subsea well intervention: learning from the past - planning for the future
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1 - Classification: Internal 2010-10-18
Subsea well intervention;Learning from the past – planning for the future
UTC 2010
Trond Inge Ramsnes
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2 - Classification: Internal 2010-10-18
Beautiful but demanding
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3 - Classification: Internal 2010-10-18
Optimising reservoir recovery from subsea fields
• Increased fluid handling capacity
• Reduced wellhead pressure
• Integrated Operations
• Identify
−Drainage points
−Well intervention needs and opportunities
Ambition: increase subsea
recovery Cost effective drainage & well intervention
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4 - Classification: Internal 2010-10-18
4
Cumulative wells – Statoil NCS
0
100
200
300
400
500
600
700
1980 1990 2000 2010
Dry trees
Wet trees
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5 - Classification: Internal 2010-10-18
5
Learning from the past – planning for the future
RLWI
Cat B
TT riser
2⅞” CT
• Platforms only to date
• Spoolable connectors
• Sweep cleanouts
TT Drill
TTML
• TTRD platforms and subsea
• CTD (Gullfaks)
• Safe & efficient operations
• Full technical capability including MPD
• Solid base for delivery of through tubing technology
• Backup to RLWI
• Cost efficient• Data collection• Light perforating• Light mechanical wireline
• TTRD• CTD• CT/WL intervention
• Maintain motherbore production
• Access by-passed reserves
• Gullfaks, Veslefrikk
2000
2002
2003
2004
2009
2013
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6 - Classification: Internal 2010-10-18
6
Impact of well intervention – mature asset
0
2000
4000
6000
8000
10000
12000
14000
16000
18000
Jan Feb Mar Apr May Jun Jul Aug Sep Oct Nov Dec
No activity Drill New Maintenance
Oil
Sm3 /D
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7 - Classification: Internal 2010-10-18
Addressing challenges – realising opportunities
Scale build-up in the upper completion
Equipment problems SCSSV
Access problems
Restricted production
Water influx
Wellbore scaling
Access problems
Restricted production
Formation damage (scale, fines, etc.)
Restricted production
“Fishes”
Access problems
Restricted production
Water holdup
Wellbore sanding
Access problems
Restricted production
Completion integrity issues
Milling or high pressure jetting to remove scale
Straddles or patches to repair tubing
Wellbore cleanout, fill removal with long or reverse circulation
Selective zonal isolation, mechanical or chemical
Heavy duty fishing with simultaneous removal of fill
Wellbore unloading with nitrogen
Formation matrix or fracture stimulation
Milling and underreaming to remove wellbore scale
Perforating long sections
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8 - Classification: Internal 2010-10-18
Category ARLWI
Category BFull range intervention & TTD
Category CDrilling and completion
•Wireline / tractor only
•Limited bhalength
•Full range of through tubing services
•Limited live well through tubing services
High pressure light weight
riser (8-5/8”)
Low pressure marine riser (21”) standard
HP concentric riser and SSTT required for live well intervention
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9 - Classification: Internal 2010-10-18
Cat B – fit for purpose concept
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
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10 - Classification: Internal 2010-10-18
LRP/EDP stack on BOP carrier SBOP In rack-back area
Key components in riser system
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11 - Classification: Internal 2010-10-18
Operational Limitations
•WSOG
•Position reference
•Propulsion
•Riser system limitations
•Wellhead limitations
•Drift-off / drive-off
•”Zero Moment Position”
•RMS system used as advisory system for rig positioning
Fatigue monitoring / management
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12 - Classification: Internal 2010-10-18
Experience with TT Riser System• Pilot operation with new system offshore
− new equipment and procedures
• stepwise and constrained progress.
• Improve cleaning after milling and drilling operations.
• No wear of the high pressure riser detected
• RMS
− High focus – used actively
− Relatively nice weather – low utilization
− High angles in Upper Flex Joint
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13 - Classification: Internal 2010-10-1813 - Classification: Internal 2010-04-12
Protecting Horizontal XT (HXT) – used on all pipe runs
HORIZONTAL XMAS TREE
PIGGY BACK WEAR SLEEVE
TUBING HANGER NIPPLE PROTECTOR
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14 - Classification: Internal 2010-10-18
Existing production tubing
Production packer
Whipstock
Through Tubing Sidetrack
SSD
CHOKE
Production from ’motherbore and new sidetrack simultaneously
Through Tubing Drilling (TTD)drilling through existing tubing (completion)
Reservoir
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15 - Classification: Internal 2010-10-18
Operational experience Åsgard P-4
< 300
kSm3
< 100
kSm3
< 50 kSm3
Decreasing target volume
Increasingtargetcount
& reserves
Additional reservesCat B enabled
15
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16 - Classification: Internal 2010-10-18
P-4 AH Actual Drilled Wellpath – Geological Cross Section
Not
Ile 2 & 3Ile 2 & 3
Ror
Tilje 3Tilje 3
TVDMSL
Tilje 1 & 2
Tilje 4, 5, 6
Ile 1
Garn 3 & 4
Garn 1 & 2
T1T1 T2T2 T3T3 T4T4 T5T5
Kick off3871mMDGarn 3
P-4 H mother bore
P-4 AH actual
Drilled a world record of 1744m 5 ¾” TTRD sidetrack
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17 - Classification: Internal 2010-10-18
Production P-4
Initial production
approx. 20 000 boe/d
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18 - Classification: Internal 2010-10-18
Status Category B Services
• 3 Contractors carrying out FEED (Front End Engineering and Design) in the period March - September 2010;
− Aker Oilfield Services
− Helix WellOps
− Saipem
• Bid process ongoing – bid due mid October
• An 8 years “Cat B Services Contract” will be awarded this year
− Operations commencement Q3 2013
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19 - Classification: Internal 2010-10-18
Subsea well intervention;Learning from the past – planning for the future
Trond Inge Ramsnes
Project Leader Well Intervention
[email protected], tel: +47 51 99 00 00
www.statoil.com
Thank you