Improved Recovery (IOR) in Statoil Improved recovery through drilling and well technologies Terje Schmidt, Alastair Buchanan, Morten Eidem
Improved Recovery (IOR) in StatoilImproved recovery through drilling and well technologies
Terje Schmidt, Alastair Buchanan, Morten Eidem
Annual Process
Idea Phase
1 Oct 1 Mar 1 May 1 Jun1 Nov 1 Jan
Preparation Idea Maturation Project Product
to Capture IOR Ideas & Projects across Statoil
IOR techniques identified in 2010
IOR Techniques Identified in 2010
31 %
26 %6 %
40 %
Drill. & Interv. Low Press. EOR Others
Water injection improvements
How can rapid water break through to producer be controlled?
Water injection assisted by EOR chemicals
• Areal and vertical sweep
• Displacement efficiency
• Injection water quality.
Watersaturation
Dep
th (
m)
1870
1970
0.0
0.2
0.4
0.6
0.8
1.0
0.0
0.2
0.4
0.6
0.8
1.0
0.0
0.2
0.4
0.6
0.8
1.0
Oil
Water
Initial 1993 1995
IRM 05.97 petek.tm.flw
EOR = Enhanced Oil Recovery with a potential of 6%
Low Pressure & Pre-compression
117bar: Expected recovery factors: 60% for gas and 41% for condensate
37 bar: Increase gas recovery factor to 75% and condensate recovery factor to 45%
0
20
40
60
80
100
120
140
160
PDO (2001) Reserve upgrade(2006)
Precomp stage 1(cut-off 2045)
Precomp stage 2(cut-off 2045)
Precomp stage 1& 2 (after 2045)
Res
erve
s, M
Sm
3 o.
e.
Production potential from pre-compression
Compressor module
117bar
37bar15bar
Extensive IOR recovery “toolbox” used by Statoil • Pressure depletion
• Water & Gas Injection
• Microbial
• Chemical & Thermal methods
• Horizontal wells
• Multilateral & Advanced wells
• Liner Drilling
• Managed pressure drilling (MPD)
• Through tubing drilling (TTRD)
• Well Intervention• Topside or Subsea
• Processing & Compression
Through Tubing Drilling and Completion
9 -
Classification: Internal 2010-08-25
Why through tubing drilling & completionExample: Watered out well
Remaining oil
”New” TTDC well
< 300
kSm3
< 100
kSm3
< 50 kSm3
Additional reservesEnabled by new technology and
methods = IOR
Taking the technology subsea
The Statoil Category B initiative (Cat B)
Lightweight HP riser system (through tubing)
Full DP or mooring assisted station keeping options
Topside system sized for through tubing operations
(2⅞” & 3½” drillpipe)
Integrated high capacity coiled tubing package (2 ⅞” / 3½”)
Full handling of live well returns
Semi-submersible rig hull type
Downhole technology developments
Work in progress – delivering resultsTVDMSL
T1T1 T2T2 T3T3 T4T4 T5T5
A world record 1744 m through tubing sidetrack
Steerable Drilling Liner
• Conventional drilling
− Liner has to be run separately after the wellbore section is drilled
− Wellbore is not secured until the liner is installed
• SDL drilling
− Simultaneously drill and secure
− Wellbore always secured
This is Steerable Drilling Liner
More cost effective drilling
• Allow simultaneous drilling and lining of the borehole
− Mitigate challenges with unstable formations
− Reduce Non-Productive Time
• Improved well construction efficiency is crucial for increasing production rate and recovery
Steerable Drilling Liner development
• May 2006: Tender - Baker Hughes submit project proposal
• December 2006: Project initiated
• August 2008: 9 5/8” full scale field test
• April 2009: 7” full scale field test
• August 2009: Worlds first offshore test performed on Brage (9 5/8” liner)
• January 2010: Offshore test executed on Statfjord (7” liner)
• March 2010: Commercial state
Future “One-trip” Steerable Drilling Liner
• Drill liner in place and cement in one run• Improve drilling robustness
• Reduced well construction time
Most efficient measure to keep up the production level and increase
the recovery
Yearly value creation for a “one trip” system fully implemented on the Norwegian Continental Shelf is estimated to NOK 2 billion / year
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