ior drilling technologies
Post on 06-Dec-2014
2.526 Views
Preview:
DESCRIPTION
TRANSCRIPT
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
Visit www.statoil.com/ONS and stay up to date with the hottest news, latest presentations, vacant positions and more.
top related