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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