workover operations (hours) and average costs of well workovers (RUR) in the Volga-Urals region, 2001 to 2008
Figure 3-121 Bashneft’s fracturing history (jobs per year) and average flow rate growth (production effect) per fracturing job (thousand tons) in the Volga-Urals region, 2004 to 2008
Figure 3-122 Bashneft’s fracturing history (jobs) and average flow rate growth (production effect) per fracturing job (thousand tons) in the Volga-Urals region, 1H 2008 and 1H 2009
Figure 3-123 Bashneft’s bottomhole stimulation history (jobs per year) and average flow rate growth (production effect) per bottomhole stimulation job (thousand tons) in the Volga-Urals region, 2001 to 2008
Figure 3-124 Bashneft’s bottomhole stimulation history (jobs) and average flow rate growth (production effect) per bottomhole stimulation job (thousand tons) in the Volga-Urals region, 1H 2008 and 1H 2009
Figure 3-125 Bashneft’s artificial lift optimization activities (jobs per year) and average flow rate growth (production effect) per job (thousand tons) in the Volga-Urals region, 2001 to 2008
Figure 3-126 Bashneft’s artificial lift optimization activities (jobs) and average flow rate growth (production effect) per job (thousand tons) in the Volga-Urals region, 1H 2008 and 1H 2009
Figure 3-127 Overall production effect from Bashneft’s jobs (fracturing, bottomhole stimulation and artificial lift optimization) in the Volga-Urals region, 2006 to 2008, thousand tons per year
Figure 3-128 Overall production effect from Bashneft’s jobs (fracturing, bottomhole stimulation and artificial lift optimization) in the Volga-Urals region , 1H 2008 and 1H 2009, thousand tons
Figure 3-129 Russneft’s oil production in the Volga-Urals region, 2001 to 2008, thousand tons per year
Figure 3-130 Russneft’s oil production in the Volga-Urals region, 1H 2008 and 1H 2009, thousand tons
Figure 3-131 Russneft’s capital expenditures in oil production (million RUR) and per ton of oil produced, 1H 2008 and 1H 2009, RUR per ton
Figure 3-132 Russneft’s oil production structure in the Volga-Urals region, 2001 to 2008, thousand tons
Figure 3-133 Russneft’s oil production structure in the Volga-Urals region, 2001 to 2008, %
Figure 3-134 Russneft’s oil production strucuture in the Volga-Urals region, 1H 2008 and 1H 2009, thousand tons
Figure 3-135 Russneft’s oil production structure in the Volga-Urals region, 1H 2008 and 1H 2009, %
Figure 3-136 Russneft’s production drilling in the Volga-Urals region, 2001 to 2008, thousand meters per year
Figure 3-137 Russneft’s production drilling in the Volga-Urals region, 1H 2008 and 1H 2009, thousand meters
Figure 3-138 Russneft’s development well stock and production well stock in the Volga-Urals region, 2001 to 2008, wells
Figure 3-139 Russneft’s development well stock and production well stock in the Volga-Urals region, 1H 2008 and 1H 2009, wells
Figure 3-140 Russneft’s well flow rates in the Volga-Urals region, 2001 to 2008, tons per day
Figure 3-141 Russneft’s well flow rates in the Volga-Urals region, 1H 2008 and 1H 2009, tons per day
Figure 3-142 Russneft’s exploration drilling volumes in the Volga-Urals region, 2001 to 2008, thousand meters per year
Figure 3-143 Russneft’s exploration drilling volumes in the Volga-Urals region, 1H 2008 and 1H 2009, thousand meters
Figure 3-144 Russneft’s workover history (jobs per year), number of crews and average number of workover jobs per crew in the Volga-Urals region, 2001 to 2008
Figure 3-145 Average duration of Russneft’s workover jobs (hours) and average costs of workover (RUR) in the Volga-Urals region, 2001 to 2008
Figure 3-146 Russneft’s fracturing history (jobs per year) and average flow rate growth (production effect) per fracturing job (thousand tons) in the Volga-Urals region, 2004 to 2008
Figure 3-147 Russneft’s fracturing history (jobs) and average flow rate growth (production effect) per fracturing job (thousand tons) in the Volga-Urals region, 1H 2008 and 1H 2009
Figure 3-148 Bottomhole stimulation history (jobs per year) and average flow rate growth (production effect) per Russneft’s bottomhole stimulation job (thousand tons) in the Volga-Urals region, 2001 to 2008
Figure 3-149 Bottomhole treatment history (jobs) and average flow rate growth (production effect) per Russneft’s bottomhole stimulation job (thousand tons) in the Volga-Urals region, 1H 2008 and 1H 2009
Figure 3-150 Russneft’s history of artificial lift optimization activities (jobs per year) and average flow rate growth (production effect) per job (thousand tons) in the Volga-Urals region, 2001 to 2008
Figure 3-151 Russneft’s history of artificial lift optimization activities (jobs) and average flow rate growth (production effect) per job (thousand tons) in the Volga-Urals region, 1H 2008 and 1H 2009
Figure 3-152 Overall production effect from Russneft’s jobs (fracturing, bottomhole stimulation and artificial lift optimization) in the Volga-Urals region, 2006 to 2008, thousand tons per year
Figure 3-153 Overall production effect from Russneft’s jobs (fracturing, bottomhole stimulation and artificial lift optimization) in the Volga-Urals region, 1H 2008 and 1H 2009, thousand tons
Figure 3-154 Oil production by independent companies in the Volga-Urals region, 2001 to 2008, thousand tons per year
Figure 3-155 Oil production by independent companies in the Volga-Urals region, 1H 2008 and 1H 2009, thousand tons
Figure 3-156 Oil production structure for independent companies in the Volga-Urals region, 2001 to 2008, thousand tons
Figure 3-157 Oil production structure for independent companies in the Volga-Urals region, 2001 to 2008, %
Figure 3-158 Independent companies’ oil production structure in the Volga-Urals region, 1H 2008 and 1H 2009, thousand tons
Figure 3-159 Oil production structure for independent companies in the Volga-Urals region, 1H 2008 and 1H 2009, %
Figure 3-160 Production drilling by independent companies in the Volga-Urals region, 2001 to 2008, thousand meters per year
Figure 3-161 Production drilling by independent companies in the Volga-Urals region, 1H 2008 and 1H 2009, thousand meters
Figure 3-162 Independent company development well stock and production well stocks in the Volga-Urals region, 2001 to 2008, wells
Figure 3-163 Independent company development well stock and production well stock in the Volga-Urals region, 1H 2008 and 1H 2009, wells
Figure 3-164 Independent company well flow rates in the Volga-Urals region, 2001 to 2008, tons per day
Figure 3-165 Independent company well flow rates in the Volga-Urals region, 1H 2008 and 1H 2009, tons per day
Figure 3-166 Independent company exploration drilling volumes in the Volga-Urals region, 2001 to 2008, thousand meters per year
Figure 3-167 Independent company exploration drilling volumes in the Volga-Urals region, 1H 2008 and 1H 2009, thousand meters
Figure 3-168 Independent company workover history (jobs per year), number of crews and average number of workover jobs per crew in the Volga-Urals region, 2001 to 2008
Figure 3-169 Average duration of independent company workover jobs (hours) and average costs of workover (RUR) in the Volga-Urals region, 2001 to 2008
Figure 3-170 Independent company fracturing history (jobs per year) and average flow rate growth (production effect) per fracturing job (thousand tons) in the Volga-Urals region, 2006 to 2008
Figure 3-171 Independent company fracturing history (jobs) and average flow rate growth (production effect) per fracturing job (thousand tons) in the Volga-Urals region, 1H 2008 and 1H 2009
Figure 3-172 Bottomhole stimulation history (jobs per year) and average flow rate growth (production effect) per independent company bottomhole stimulation job (thousand tons) in the Volga-Urals region, 2001 to 2008
Figure 3-173 Bottomhole treatment history (jobs) and average flow rate growth (production effect) per independent company bottomhole stimulation job (thousand tons) in the Volga-Urals region, 1H 2008 and 1H 2009
Figure 3-174 Independent company artificial lift optimization activities history (jobs) and average flow rate growth (production effect) per job (thousand tons) in the Volga-Urals region, 1H 2008 and 1H 2009
Figure 3-175 Overall production effect from independent company jobs (fracturing, bottomhole stimulation and artificial lift optimization) in the Volga-Urals region, 2001 to 2008, thousand tons per year
Figure 3-176 Overall production effect from independent company jobs (fracturing, bottomhole stimulation and artificial lift optimization) in the Volga-Urals region, 1H 2008 and 1H 2009, thousand tons
Figure 2-2 Oil production in the Volga-Urals region by company, 1H 2008 and 1H 2009, thousand tons
Figure 2-3 VIOCs’ capital expenditures in oil production in the Volga-Urals region, 1H 2008 and 1H 2009, million RUR
Figure 2-4 Capital expenditures per ton of oil produced in the Volga-Urals region by VIOCs, 1H 2008 and 1H 2009, RUR per ton
Figure 2-5 Oil production structure in the Volga-Urals region by VIOCs and independent companies, 2001 to 2008, thousand tons
Figure 2-6 Oil production structure in the Volga-Urals region by VIOCs and independent companies, 2001 to 2008, %
Figure 2-7 Oil production structure in the Volga-Urals region by VIOCs and independent companies, 1H 2008 and 1H 2009, thousand tons
Figure 2-8 Oil production structure in the Volga-Urals region by VIOCs and independent company, 1H 2008 and 1H 2009, %
Figure 2-9 Oil production structure in the Volga-Urals region by VIOCs, 2008, thousand tons
Figure 2-10 Oil production structure in the Volga-Urals region by VIOCs, 2007, thousand tons
Figure 2-11 Oil production structure in the Volga-Urals region by VIOC, 2008, %
Figure 2-12 Oil production structure in the Volga-Urals region by VIOC, 2007, %
Figure 2-13 Annual volumes of VIOC and independent company production drilling in the Volga-Urals region, 2001 to 2008, thousand meters
Figure 2-14 VIOC and independent company production drilling volumes in the Volga-Urals region, 1H 2008 and 1H 2009, thousand meters
Figure 2-15 Commissioning of new development wells in the Volga-Urals region by VIOCs and independent producers, 2001 to 2008, wells per year
Figure 2-16 Production effect from newly drilled wells in the Volga-Urals region, 2001 to 2008, thousand tons per year
Figure 2-17 Commissioning of new development wells in the Volga-Urals region by VIOC and independent producers, 1H 2008 and 1H 2009, wells
Figure 2-18 Production effect from newly drilled wells in the Volga-Urals region, 1H 2008 and 1H 2009, thousand tons
Figure 2-19 VIOCs and independent producer development well stocks in the Volga-Urals region, 2001 to 2008, wells
Figure 2-20 VIOC and independent producer production well stocks in the Volga-Urals region, 2001 to 2008, wells
Figure 2-21 VIOC and independent producer development well stocks in the Volga-Urals region, 1H 2008 and 1H 2009, wells
Figure 2-22 VIOC and independent producer production well stocks in the Volga-Urals region, 1H 2008 and 1H 2009, wells
Figure 2-23 VIOC and independent company production wells within development well stocks in the Volga-Urals region, 2001 to 2008, %
Figure 2-24 VIOC and independent company production wells within development well stocks in the Volga-Urals region, 1H 2008 and 1H 2009, %
Figure 2-25 Average flow rate of wells in the Volga-Urals region, 2001 to 2008, tons per day
Figure 2-26 Average flow rates for VIOC and independent producer wells in the Volga-Urals region, 1H 2008 and 1H 2009, tons per day
Figure 2-27 Average flow rates of newly drilled wells in the Volga-Urals region, 2001 to 2008, tons per day
Figure 2-28 Average flow rates of VIOC and independent producer newly drilled wells in the Volga-Urals region, 1H 2008 and 1H 2009, tons per day
Figure 2-29 Capital expenditures for production drilling in the Volga-Urals region, 1H 2008 and 1H 2009, million RUR
Figure 2-30 Capital expenditures for production drilling per meter drilled in the Volga-Urals region, 1H 2008 and 1H 2009, RUR per meter
Figure 2-31 Annual exploration drilling volume in the Volga-Urals region by VIOCs and independent producers, 2001 to 2008, thousand meters
Figure 2-32 Exploration drilling volume in the Volga-Urals region by VIOCs and independent producers, 1H 2008 and 1H 2009, thousand meters
Figure 2-33 Capital expenditures for exploration drilling in the Volga-Urals region, 1H 2008 and 1H 2009, million RUR
Figure 2-34 Capital expenditure per meter drilled for exploration drilling in the Volga-Urals region, 1H 2008 and 1H 2009, RUR per meter
Figure 2-35 VIOC and independent company workover history in the Volga-Urals region, 2001 to 2008, jobs per year
Figure 2-36 Average annual number of workover crews worked against VIOC and independent company orders in the Volga-Urals region, 2001 to 2008, crews
Figure 2-37 Average workover duration by VIOC and independent company orders in the Volga-Urals region, 2001 to 2008, hours
Figure 2-38 Average workover cost by VIOC and independent company orders in the Volga-Urals region, 2001 to 2008, RUR
Figure 2-39 Productivity of workover crews in the Volga-Urals region, 2001 to 2008, operations per year
Figure 2-40 Fracturing history in the Volga-Urals region, 2001 to 2008, jobs per year
Figure 2-14 Fracturing history in the Volga-Urals region, 1H 2008 and 1H 2009, jobs per year
Figure 2-42 Overall hydraulic fracturing production effect in the Volga-Urals region, 2001 through 2008, thousand tons per year
Figure 2-43 Overall hydraulic fracturing production effect in the Volga-Urals region, 1H 2008 and 1H 2009, thousand tons
Figure 2-44 Average flow rate growth per fracturing job, 2001 to 2008, thousand tons per year
Figure 2-45 Average flow rate growth per fracturing job, 1H 2008 and 1H 2009, thousand tons
Figure 2-46 Bottomhole stimulation history in the Volga-Urals region, 2001 to 2008, jobs per year
Figure 2-47 Bottomhole stimulation history in the Volga-Urals region, 1H 2008 and 1H 2009, jobs
Figure 2-48 Total bottomhole stimulation production effect in the Volga-Urals region, 2001 to 2008, thousand tons per year
Figure 2-49 Total bottomhole stimulation production effect in the Volga-Urals region, 1H 2008 and 1H 2009, thousand tons
Figure 2-50 Average flow rate growth per bottomhole stimulation job in the Volga-Urals region, 2001 to 2008, thousand tons per year
Figure 2-51 Average flow rate growth per bottomhole stimulation job in the Volga-Urals region, 1H 2008 and 1H 2009, thousand tons
Figure 2-52 History of artificial lift optimization activities in the Volga-Urals region, 2001 to 2008, jobs per year
Figure 2-53 History of artificial lift optimization activities in the Volga-Urals region, 1H 2008 and 1H 2009, jobs
Figure 2-54 Total production effect from artificial lift optimization jobs in the Volga-Urals region, 2001 to 2008, thousand tons per year
Figure 2-55 Total production effect of artificial lift optimization in the Volga-Urals region, 1H 2008 and 1H 2009, thousand tons
Figure 2-56 Average flow rate growth of artificial lift optimization per job in the Volga-Urals region, 2001 to 2008, thousand tons per year
Figure 2-57 Average flow rate growth of artificial lift optimization per job in the Volga-Urals region, 1H 2008 and 1H 2009, thousand tons
Figure 3-1 Tatneft’s oil production in the Volga-Urals region, 2001 to 2008, thousand tons per year
Figure 3-2 Tatneft’s oil production in the Volga-Urals region, 1H 2008 and 1H 2009, thousand tons Figure 3-3 Tatneft’s capital expenditures in oil production (million RUR) and per ton of oil, 1H 2008 and 1H 2009, RUR per ton
Figure 3-4 Tatneft’s oil production structure in the Volga-Urals region, 2001 to 2008, thousand tons Figure 3-5 Tatneft’s oil production structure in the Volga-Urals region, 2001 to 2008, %
Figure 3-6 Tatneft’s oil production structure in the Volga-Urals region, 1H 2008 and 1H 2009, thousand tons
Figure 3-7 Tatneft’s oil production structure in the Volga-Urals region, 1H 2008 and 1H 2009, %
Figure 3-8 Tatneft’s production drilling in the Volga-Urals region, 2001 to 2008, thousand meters per year
Figure 3-9 Tatneft’s production drilling in the Volga-Urals region, 1H 2008 and 1H 2009, thousand meters
Figure 3-10 Tatneft’s development well stocks and production well stocks in the Volga-Urals region, 2001 to 2008, wells
Figure 3-11 Tatneft’s development well stocks and production well stocks in the Volga-Urals region, 1H 2008 and 1H 2009, wells
Figure 3-12 Tatneft’s well flow rates in the Volga-Urals region, 2001 to 2008, tons per day
Figure 3-13 Tatneft’s well flow rates in the Volga-Urals region, 1H 2008 and 1H 2009, tons per day
Figure 3-14 Tatneft’s exploration drilling volumes in the Volga-Urals region, 2001 to 2008, thousand meters per year
Figure 3-15 Tatneft’s exploration drilling volumes in the Volga-Urals region, 1H 2008 and 1H 2009, thousand meters
Figure 3-16 Tatneft’s capital expenditures in production and exploration drilling in the Volga-Urals region, 1H 2008 and 1H 2009, million RUR
Figure 3-17 Tatneft’s workover history, number of crews and average number of workover jobs per crew in the Volga-Urals region, 2001 to 2008
Figure 3-18 Average duration of Tatneft’s workovers in the Volga-Urals region, 2001 to 2008, hours
Figure 3-19 Tatneft’s fracturing history (jobs per year) and average flow rate growth per fracturing job (thousand tons) in the Volga-Urals region, 2004 to 2008
Figure 3-20 Tatneft’s fracturing history (jobs) and average flow rate growth per fracturing job (thousand tons) in the Volga-Urals region, 1H 2008 and 1H 2009
Figure 3-21 Bottomhole stimulation history (jobs per year) and average flow rate growth (production effect) of Tatneft’s bottomhole stimulation per job (thousand tons) in the Volga-Urals region, 2001 to 2008
Figure 3-22 Bottomhole stimulation history (jobs) and average flow rate growth (production effect) of Tatneft’s bottomhole stimulation per job (thousand tons) in the Volga-Urals region, 1H 2008 and 1H 2009
Figure 3-23 History of Tatneft’s artificial lift optimization activities (jobs per year) and average flow rate growth (production effect) per job (thousand tons) in the Volga-Urals region, 2001 to 2008
Figure 3-24 History of Tatneft’s artificial lift optimization activities (jobs) and average flow rate growth (production effect) per job (thousand tons) in the Volga-Urals region, 1H 2008 and 1H 2009
Figure 3-25 Overall production effect from Tatneft’s jobs (fracturing, bottomhole stimulation and artificial lift optimization) in the Volga-Urals region, 2001 to 2008, thousand tons per year
Figure 3-26 Overall production effect from Tatneft’s jobs (fracturing, bottomhole stimulation and artificial lift optimization) in the Volga-Urals region, 1H 2008 and 1H 2009, thousand tons
Figure 3-27 LUKOIL’s oil production in the Volga-Urals region, 2001 to 2008, thousand tons per year
Figure 3-28 LUKOIL’s oil production in the Volga-Urals region, 1H 2008 and 1H 2009, thousand tons
Figure 3-29 LUKOIL’s capital expenditures in oil production (million RUR) and per ton of oil produced, 1H 2008 and 1H 2009, RUR per ton
Figure 3-30 LUKOIL’s oil production structure in the Volga-Urals region, 2001 to 2008, thousand tons
Figure 3-31 LUKOIL’s oil production structure in the Volga-Urals region, 2001 to 2008, %
Figure 3-32 LUKOIL’s oil production structure in the Volga-Urals region, 1H 2008 and 1H 2009, thousand tons
Figure 3-33 LUKOIL’s oil production structure in the Volga-Urals region, 1H 2008 and 1H 2009, %
Figure 3-34 LUKOIL’s production drilling in the Volga-Urals region, 2001 to 2008, thousand meters per year
Figure 3-35 LUKOIL’s production drilling in the Volga-Urals region, 1H 2008 and 1H 2009, thousand meters
Figure 3-36 LUKOIL’s development well stock and production well stock in the Volga-Urals region, 2001 to 2008, wells
Figure 3-37 LUKOIL’s development well stock and production well stock in the Volga-Urals region, 1H 2008 and 1H 2009, wells
Figure 3-38 LUKOIL’s well flow rates in the Volga-Urals region, 2001 to 2008, tons per day
Figure 3-39 LUKOIL’s well flow rates (tons per day) in the Volga-Urals region, 1H 2008 and 1H 2009, tons per day
Figure 3-40 LUKOIL’s exploration drilling volumes in the Volga-Urals region, 2001 to 2008, thousand meters per year
Figure 3-41 LUKOIL’s exploration drilling volumes in the Volga-Urals region, 1H 2008 and 1H 2009, thousand meters
Figure 4-42 LUKOIL’s capital expenditures in production and exploration drilling in the Volga-Urals region in 1H 2008 and 1H 2009, million RUR
Figure 3-43 LUKOIL’s workover history (jobs per year), number of crews and average number of workover jobs per crew in the Volga-Urals region, 2001 to 2008
Figure 3-44 Average duration of LUKOIL’s workover jobs (hours) and average costs per workover (RUR) in the Volga-Urals region, 2001 to 2008
Figure 3-45 LUKOIL’s fracturing history (jobs per year) and average flow rate growth per fracturing job (thousand tons) in the Volga-Urals region, 2004 to 2008
Figure 3-46 LUKOIL’s fracturing history (jobs) and average flow rate growth per fracturing job (thousand tons) in the Volga-Urals region, 1H 2008 and 1H 2009
Figure 3-47 Bottomhole stimulation history (jobs per year) and average flow rate growth (production effect) per LUKOIL bottomhole stimulation job (thousand tons) in the Volga-Urals region, 2001 to 2008
Figure 3-48 Bottomhole stimulation history (jobs) and average flow rate growth (production effect) per LUKOIL bottomhole stimulation job (thousand tons) in the Volga-Urals region, 1H 2008 and 1H 2009
Figure 3-49 LUKOIL’s artificial lift optimization activities history (jobs per year) and average flow rate growth (production effect) per job (thousand tons) in the Volga-Urals region, 2001 to 2008
Figure 3-50 LUKOIL’s artificial lift optimization activities history (jobs) and average flow rate growth (production effect) per job (thousand tons) in the Volga-Urals region, 1H 2008 and 1H 2009
Figure 3-51 Overall production effect from LUKOIL’s jobs (fracturing, bottomhole stimulation and artificial lift optimization) in the Volga-Urals region, 2001 to 2008, thousand tons per year
Figure 3-52 Overall production effect from LUKOIL’s jobs (fracturing, bottomhole stimulation and artificial lift optimization) in the Volga-Urals region, 1H 2008 and 1H 2009, thousand tons
Figure 3-53 TNK-BP’s oil production in the Volga-Urals region, 2001 to 2008, thousand tons per year
Figure 3-54 TNK-BP’s oil production in the Volga-Urals region, 1H 2008 and 1H 2009, thousand tons
Figure 3-55 TNK-BP’s oil production structure in the Volga-Urals region, 2001 to 2008, thousand tons
Figure 3-56 TNK-BP’s oil production structure in the Volga-Urals region, 2001 to 2008, %
Figure 3-57 TNK-BP’s oil production structure in the Volga-Urals region, 1H 2008 and 1H 2009, thousand tons
Figure 3-58 TNK-BP’s oil production structure in the Volga-Urals region, 1H 2008 and 1H 2009, %
Figure 3-59 TNK-BP’s production drilling in the Volga-Urals region, 2001 to 2008, thousand meters per year
Figure 3-60 TNK-BP’s production drilling in the Volga-Urals region, 1H 2008 and 1H 2009, thousand meters
Figure 3-61 TNK-BP’s development well stock and production well stock in the Volga-Urals region, 2001 to 2008, wells
Figure 3-62 TNK-BP’s development well stock and production well stock in the Volga-Urals region, 1H 2008 and 1H 2009, wells
Figure 3-63 TNK-BP’s well flow rates in the Volga-Urals region, 2001 to 2008, tons per day
Figure 3-64 TNK-BP’s well flow rates in the Volga-Urals region, 1H 2008 and 1H 2009, tons per day
Figure 3-65 TNK-BP’s exploration drilling volumes in the Volga-Urals region, 2001 to 2008, thousand meters per year
Figure 3-66 TNK-BP’s exploration drilling volumes in the Volga-Urals region, 1H 2008 and 1H 2009, thousand meters
Figure 3-67 TNK-BP’s workover history (jobs per year), number of crews and average number of workover jobs per crew in the Volga-Urals region from 2001 to 2008
Figure 3-68 Average duration of TNK-BP’s workover operations (hours) and average costs of well workovers (RUR) in the Volga-Urals region, 2001 to 2008
Figure 3-69 TNK-BP’s fracturing history (jobs per year) and average flow rate growth (production effect) per fracturing job (thousand tons) in the Volga-Urals region, 2004 to 2008
Figure 3-70 TNK-BP’s fracturing history (jobs) and average flow rate growth (production effect) per fracturing job (thousand tons) in the Volga-Urals region, 1H 2008 and 1H 2009
Figure 3-71 TNK-BP’s bottomhole stimulation history (jobs per year) and average flow rate growth (production effect) of bottomhole stimulation per job (thousand tons) in the Volga-Urals region, 2001 to 2008
Figure 3-72 TNK-BP’s bottomhole stimulation history (jobs) and average flow rate growth (production effect) per bottomhole stimulatiion job (thousand tons) in the Volga-Urals region, 1H 2008 and 1H 2009
Figure 3-73 TNK-BP’s artificial lift optimization activities (jobs per year) and average flow rate growth (production effect) per job (thousand tons) in the Volga-Urals region, 2001 to 2008
Figure 3-74 TNK-BP’s artificial lift optimization activities (jobs) and average flow rate growth (production effect) per job (thousand tons) in the Volga-Urals region, 1H 2008 and 1H 2009
Figure 3-75 Overall production effect from TNK-BP’s jobs (fracturing, bottomhole stimulation and artificial lift optimization) in the Volga-Urals region, 2001 to 2008, thousand tons per year
Figure 3-76 Overall production effect from TNK-BP’s jobs (fracturing, bottomhole stimulation and artificial lift optimization) in the Volga-Urals region, 1H 2008 and 1H 2009, thousand tons
Figure 3-77 Rosneft’s oil production in the Volga-Urals region, 2006 to 2008, thousand tons per year
Figure 3-78 Rosneft’s oil production in the Volga-Urals region, 1H 2008 and 1H 2009, thousand tons
Figure 3-79 Rosneft’s capital expenditures in oil production (million RUR) and per ton of oil produced, 1H 2008 and 1H 2009, RUR per ton
Figure 3-80 Rosneft’s oil production structure in the Volga-Urals region, 2006 to 2008, thousand tons
Figure 3-81 Rosneft’s oil production structure in the Volga-Urals region, 2006 to 2008, %
Figure 3-82 Rosneft’s oil production structure in the Volga-Urals region, 1H 2008 and 1H 2009, thousand tons
Figure 3-83 Rosneft’s oil production jobs in the Volga-Urals region, 1H 2008 and 1H 2009, %
Figure 3-84 Rosneft’s production drilling in the Volga-Urals region, 2006 to 2008, thousand meters per year
Figure 3-85 Rosneft’s production drilling in the Volga-Urals region, 1H 2008 and 1H 2009, thousand meters
Figure 3-86 Rosneft’s development well stock and productiion well stock in the Volga-Urals region, 2006 to 2008, wells
Figure 3-87 Rosneft’s development well stock and production well stock in the Volga-Urals region, 1H 2008 and 1H 2009, wells
Figure 3-88 Rosneft’s well flow rates in the Volga-Urals region, 2006 to 2008, tons per day
Figure 3-89 Rosneft’s well flow rates in the Volga-Urals region, 1H 2008 and 1H 2009, tons per day
Figure 3-90 Rosneft’s exploration drilling volumes in the Volga-Urals region, 2007 to 2008, thousand meters per year
Figure 3-91 Rosneft’s exploration drilling volumes in the Volga-Urals region, 1H 2008 and 1H 2009, thousand meters
Figure 3-92 Rosneft’s capital expenditures in production and exploration drilling in the Volga-Urals region, 1H 2008 and 1H 2009, million RUR
Figure 3-93 Rosneft’s workover history (jobs per year), effective average number of crews and average number of workover jobs per crew in the Volga-Urals region, 2006 to 2008
Figure 3-94 Average duration of Rosneft's workover jobs (hours) and average cost of well workovers (RUR) in the Volga-Urals region, 2006 to 2008
Figure 3-95 Rosneft’s fracturing history (jobs per year) and average flow rate growth (production effect) perfracturing job (thousand tons) in the Volga-Urals region, 2006 to 2008
Figure 3-96 Rosneft’s fracturing history (jobs) and average flow rate growth (production effect) per fracturing job (thousand tons) in the Volga-Urals region, 1H 2008 and 1H 2009
Figure 3-97 Rosneft’s bottomhole stimulation history (jobs per year) and average flow rate growth (production effect) of bottomhole treatment per job (thousand tons) in the Volga-Urals region, 2006 to 2008
Figure 3-98 Rosneft’s bottomhole stimulation history (jobs) and average flow rate growth (production effect) of bottomhole treatment per job (thousand tons) in the Volga-Urals region,, 1H 2008 and 1H 2009
Figure 3-99 History of Rosneft’s artificial lift optimization activities (jobs per year) and average flow rate growth (production effect) per job (thousand tons) in the Volga-Urals region, 2006 to 2008
Figure 3-100 History of Rosneft’s artificial lift optimization activities (jobs per year) and average flow rate growth (production effect) per job (thousand tons) in the Volga-Urals region, 1H 2008 and 1H 2009
Figure 3-101 Overall production effect from Rosneft’s jobs (fracturing, bottomhole stimulation and artificial lift optimization) in the Volga-Urals region, 2006 to 2008, thousand tons per year
Figure 3-102 Overall production effect from Rosneft’s jobs (fracturing, bottomhole stimulation and artificial lift optimization) in the Volga-Urals region, 1H 2008 and 1H 2009, thousand tons
Figure 3-103 Bashneft’s oil production in the Volga-Urals region, 2001 to 2008, thousand tons per year
Figure 3-104 Bashneft’s oil production in the Volga-Urals region, 1H 2008 and 1H 2009, thousand tons
Figure 3-105 Bashneft’s capital expenditures in oil production (million RUR ) and per ton of oil produced, 1H 2008 and 1H 2009, RUR per ton
Figure 3-106 Bashneft’s oil production structure in the Volga-Urals region, 2001 to 2008, thousand tons
Figure 3-107 Bashneft’s oil production structure in the Volga-Urals region, 2001 to 2008, %
Figure 3-108 Bashneft’s oil production structure in the Volga-Urals region, 1H 2008 and 1H 2009, thousand tons
Figure 3-109 Bashneft’s oil production structure in the Volga-Urals region, 1H 2008 and 1H 2009, %
Figure 3-110 Bashneft’s production drilling in the Volga-Urals region, 2001 to 2008, thousand meters per year
Figure 3-111 Bashneft’s production drilling in the Volga-Urals region, 1H 2008 and 1H 2009, thousand meters
Figure 3-112 Bashneft’s development well and production well stocks in the Volga-Urals region, 2001 to 2008, wells
Figure 3-113 Bashneft’s development well and production well stocks in the Volga-Urals region, 1H 2008 and 1H 2009, wells
Figure 3-114 Bashneft’s well flow rates in the Volga-Urals region, 2001 to 2008, tons per day
Figure 3-115 Bashneft’s well flow rates in the Volga-Urals region, 1H 2008 and 1H 2009, tons per day
Figure 3-116 Bashneft’s exploration drilling volumes in the Volga-Urals region, 2001 to 2008, thousand meters per year
Figure 3-117 Bashneft’s exploration drilling volumes in the Volga-Urals region, 1H 2008 and 1H 2009, thousand meters
Figure 3-118 Bashneft’s capital expenditures in production and exploration drilling in the Volga-Urals region, 1H 2008 and 1H 2009, million RUR
Figure 3-119 Bashneft’s workover history (jobs per year), number of crews and average number of workover operations per crew in the Volga-Urals region, 2001 to 2008
Figure 3-120 Average duration of Bashneft’s workover operations (hours) and average costs of well workovers (RUR) in the Volga-Urals region, 2001 to 2008
Figure 3-121 Bashneft’s fracturing history (jobs per year) and average flow rate growth (production effect) per fracturing job (thousand tons) in the Volga-Urals region, 2004 to 2008
Figure 3-122 Bashneft’s fracturing history (jobs) and average flow rate growth (production effect) per fracturing job (thousand tons) in the Volga-Urals region, 1H 2008 and 1H 2009
Figure 3-123 Bashneft’s bottomhole stimulation history (jobs per year) and average flow rate growth (production effect) per bottomhole stimulation job (thousand tons) in the Volga-Urals region, 2001 to 2008
Figure 3-124 Bashneft’s bottomhole stimulation history (jobs) and average flow rate growth (production effect) per bottomhole stimulation job (thousand tons) in the Volga-Urals region, 1H 2008 and 1H 2009
Figure 3-125 Bashneft’s artificial lift optimization activities (jobs per year) and average flow rate growth (production effect) per job (thousand tons) in the Volga-Urals region, 2001 to 2008
Figure 3-126 Bashneft’s artificial lift optimization activities (jobs) and average flow rate growth (production effect) per job (thousand tons) in the Volga-Urals region, 1H 2008 and 1H 2009
Figure 3-127 Overall production effect from Bashneft’s jobs (fracturing, bottomhole stimulation and artificial lift optimization) in the Volga-Urals region, 2006 to 2008, thousand tons per year
Figure 3-128 Overall production effect from Bashneft’s jobs (fracturing, bottomhole stimulation and artificial lift optimization) in the Volga-Urals region , 1H 2008 and 1H 2009, thousand tons
Figure 3-129 Russneft’s oil production in the Volga-Urals region, 2001 to 2008, thousand tons per year
Figure 3-130 Russneft’s oil production in the Volga-Urals region, 1H 2008 and 1H 2009, thousand tons
Figure 3-131 Russneft’s capital expenditures in oil production (million RUR) and per ton of oil produced, 1H 2008 and 1H 2009, RUR per ton
Figure 3-132 Russneft’s oil production structure in the Volga-Urals region, 2001 to 2008, thousand tons
Figure 3-133 Russneft’s oil production structure in the Volga-Urals region, 2001 to 2008, %
Figure 3-134 Russneft’s oil production strucuture in the Volga-Urals region, 1H 2008 and 1H 2009, thousand tons
Figure 3-135 Russneft’s oil production structure in the Volga-Urals region, 1H 2008 and 1H 2009, %
Figure 3-136 Russneft’s production drilling in the Volga-Urals region, 2001 to 2008, thousand meters per year
Figure 3-137 Russneft’s production drilling in the Volga-Urals region, 1H 2008 and 1H 2009, thousand meters
Figure 3-138 Russneft’s development well stock and production well stock in the Volga-Urals region, 2001 to 2008, wells
Figure 3-139 Russneft’s development well stock and production well stock in the Volga-Urals region, 1H 2008 and 1H 2009, wells
Figure 3-140 Russneft’s well flow rates in the Volga-Urals region, 2001 to 2008, tons per day
Figure 3-141 Russneft’s well flow rates in the Volga-Urals region, 1H 2008 and 1H 2009, tons per day
Figure 3-142 Russneft’s exploration drilling volumes in the Volga-Urals region, 2001 to 2008, thousand meters per year
Figure 3-143 Russneft’s exploration drilling volumes in the Volga-Urals region, 1H 2008 and 1H 2009, thousand meters
Figure 3-144 Russneft’s workover history (jobs per year), number of crews and average number of workover jobs per crew in the Volga-Urals region, 2001 to 2008
Figure 3-145 Average duration of Russneft’s workover jobs (hours) and average costs of workover (RUR) in the Volga-Urals region, 2001 to 2008
Figure 3-146 Russneft’s fracturing history (jobs per year) and average flow rate growth (production effect) per fracturing job (thousand tons) in the Volga-Urals region, 2004 to 2008
Figure 3-147 Russneft’s fracturing history (jobs) and average flow rate growth (production effect) per fracturing job (thousand tons) in the Volga-Urals region, 1H 2008 and 1H 2009
Figure 3-148 Bottomhole stimulation history (jobs per year) and average flow rate growth (production effect) per Russneft’s bottomhole stimulation job (thousand tons) in the Volga-Urals region, 2001 to 2008
Figure 3-149 Bottomhole treatment history (jobs) and average flow rate growth (production effect) per Russneft’s bottomhole stimulation job (thousand tons) in the Volga-Urals region, 1H 2008 and 1H 2009
Figure 3-150 Russneft’s history of artificial lift optimization activities (jobs per year) and average flow rate growth (production effect) per job (thousand tons) in the Volga-Urals region, 2001 to 2008
Figure 3-151 Russneft’s history of artificial lift optimization activities (jobs) and average flow rate growth (production effect) per job (thousand tons) in the Volga-Urals region, 1H 2008 and 1H 2009
Figure 3-152 Overall production effect from Russneft’s jobs (fracturing, bottomhole stimulation and artificial lift optimization) in the Volga-Urals region, 2006 to 2008, thousand tons per year
Figure 3-153 Overall production effect from Russneft’s jobs (fracturing, bottomhole stimulation and artificial lift optimization) in the Volga-Urals region, 1H 2008 and 1H 2009, thousand tons
Figure 3-154 Oil production by independent companies in the Volga-Urals region, 2001 to 2008, thousand tons per year
Figure 3-155 Oil production by independent companies in the Volga-Urals region, 1H 2008 and 1H 2009, thousand tons
Figure 3-156 Oil production structure for independent companies in the Volga-Urals region, 2001 to 2008, thousand tons
Figure 3-157 Oil production structure for independent companies in the Volga-Urals region, 2001 to 2008, %
Figure 3-158 Independent companies’ oil production structure in the Volga-Urals region, 1H 2008 and 1H 2009, thousand tons
Figure 3-159 Oil production structure for independent companies in the Volga-Urals region, 1H 2008 and 1H 2009, %
Figure 3-160 Production drilling by independent companies in the Volga-Urals region, 2001 to 2008, thousand meters per year
Figure 3-161 Production drilling by independent companies in the Volga-Urals region, 1H 2008 and 1H 2009, thousand meters
Figure 3-162 Independent company development well stock and production well stocks in the Volga-Urals region, 2001 to 2008, wells
Figure 3-163 Independent company development well stock and production well stock in the Volga-Urals region, 1H 2008 and 1H 2009, wells
Figure 3-164 Independent company well flow rates in the Volga-Urals region, 2001 to 2008, tons per day
Figure 3-165 Independent company well flow rates in the Volga-Urals region, 1H 2008 and 1H 2009, tons per day
Figure 3-166 Independent company exploration drilling volumes in the Volga-Urals region, 2001 to 2008, thousand meters per year
Figure 3-167 Independent company exploration drilling volumes in the Volga-Urals region, 1H 2008 and 1H 2009, thousand meters
Figure 3-168 Independent company workover history (jobs per year), number of crews and average number of workover jobs per crew in the Volga-Urals region, 2001 to 2008
Figure 3-169 Average duration of independent company workover jobs (hours) and average costs of workover (RUR) in the Volga-Urals region, 2001 to 2008
Figure 3-170 Independent company fracturing history (jobs per year) and average flow rate growth (production effect) per fracturing job (thousand tons) in the Volga-Urals region, 2006 to 2008
Figure 3-171 Independent company fracturing history (jobs) and average flow rate growth (production effect) per fracturing job (thousand tons) in the Volga-Urals region, 1H 2008 and 1H 2009
Figure 3-172 Bottomhole stimulation history (jobs per year) and average flow rate growth (production effect) per independent company bottomhole stimulation job (thousand tons) in the Volga-Urals region, 2001 to 2008
Figure 3-173 Bottomhole treatment history (jobs) and average flow rate growth (production effect) per independent company bottomhole stimulation job (thousand tons) in the Volga-Urals region, 1H 2008 and 1H 2009
Figure 3-174 Independent company artificial lift optimization activities history (jobs) and average flow rate growth (production effect) per job (thousand tons) in the Volga-Urals region, 1H 2008 and 1H 2009
Figure 3-175 Overall production effect from independent company jobs (fracturing, bottomhole stimulation and artificial lift optimization) in the Volga-Urals region, 2001 to 2008, thousand tons per year
Figure 3-176 Overall production effect from independent company jobs (fracturing, bottomhole stimulation and artificial lift optimization) in the Volga-Urals region, 1H 2008 and 1H 2009, thousand tons
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