Oilfield Services Market of Western Siberia 2009

Oilfield Services Market of Western Siberia 2009 examines current development trends in the oilfield services segment of Khanty-Mansiysk Autonomous District, Tomsk and Tyumen regions – oil provinces that together have a leading role in Russian oil production (over 60% of total), as well as in production drilling (over 70% of total).

  
Oilfield Services Market of Western Siberia 2009 offers analysis of key market segments:

• on a regional basis
• by operating companies

The unique feature of the report is comparison of operational indicators.

The report also presents a year-by-year comparison (2001-2008) of:

• oil production
• drilling (exploration and production)
• well stock
• well workover
• hydraulic fracturing
• bottom-hole treatment
• artificial lift optimization 

as well as a quarterly comparison (Q1 and Q2 2009) of:

• oil production
• drilling
• capital costs

Oilfield Services Market of Western Siberia 2009 is the second in a series of reports - Russian Oilfield Services Market 2009 - analyzing key factors that shaped the market in 2009 with detailed examination of particular market segments, regions and key players.

Other reports from the series are listed below:

Introduction
 
Chapter 1. Oil Production in Western Siberia
 
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
 
1.2 Capital costs by VIOCs: volumes per ton of produced oil

• H1 2009 compared to H1 2008
• Q2 2009 compared to Q1 2009

 
1.3 Share of oil produced by means of new drilling and intensification methods by VIOCs and independent operators

• 2001-2008
• H1 2009 compared to H1 2008

1.4 Capital costs of production drilling by VIOCs, cost efficiency per drilling footage by VIOCs

• H1 2009 compared to H1 2008
• Q2 2009 compared to Q1 2009

 
1.5 Production drilling and well stock by VIOCs and independent operators

• 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

1.6 Capital costs of exploration drilling by VIOCs, cost efficiency per drilling footage by VIOCs

• H1 2009 compared to H1 2008
• Q2 2009 compared to Q1 2009

 
1.7 Exploration drilling by VIOCs and independent operators

• drilling footage
  - 2001-2008
  - H1 2009 compared to H1 2008
  - Q2 2009 compared to Q1 2009

 
1.8 Well workover by VIOCs and independent operators in 2001-2008

• dynamics of operations
• average cost of operation
• number of crews and their performance (number of operations per crew per year)

 
1.9 Hydraulic fracturing by VIOCs and independent operators

• dynamics of operations
  - 2001-2008
  - H1 2009 compared to H1 2008
  - Q2 2009 compared to Q1 2009
• efficiency of operations and average flow rate growth per operation
  - 2001-2008
  - H1 2009 compared to H1 2008
  - Q2 2009 compared to Q1 2009

 
1.10 Bottom-hole treatment by VIOCs and independent operators

Figure 1.1 Oil production in Western Siberia and other regions from 2001 through 2008, thousand tons
Figure 1.2 Western Siberia in Russia’s total oil production from 2001 through 2008, percent
Figure 1.3 Oil production by VIOCs and independent companies in Western Siberia from 2001 through 2008, thousand tons
Figure 1.4 Oil production by VIOCs and independent companies in Western Siberia in first six months of 2008 and 2009, thousand tons
Figure 1.5 Oil production by VIOCs and independent companies in Western Siberia in first and second quarters of 2009, thousand tons
Figure 1.6 VIOCs’s oil production capex in Western Siberia in first six months of 2008 and 2009, RUR million

Figure 1.7 VIOCs’s oil production capex in Western Siberia in first six months of 2008 and 2009, RUR million

Figure 1.8 VIOCs’s capital expenditures per ton of produced oil in Western Siberia in first six months of 2008 and 2009, RUR/t
Figure 1.9 VIOCs’s capital expenditures per ton of produced oil in Western Siberia in first and second quarters of 2009, RUR/t
Figure 1.10 Structure of oil production by VIOCs and independent companies in Western Siberia from 2001 through 2008, thousand tons
Figure 1.11 Structure of oil production by VIOCs and independent companies in Western Siberia from 2001 through 2008, percent
Figure 1.12 Structure of oil production by VIOCs and independent companies in Western Siberia in first six months of 2008 and 2009, thousand tons
Figure 1.13 Structure of oil production by VIOCs and independent companies in Western Siberia in first six months of 2008 and 2009, percent
Figure 1.14 VIOCs’s capital expenditures in development drilling in Western Siberia in first six months of 2008 and 2009, RUR million
Figure 1.15 VIOCs’s capital expenditures in development drilling in Western Siberia in first and second quarters of 2009, RUR million
Figure 1.16 VIOCs’s capital expenditures in development drilling in Western Siberia in first six months of 2008 and 2009, RUR per meter
Figure 1.17 VIOCs’s capital expenditures in development drilling in Western Siberia in first and second quarters of 2009, RUR per meter
Figure 1.18 Development drilling by VIOCs and independent companies in Western Siberia from 2001 through 2008, thousand meters
Figure 1.19 Development drilling by VIOCs and independent companies in Western Siberia in first six months of 2008 and 2009, thousand meters
Figure 1.20 Development drilling by VIOCs and independent companies in Western Siberia in first and second quarters of 2009, thousand meters
Figure 1.21 New development wells put on stream by VIOCs and independent companies in Western Siberia from 2001 through 2008, wells
Figure 1.22 New development wells put on stream by VIOCs and independent companies in Western Siberia in first six months of 2008 and 2009, wells
Figure 1.23 VIOCs’s and independent companies’ development well stock in Western Siberia from 2001 through 2008, wells
Figure 1.24 VIOCs’s and independent companies’ development well stock in Western Siberia in first six months of 2008 and 2009, wells
Figure 1.25 VIOCs’s and independent companies’ production well stock in Western Siberia from 2001 through 2008, wells
Figure 1.26 VIOCs’s and independent companies’ production well stock in Western Siberia in first six months of 2008 and 2009, wells
Figure 1.27 VIOCs’s and independent companies’ production wells within development well stocks from 2001 through 2008, percent
Figure 1.28 VIOCs’s and independent companies’ production wells within development well stocks in first six months of 2008 and 2009, percent
Figure 1.29 Average calculated daily flow rate in VIOCs’s and independent companies’ development wells in Western Siberia from 2001 through 2008, t/day
Figure 1.30 Average calculated daily flow rate in VIOCs’s and independent companies’ development wells in Western Siberia in first six months of 2008 and 2009, t/day
Figure 1.31 Average calculated daily flow rate in VIOCs’s and independent companies’ new development wells in Western Siberia from 2001 through 2008, t/day
Figure 1.32 Average calculated daily flow rate in VIOCs’s and independent companies’ new development wells in Western Siberia in first six months of 2008 and 2009, t/day
Figure 1.33 VIOCs’s capital expenditures in exploration drilling in Western Siberia in first six months of 2008 and 2009, RUR million
Figure 1.34 VIOCs’s capital expenditures in exploration drilling in Western Siberia in first and second quarters of 2009, RUR million
Figure 1.35 VIOCs’s capital expenditures in exploration drilling in Western Siberia in first six months of 2008 and 2009, RUR per meter
Figure 1.36 VIOCs’s capital expenditures in exploration drilling in Western Siberia in first and second quarters of 2009, RUR per meter
Figure 1.37 Exploration drilling by VIOCs and independent companies in Western Siberia from 2001 through 2008, thousand m
Figure 1.38 Exploration drilling by VIOCs and independent companies in Western Siberia in first six months of 2008 and 2009, thousand m
Figure 1.39 Exploration drilling by VIOCs and independent companies in Western Siberia in first and second quarters of 2009, thousand m
Figure 1.40 VIOCs’s and independent companies’ workover history in Western Siberia from 2001 through 2008, operations
Figure 1.41 Average cost of workovers for VIOCs and independent companies in Western Siberia from 2001 through 2008, RUR thousand
Figure 1.42 Average operating number of workover crews at VIOCs and independent companies in Western Siberia from 2001 through 2008
Figure 1.43 Productivity of workover crews at VIOCs and independent companies in Western Siberia from 2001 through 2008, operations per crew per year
Figure 1.44 VIOCs’s and independent companies’ fracturing history in Western Siberia from 2001 through 2008

Figure 1.45 VIOCs’s and independent companies’ fracturing history in Western Siberia in first six months of 2008 and 2009
Figure 1.46 VIOCs’s and independent companies’ fracturing history in Western Siberia in first and second quarters of 2009
Figure 1.47 Total fracturing efficiency at VIOCs and independent companies in Western Siberia from 2001 through 2008, thousand tons
Figure 1.48 Total fracturing efficiency at VIOCs and independent companies in Western Siberia in first six months of 2008 and 2009, thousand tons
Figure 1.49 Total fracturing efficiency at VIOCs and independent companies in Western Siberia in first and second quarters of 2009, thousand tons
Figure 1.50 Average flow rate growth per fracturing job at VIOCs and independent companies in Western Siberia from 2001 through 2008, thousand tons
Figure 1.51 Average flow rate growth per fracturing job at VIOCs and independent companies in Western Siberia in first six months of 2008 and 2009, thousand tons
Figure 1.52 Average flow rate growth per fracturing job at VIOCs and independent companies in Western Siberia in first and second quarters of 2009, thousand tons
Figure 1.53 VIOCs’s and independent companies’ bottomhole treatment history in Western Siberia from 2001 through 2008
Figure 1.54 VIOCs’s and independent companies’ bottomhole treatment history in Western Siberia in first six months of 2008 and 2009
Figure 1.55 VIOCs’s and independent companies’ bottomhole treatment history in Western Siberia in first and second quarters of 2009
Figure 1.56 Total bottomhole treatment efficiency at VIOCs and independent companies in Western Siberia from 2001 through 2008, thousand tons
Figure 1.57 Total bottomhole treatment efficiency at VIOCs and independent companies in Western Siberia in first six months of 2008 and 2009, thousand tons
Figure 1.58 Total bottomhole treatment efficiency at VIOCs and independent companies in Western Siberia in first and second quarters of 2009, thousand tons
Figure 1.59 Average flow rate growth per bottomhole treatment job at VIOCs and independent companies in Western Siberia from 2001 through 2008, thousand tons
Figure 1.60 Average flow rate growth per bottomhole treatment job at VIOCs and independent companies in Western Siberia in first six months of 2008 and 2009, thousand tons
Figure 1.61 Average flow rate growth per bottomhole treatment job at VIOCs and independent companies in Western Siberia in first and second quarters of 2009, thousand tons
Figure 1.62 VIOCs’s and independent companies’ enhanced recovery history in Western Siberia from 2001 through 2008
Figure 1.64 VIOCs’s and independent companies’ enhanced recovery history in Western Siberia in first and second quarters of 2009
Figure 1.65 Total enhanced recovery efficiency at VIOCs and independent companies in Western Siberia from 2001 through 2008, thousand tons
Figure 1.66 Total enhanced recovery efficiency at VIOCs and independent companies in Western Siberia in first six months of 2008 and 2009, thousand tons
Figure 1.67 Total enhanced recovery efficiency at VIOCs and independent companies in Western Siberia in first and second quarters of 2009, thousand tons
Figure 1.68 Average flow rate growth per enhanced recovery operation at VIOCs and independent companies in Western Siberia from 2001 through 2008, thousand tons
Figure 1.69 Average flow rate growth per enhanced recovery operation at VIOCs and independent companies in Western Siberia in first six months of 2008 and 2009, thousand tons
Figure 1.70 Average flow rate growth per enhanced recovery operation at VIOCs and independent companies in Western Siberia in first and second quarters of 2009, thousand tons
Figure 2.1.1 LUKOIL’s oil production in Western Siberia from 2001 through 2008, thousand tons
Figure 2.1.2 LUKOIL’s oil production in Western Siberia in first six months of 2008 and 2009, thousand tons
Figure 2.1.3 LUKOIL’s oil production in Western Siberia in first and second quarters of 2009, thousand tons
Figure 2.1.4 LUKOIL’s capital expenditures per ton of produced oil in first six months of 2008 and 2009
Figure 2.1.5 LUKOIL’s capital expenditures per ton of produced oil in first and second quarters of 2009
Figure 2.1.6 LUKOIL’s oil production structure in Western Siberia from 2001 through 2008, percent
Figure 2.1.7 LUKOIL’s oil production structure in Western Siberia from 2001 through 2008, thousand tons
Figure 2.1.8 LUKOIL’s oil production structure in Western Siberia in first six months of 2008 and 2009, thousand tons
Figure 2.1.9 LUKOIL’s oil production structure in Western Siberia in first six months of 2008 and 2009, percent

Figure 2.1.10 LUKOIL’s capital expenditures in development and exploration drilling in Western Siberia in first six months of 2008 and 2009
Figure 2.1.11 LUKOIL’s capital expenditures in development and exploration drilling in Western Siberia in first and second quarters of 2009
Figure 2.1.12 LUKOIL’s development drilling in Western Siberia from 2001 through 2008, thousand m
Figure 2.1.13 LUKOIL’s development drilling in Western Siberia in first six months of 2008 and 2009, thousand m
Figure 2.1.14 LUKOIL’s development drilling in Western Siberia in first and second quarters of 2009, thousand m
Figure 2.1.15 LUKOIL’s development well stock and its efficiency in Western Siberia from 2001 through 2008

Figure 2.1.16 LUKOIL’s development well stock and its efficiency in Western Siberia in first six months of 2008 and 2009
Figure 2.1.17 LUKOIL’s average calculated daily flow rate in new and development wells, new wells put on stream in Western Siberia from 2001 through 2008
Figure 2.1.18 LUKOIL’s average calculated daily flow rate in new and development wells, new wells put on stream in Western Siberia in first six months of 2008 and 2009
Figure 2.1.19.LUKOIL’s exploration meterage in Western Siberia from 2001 through 2008, thousand m
Figure 2.1.20 LUKOIL’s exploration meterage in Western Siberia in first six months of 2008 and 2009, thousand m
Figure 2.1.21 LUKOIL’s exploration meterage in Western Siberia in first and second quarters of 2009, thousand m
Figure 2.1.22 LUKOIL’s workover history, number and productivity of crews in Western Siberia from 2001 through 2008
Figure 2.1.23 Average duration and cost of LUKOIL’s workover operations in Western Siberia from 2001 through 2008
Figure 2.1.24 Comparative efficiency of LUKOIL’s well stimulation operations in Western Siberia from 2001 through 2008, thousand tons
Figure 2.1.25 Comparative efficiency of LUKOIL’s well stimulation operations in Western Siberia in first six months of 2008 and 2009, thousand tons
Figure 2.1.26 History and efficiency of LUKOIL’s fracturing operations in Western Siberia from 2004 through 2008
Figure 2.1.27 History and average flow rate growth of LUKOIL’s fracturing per operation in Western Siberia in first six months of 2008 and 2009
Figure 2.1.28 History and average flow rate growth of LUKOIL’s bottomhole treatment per operation in Western Siberia from 2001 through 2008
Figure 2.1.29 History and average flow rate growth of LUKOIL’s bottomhole treatment per operation in Western Siberia in first six months of 2008 and 2009
Figure 2.1.30 History and average flow rate growth of LUKOIL’s enhanced recovery per operation in Western Siberia from 2001 through 2008
Figure 2.1.31 History and average flow rate growth of LUKOIL’s enhanced recovery per operation in Western Siberia in first six months of 2008 and 2009
Figure 2.2.1 TNK-BP’s oil production in Western Siberia from 2001 through 2008, thousand tons
Figure 2.2.2 TNK-BP’s oil production in Western Siberia in first six months of 2008 and 2009
Figure 2.2.3 TNK-BP’s oil production in Western Siberia in first and second quarters of 2009
Figure 2.2.4 TNK-BP’s capital expenditures per ton of produced oil in first six months of 2008 and 2009
Figure 2.2.5 TNK-BP’s capital expenditures per ton of produced oil in first
Figure 2.2.6 TNK-BP’s oil production structure in Western Siberia from 2001 through 2008, thousand tons
Figure 2.2.7 TNK-BP’s oil production structure in Western Siberia from 2001 through 2008, percent
Figure 2.2.8 TNK-BP’s oil production structure in Western Siberia in first six months of 2008 and 2009, thousand tons
Figure 2.2.9 TNK-BP’s oil production structure in Western Siberia in first six months of 2008 and 2009, percent

Figure 2.2.10 TNK-BP’s capital expenditures in development and exploration drilling in Western Siberia in first six months of 2008 and 2009
Figure 2.2.11 TNK-BP’s capital expenditures in development and exploration drilling in Western Siberia in first and second quarters of 2009
Figure 2.2.12 TNK-BP’s development drilling in Western Siberia from 2001 through 2008, thousand m
Figure 2.2.13 TNK-BP’s development drilling in Western Siberia in first six months of 2008 and 2009, thousand m
Figure 2.2.14 TNK-BP’s development drilling in Western Siberia in first and second quarters of 2009, thousand m
Figure 2.2.15 TNK-BP’s development well stock and its efficiency in Western Siberia from 2001 through 2008

Figure 2.2.16 TNK-BP’s development well stock and its efficiency in Western Siberia in first six months of 2008 and 2009
Figure 2.2.17 TNK-BP’s average calculated daily flow rate in new and development wells, new wells put on stream in Western Siberia from 2001 through 2008
Figure 2.2.18 TNK-BP’s average calculated daily flow rate in new and development wells, new wells put on stream in Western Siberia in first six months of 2008 and 2009
Figure 2.1.19 TNK-BP’s exploration meterage in Western Siberia from 2001 through 2008, thousand m
Figure 2.2.20 TNK-BP’s exploration meterage in Western Siberia in first six months of 2008 and 2009, thousand m
Figure 2.2.21 TNK-BP’s exploration meterage in Western Siberia in first and second quarters of 2009 Figure 2.2.22 TNK-BP’s workover history, number and productivity of crews in Western Siberia from 2001 through 2008
Figure 2.2.23 Average duration and cost of TNK-BP’s workover operations in Western Siberia from 2001 through 2008
Figure 2.2.24 Comparative efficiency of TNK-BP’s well stimulation operations in Western Siberia from 2001 through 2008, thousand tons
Figure 2.2.25 Comparative efficiency of TNK-BP’s well stimulation operations in Western Siberia in first six months of 2008 and 2009, thousand tons
Figure 2.2.26 History and efficiency of TNK-BP’s fracturing operations in Western Siberia from 2003 through 2008
Figure 2.2.27 History and average flow rate growth of TNK-BP’s fracturing per operation in Western Siberia in first six months of 2008 and 2009
Figure 2.2.28 History and average flow rate growth of TNK-BP’s bottomhole treatment per operation in Western Siberia from 2001 through 2008
Figure 2.2.29 History and average flow rate growth of TNK-BP’s bottomhole treatment per operation in Western Siberia in first six months of 2008 and 2009
Figure 2.2.30 History and average flow rate growth of TNK-BP’s enhanced recovery per operation in Western Siberia from 2001 through 2008
Figure 2.2.31 History and average flow rate growth of TNK-BP’s enhanced recovery per operation in Western Siberia in first six months of 2008 and 2009
Figure 2.3.1 Surgutneftegaz’s oil production in Western Siberia from 2001 through 2008, thousand tons
Figure 2.3.2 Surgutneftegaz’s oil production in Western Siberia in first six months of 2008 and 2009
Figure 2.3.3 Surgutneftegaz’s oil production in Western Siberia in first and second quarters of 2009
Figure 2.3.4 Surgutneftegaz’s oil production capex per ton of produced oil in first six months of 2008 and 2009
Figure 2.3.5 Surgutneftegaz’s capital expenditures per ton of produced oil in first
Figure 2.3.6 Surgutneftegaz’s oil production structure in Western Siberia from 2001 through 2008, thousand tons
Figure 2.3.7 Surgutneftegaz’s oil production structure in Western Siberia from 2001 through 2008, percent
Figure 2.3.8 Surgutneftegaz’s oil production structure in Western Siberia in first six months of 2008 and 2009, thousand tons
Figure 2.3.9 Surgutneftegaz’s oil production structure in Western Siberia in first six months of 2008 and 2009, percent
Figure 2.3.10 Surgutneftegaz’s capital expenditures in development and exploration drilling in Western Siberia in first six months of 2008 and 2009
Figure 2.3.11 Surgutneftegaz’s capital expenditures in development and exploration drilling in Western Siberia in first and second quarters of 2009
Figure 2.3.12 Surgutneftegaz’s development drilling in Western Siberia from 2001 through 2008, thousand m
Figure 2.3.13 Surgutneftegaz’s development drilling in Western Siberia in first six months of 2008 and 2009, thousand m
Figure 2.3.14 Surgutneftegaz’s development drilling in Western Siberia in first and second quarters of 2009, thousand m
Figure 2.3.15 Surgutneftegaz’s development well stock and its efficiency in Western Siberia from 2001 through 2008
Figure 2.3.16 Surgutneftegaz’s development well stock and its efficiency in Western Siberia in first six months of 2008 and 2009
Figure 2.3.17 Surgutneftegaz’s average calculated daily flow rate in new and development wells, new wells put on stream in Western Siberia from 2001 through 2008
Figure 2.3.18 Surgutneftegaz’s average calculated daily flow rate in new and development wells, new wells put on stream in Western Siberia in first six months of 2008 and 2009
Figure 2.3.19 Surgutneftegaz’s exploration meterage in Western Siberia from 2001 through 2008, thousand m

Figure 2.3.20 Surgutneftegaz’s exploration meterage in Western Siberia in first six months of 2008 and 2009, thousand m
Figure 2.3.21 Surgutneftegaz’s exploration meterage in Western Siberia in first and second quarters of 2009
Figure 2.3.22 Surgutneftegaz’s workover history, number and productivity of crews in Western Siberia from 2001 through 2008
Figure 2.3.23 Average duration and cost of Surgutneftegaz’s workover operations in Western Siberia from 2001 through 2008
Figure 2.3.24 Comparative efficiency of Surgutneftegaz’s well stimulation operations in Western Siberia from 2001 through 2008, thousand tons
Figure 2.3.25 Comparative efficiency of Surgutneftegaz’s well stimulation operations in Western Siberia in first six months of 2008 and 2009, thousand tons
Figure 2.3.26 History and efficiency of Surgutneftegaz’s fracturing operations in Western Siberia from 2001 through 2008
Figure 2.3.27 History and average flow rate growth of Surgutneftegaz’s fracturing per operation in Western Siberia in first six months of 2008 and 2009
Figure 2.3.28 History and average flow rate growth of Surgutneftegaz’s bottomhole treatment per operation in Western Siberia from 2001 through 2008
Figure 2.3.29 History and average flow rate growth of Surgutneftegaz’s bottomhole treatment per operation in Western Siberia in first six months of 2008 and 2009
Figure 2.3.30 History and average flow rate growth of Surgutneftegaz’s enhanced recovery per operation in Western Siberia from 2001 through 2008
Figure 2.3.31 History and average flow rate growth of Surgutneftegaz’s enhanced recovery per operation in Western Siberia in first six months of 2008 and 2009
Figure 2.4.1 Rosneft’s oil production in Western Siberia from 2005 through 2008
Figure 2.4.2 Rosneft’s oil production in Western Siberia in first six months of 2008 and 2009
Figure 2.4.3 Rosneft’s oil production in Western Siberia in first and second quarters of 2009
Figure 2.4.4 Rosneft’s capital expenditures per ton of produced oil in first six months of 2008 and 2009
Figure 2.4.5 Rosneft’s capital expenditures per ton of produced oil in first
Figure 2.4.6 Rosneft’s oil production structure in Western Siberia from 2005 through 2008, thousand tons
Figure 2.4.7 Rosneft’s oil production structure in Western Siberia from 2001 through 2008, percent
Figure 2.4.8 Rosneft’s oil production structure in Western Siberia in first six months of 2008 and 2009, thousand tons
Figure 2.4.9 Rosneft’s oil production structure in Western Siberia in first six months of 2008 and 2009, percent

Figure 2.4.10 Rosneft’s capital expenditures in development and exploration drilling in Western Siberia in first six months of 2008 and 2009
Figure 2.4.11 Rosneft’s capital expenditures in development and exploration drilling in Western Siberia in first and second quarters of 2009
Figure 2.4.12 Rosneft’s development drilling in Western Siberia from 2005 through 2008, thousand m
Figure 2.4.13 Rosneft’s development drilling in Western Siberia in first six months of 2008 and 2009, thousand m
Figure 2.4.14 Rosneft’s development drilling in Western Siberia in first and second quarters of 2009, thousand m
Figure 2.4.15 Rosneft’s development well stock and its efficiency in Western Siberia from 2005 through 2008

Figure 2.4.16 Rosneft’s development well stock and its efficiency in Western Siberia in first six months of 2008 and 2009
Figure 2.4.17 Rosneft’s average calculated daily flow rate in new and development wells, new wells put on stream in Western Siberia from 2005 through 2008
Figure 2.4.18 Rosneft’s average calculated daily flow rate in new and development wells, new wells put on stream in Western Siberia in first six months of 2008 and 2009
Figure 2.4.19 Rosneft’s exploration meterage in Western Siberia from 2005 through 2008, thousand m
Figure 2.4.20 Rosneft’s exploration meterage in Western Siberia in first six months of 2008 and 2009, thousand m
Figure 2.4.21 Rosneft’s exploration meterage in Western Siberia in first and second quarters of 2009
Figure 2.4.22 Rosneft’s workover history, number and productivity of crews in Western Siberia from 2005 through 2008
Figure 2.4.23 Average duration and cost of Rosneft’s workover operations in Western Siberia from 2005 through 2008

Figure 2.4.24 Comparative efficiency of Rosneft’s well stimulation operations in Western Siberia from 2005 through 2008, thousand tons
Figure 2.4.25 Comparative efficiency of Rosneft’s well stimulation operations in Western Siberia in first six months of 2008 and 2009, thousand tons
Figure 2.4.26 History and efficiency of Rosneft’s fracturing operations in Western Siberia from 2005 through 2008
Figure 2.4.27 History and average flow rate growth of Rosneft’s fracturing per operation in Western Siberia in first six months of 2008 and 2009
Figure 2.4.28 History and average flow rate growth of Rosneft’s bottomhole treatment per operation in Western Siberia from 2005 through 2008
Figure 2.4.29 History and average flow rate growth of Rosneft’s bottomhole treatment per operation in Western Siberia in first six months of 2008 and 2009
Figure 2.4.30 History and average flow rate growth of Rosneft’s enhanced recovery per operation in Western Siberia from 2005 through 2008
Figure 2.4.31 History and average flow rate growth of Rosneft’s enhanced recovery per operation in Western Siberia in first six months of 2008 and 2009
Figure 2.5.1 Gazprom Neft’s oil production in Western Siberia from 2001 through 2008, thousand tons
Figure 2.5.2 Gazprom Neft’s oil production in Western Siberia in H1 2008 and H1 2009
Figure 2.5.3 Gazprom Neft’s oil production in Western Siberia in Q1 and Q2 2009
Figure 2.5.4 Gazprom Neft’s oil production capex per ton of oil produced in H1 2008 and H1 2009
Figure 2.5.5 Gazprom Neft’s oil production capex per ton of oil produced in Q1 2009 and Q2 2009
Figure 2.5.6 Gazprom Neft’s oil production structure in Western Siberia from 2001 through 2008, thousand tons
Figure 2.5.7 Gazprom Neft’s oil production structure in Western Siberia from 2001 through 2008, percent
Figure 2.5.8 Gazprom Neft’s oil production structure in Western Siberia in H1 2008 and H1 2009, thousand tons
Figure 2.5.9 Gazprom Neft’s oil production structure in Western Siberia in H1 2008 and H1 2009, percent
Figure 2.5.10 Gazprom Neft’s capital investments in production and exploration drilling in Western Siberia in H1 2008 and H1 2009
Figure 2.5.11 Gazprom Neft’s capital investments in production and exploration drilling in Western Siberia in Q1 2009 and Q2 2009
Figure 2.5.12 Gazprom Neft’s production drilling in Western Siberia from 2001 through 2008, thousand m
Figure 2.5.13 Gazprom Neft’s production drilling in Western Siberia in H1 2008 and H1 2009, thousand m
Figure 2.5.14 Gazprom Neft’s production drilling in Western Siberia in Q1 2009 and Q2 2009, thousand m
Figure 2.5.15 Gazprom Neft’s production well stock and its efficiency in Western Siberia from 2001 through 2008
Figure 2.5.16 Gazprom Neft’s production well stock and its efficiency in Western Siberia in H1 2008 and H1 2009
Figure 2.5.17 Gazprom Neft’s average design daily flow rate in new and production wells, new wells put on stream in Western Siberia from 2001 through 2008
Figure 2.5.18 Gazprom Neft’s average design daily flow rate in new and development wells, new wells put on stream in Western Siberia in H1 2008 and H1 2009
Figure 2.5.19 Gazprom Neft’s exploration footage in Western Siberia from 2006 through 2008, thousand m
Figure 2.5.20 Gazprom Neft’s exploration footage in Western Siberia in H1 2008 and H1 2009, thousand m
Figure 2.5.21 Overall efficiency of Gazprom Neft’s well stimulation operations in Western Siberia from 2003 through 2008, thousand tons
Figure 2.5.22 Overall efficiency of Gazprom Neft’s well stimulation operations in Western Siberia in H1 2008 and H1 2009, thousand tons
Figure 2.5.23 Historical efficiency of Gazprom Neft’s hydraulic fracturing per operation in Western Siberia from 2004 through 2008
Figure 2.5.24 Historical efficiency of Gazprom Neft’s hydraulic fracturing per operation in Western Siberia in H1 2008 and H1 2009
Figure 2.5.25 Historical average flow rate growth of Gazprom Neft’s bottomhole treatment per operation in Western Siberia from 2004 through 2008
Figure 2.5.26 Historical average flow rate growth of Gazprom Neft’s bottomhole treatment per operation in Western Siberia in H1 2008 and H1 2009
Figure 2.5.27 Historical average flow rate growth of Gazprom Neft’s well operation optimization per operation in Western Siberia from 2003 through 2008
Figure 2.5.28 Historical average flow rate growth of Gazprom Neft’s well operation optimization per operation in Western Siberia in H1 2008 and H1 2009
Figure 2.6.1 Slavneft’s oil production in Western Siberia from 2001 through 2008, thousand tons
Figure 2.6.2 Slavneft’s oil production in Western Siberia in H1 2008 and H1 2009 thousand tons
Figure 2.6.3 Slavneft’s oil production in Western Siberia in Q1 2009 and Q2 2009, thousand tons
Figure 2.6.4 Slavneft’s capital expenditures in oil production on Western Siberia per ton of oil produced in H1 2008 and H1 2009
Figure 2.6.5 Slavneft’s capital expenditures in oil production on Western Siberia per ton of oil produced in Q1 2009 and Q2 2009
Figure 2.6.6 Slavneft’s oil production structure in Western Siberia from 2001 through 2008, thousand tons
Figure 2.6.7 Slavneft’s oil production structure in Western Siberia in H1 2008 and H1 2009, percent
Figure 2.6.8 Slavneft’s oil production structure in Western Siberia in H1 2008 and H1 2009, thousand tons
Figure 2.6.9 Slavneft’s oil production structure in Western Siberia in H1 2008 and H1 2009, percent
Figure 2.6.10 Slavneft’s capital investments in production and exploration drilling in Western Siberia in H1 and H1 2009
Figure 2.6.11 Slavneft’s capital investments in production and exploration drilling in Western Siberia in Q1 2009 and Q2 2009
Figure 2.6.12 Slavneft’s production drilling in Western Siberia from 2001 through 2008, thousand m
Figure 2.6.13 Slavneft’s production drilling in Western Siberia in H1 2008 and H1 2009, thousand m
Figure 2.6.14 Slavneft’s production drilling in Western Siberia in Q1 2009 and Q2 2009, thousand m
Figure 2.6.15 Slavneft’s production well stock and its efficiency in Western Siberia from 2001 through 2008
Figure 2.6.16 Slavneft’s production well stock and its efficiency in Western Siberia in H1 2008 and H1 2009
Figure 2.6.17 Slavneft’s average design daily flow rate in new and production wells, new wells put on stream in Western Siberia from 2001 through 2008
Figure 2.6.18 Slavneft’s average design daily flow rate in new and production wells, new wells put on stream in Western Siberia in H1 2008 and H1 2009
Figure 2.6.19 Slavneft’s exploration footage in Western Siberia from 2001 through 2008, thousand m
Figure 2.6.20 Slavneft’s exploration footage in Western Siberia in H1 2008 and H1 2009, thousand m
Figure 2.6.21 Slavneft’s workover history, number and productivity of crews in Western Siberia from 2001 through 2008
Figure 2.6.22 Average duration and cost of Slavneft’s workover operations in Western Siberia from 2001 through 2008

Figure 2.6.23 Overall efficiency of Slavneft’s well stimulation operations in Western Siberia from 2001 through 2008, thousand tons
Figure 2.6.24 Overall efficiency of Slavneft’s well stimulation operations in Western Siberia in H1 2008 and H1 2009, thousand tons
Figure 2.6.25 Historical efficiency of Slavneft’s hydraulic fracturing per operation in Western Siberia from 2004 through 2008
Figure 2.6.26 Historical efficiency of Slavneft’s hydraulic fracturing per operation in Western Siberia in H1 2008 and H1 2009
Figure 2.6.27 Historical average flow rate growth of Slavneft’s bottomhole treatment per operation in Western Siberia from 2001 through 2008
Figure 2.6.28 Historical average flow rate growth of Slavneft’s bottomhole treatment per operation in Western Siberia in H1 2008 and H1 2009
Figure 2.6.29 Historical average flow rate growth of Slavneft’s well operation optimization per operation in Western Siberia from 2001 through 2008
Figure 2.6.30 Historical average flow rate growth of Slavneft’s well operation optimization per operation in Western Siberia in H1 2008 and H1 2009
Figure 2.7.1 RussNeft’s oil production in Western Siberia from 2001 through 2008, thousand tons
Figure 2.7.2 RussNeft’s oil production in Western Siberia in H1 2008 and H1 2009 thousand tons
Figure 2.7.3 RussNeft’s oil production in Western Siberia in Q1 2009 and Q2 2009, thousand tons
Figure 2.7.4 RussNeft’s oil production capex per ton of oil produced in H1 2008 and H1 2009
Figure 2.7.5 RussNeft’s oil production capex per ton of oil produced in Q1 2009 and Q2 2009
Figure 2.7.6 RussNeft’s oil production structure in Western Siberia from 2001 through 2008, thousand tons
Figure 2.7.7 RussNeft’s oil production structure in Western Siberia from 2001 through 2008, percent
Figure 2.7.8 RussNeft’s oil production structure in Western Siberia in H1 2008 and H1 2009, thousand tons
Figure 2.7.9 RussNeft’s oil production structure in Western Siberia in H1 2008 and H1 2009, percent
Figure 2.7.10 RussNeft’s capital investments for production and exploration drilling in Western Siberia in H1 2008 and H1 2009
Figure 2.7.11 RussNeft’s capital investments in production and exploration drilling in Western Siberia in Q1 2009 and Q2 2009
Figure 2.7.12 RussNeft’s production drilling footage drilling in Western Siberia from 2001 through 2008, thousand m
Figure 2.7.13 RussNeft’s production drilling footage in Western Siberia in H1 2008 and H1 2009, thousand m
Figure 2.7.14 RussNeft’s production drilling footage in Western Siberia in Q1 2009 and Q2 2009, thousand m
Figure 2.7.15 RussNeft’s production well stock and its efficiency in Western Siberia from 2001 through 2008

Figure 2.7.16 RussNeft’s production well stock and its efficiency in Western Siberia in H1 2008 and H1 2009

Figure 2.7.17 RussNeft’s average design daily flow rate in new and production wells, new wells put on stream in Western Siberia from 2001 through 2008
Figure 2.7.18 RussNeft’s average design daily flow rate in new and production wells, new wells put on stream in Western Siberia in H1 2008 and H1 2009
Figure 2.7.19 RussNeft’s exploration footage in Western Siberia from 2001 through 2008, thousand m
Figure 2.7.20 RussNeft’s exploration footage in Western Siberia in H1 2008 and H1 2009, thousand m
Figure 2.7.21 RussNeft’s workover history, number and productivity of crews in Western Siberia from 2001 through 2008
Figure 2.7.22 Average duration and cost of RussNeft’s workover operations in Western Siberia from 2001 through 2008
Figure 2.7.23 Overall efficiency of Slavneft’s well stimulation operations in Western Siberia from 2001 through 2008, thousand tons
Figure 2.7.24 Overall efficiency of RussNeft’s well stimulation operations in Western Siberia in H1 2008 and H1 2009, thousand tons
Figure 2.7.25 Historical efficiency of RussNeft’s hydraulic fracturing per operation in Western Siberia from 2004 through 2008
Figure 2.7.26 Historical efficiency of RussNeft’s hydraulic fracturing per operation in Western Siberia in H1 2008 and H1 2009

Figure 2.7.27 Historical average flow rate growth of RussNeft’s bottomhole treatment per operation in Western Siberia from 2001 through 2008
Figure 2.7.28 Historical average flow rate growth of RussNeft’s bottomhole treatment per operation in

Western Siberia in H1 2008 and H1 2009
Figure 2.7.29 Historical average flow rate growth of RussNeft’s well operation optimization per operation in Western Siberia from 2001 through 2008
Figure 2.7.30 Historical average flow rate growth of RussNeft’s well operation optimization per operation in Western Siberia