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Subsea Technology Conference 5 December 2005
Musikhuset Esbjerg
Riserless Light Well Intervention&
Through Tubing Rotary Drilling
Asle Solheim
FMC Production Services AS
Floating Production Storage & Offloading Vessels
Turret Mooring Systems
Tension Leg Platforms
Light Well Intervention
GuidelinelessDeepwater Trees
Subsea Manifold
Smart Well Control Systems
Subsea TemplateSystems
Standard Subsea Trees
Metering & Control Systems
Surface Well Systems
ROV Tie-In Systems
Subsea Processing
Subsea Drilling Systems
FMC World Class Subsea SupplierFMC Production Services AS
1980BonitoRJS-39189m
1980BonitoRJS-39189m
Strong Deepwater Track Record
ABB5,605 ftABB
5,605 ft
6,080 ft6,080 ft
2,561 ft2,561 ft
3,368 ft3,368 ft
1,613 ft1,613 ft
619 ft619 ftKvaerner
961 ftKvaerner
961 ft
1983PiraúnaRJS-232
293m
1,256 ft1,256 ft
1985MarimbáRJS-284
383m
1992MarlimMRL-9781m
1988PlacidGreen
Canyon 31684m
ABB2,244 ftABB
2,244 ft
1994MarlimMRL-41027m
1997Marlim Sul
MLS-31709m
1997Shell Mensa
1618m
5,308 ft5,308 ft
1999RoncadorRJS-4361853m
1988MarimbáRJS-376D
492m
2000PetrobrasRoncador
1877m
ABB6,157 ftABB
6,157 ft
2004Shell
Coulomb2307m
Cameron7,209 ft
Cameron7,209 ft
2002MarathonCamden
Hills2197m
7,570 ft7,570 ft
WorldRecord
Number of Operating & Planned Subsea WellsWorldwide 1985 - 2005
0
500
1000
1500
2000
2500
3000
3500
1985
1990
1995
2000
2005
• Operators have focus on:– Safety
– Optimizing rate of production flow
– Increased Oil Recovery from subsea wells
– Reducing OPEX
– Better capitalization of initial CAPEX
– Rig availability
Source: Infield
Norwegian Continental Shelf
0
50
100
150
200
250
300
2002 2006 2010 2014 2018 2022 2026 2030 2034 2038 2042 2046 2050
Year
ly p
rodu
ctio
n of
Oil
& G
as (m
ill S
m3
o.e.
)
New technology, marginal fields etc.
“Generic” well production profile
Q Oil%
100
LWI intervention(plug-reperforation ie)
Break even production line
Initial production profile
Production profileafter intervention
80
60
40
20
0Years1 2 3 4 5 6 7 8
Statoil ambitions
Background:• 250 subsea wells, increasing
60% of Statoil tot. oil production comes from subsea wells, rising
Ambition:• Increase recovery factor for Statoil subsea
fields from 43% today, to 55% by 2009
Means:• Low cost drainage of smaller reservoir pockets, is one of
several projects
Snubbing, Coiled Tubing and WL Tractor operations on Statoil Operated Fields
0
10
20
30
40
50
60
70
80
90
100
110
120
130
140O
pera
tions
pr
Yea
r
1992 1993 1994 1995 1996 1997 1998 1999 2000 2001 2002 2003 2004 H1-2005
Snubbing/RAS: 202 jobs CT: 429 jobs W/L Tractor: 596 jobs LWI: 27 jobs
Subsea Riserless Well InterventionIncreased Oil Recovery
The “Alliance”
“RLWI Alliance”
“Island Offshore Management”Main contractor Vessel owner
Island Offshore Management
Subsea intervention package
Wireline and downholeservices
Island Frontier
Island Frontier
“ISLAND WELLSERVER” 2008•Loa 116 m
•Bmld 25 m
•Draught 8,70 m
•Deck area 1150 m sq.
•Transit speed 14 knots
•Deadweight 8200 tons
Island Wellserver
Pressure Control Head (PCH)
Upper Lubricator Package (ULP)
Lubricator Tubulars (LUB)
Lower Lubricator Package (LLP)
Lower Intervention Package (LIP)
XT connector
Light Well Intervention System• Main System Features
– Subsea flushing, no well fluid to surface
– Riser back-up
– Toolstring lengths up to 22m
– 7-1/16” bore; 10k psi
– Hydrate inhibitor system
– Subsea grease injection system
• Hardware made and tested in 2002-2003.
• Work performed on NCS fields in 2003
• Worked on UK in 2005
• Won 6 years contract for Statoil
Production problems- Water breakthrough- Gas breakthrough- Formation damage- Sand production- Scale
Well Intervention Operations
• Verify fluid properties from different perforated zones
• Install / manipulate various mechanical devices (valves, plugs, screens etc.)
• Well stimulation
• Re-perforation
• Well abandonment
TOPSIDE MODULE HANDLING
Skidding system
– All components placed on skidding pallets and secured to skid-beams
– Hydraulic push/pull units moves components on skid-beams to/from moonpool area
No module assembling offshore
- LIP/LLP ready for deployment placed on skidding pallet in front of MHT
- Lubricator sections assembled and racked back in MHT
Handling on deck
Guided module deployment/retrieval in MHT and through moonpool
Umbilical compensation
Current status - Current contract - Current preparation for Deep water
• FMC light well intervention used on 4 fields (UK sector)
• 6 year contract with Statoil – Island Offshore “Alliance”
Deepwater concept will be developed next 6 months– Wireline – subsea lubricator
– Composite cable
– Coil Tubing Operations
Time Comparison WL Service
(From DEMO 2000)
0
50
100
150
200
250
AnchoredSemi DP Semi Vessel/
Riserless
Hou
rs
Operation
Preparation
Transit
Anchors
Overall time for a 35h wireline operation
The “Alliance” Running and Pulling equipment
0
50
100
150
200
250
Activit
yDP Tria
lRun
Lower
stack
Run U
pper s
tack
Run P
CH and f
lush
Flush an
d Retr
ieve P
CHPull
Upp
er sta
ck
Instal
l Deb
ris ca
p han
d ove
r well
Total
"MSV Regalia" Statfjord"MSV Regalia" Visund"MSV Regalia" Åsgard"Island Frontier" Strathspey
Experience on different trees
Xt Xt type Pressure Wireline operation
FMC 5” Vertical 5000psi Pulling plug, horizontal well using tractor
Kværner 7” Horizontal 10 000psi Repair DHSV
FMC 7” Horizontal 10 000psi PLT
Cameron 5”
Vertical
5000psi Replacing DHSV
Composite cable
• Technology development risk reduced due to:– cable pilot production completed
– prototype injector head and control system tested (2003)
– onshore test part of phase 1
• Tool for extended wirelinecapabilities
• Benefits:– extended reach
– increased payload
– increased power and signal transmission
– facilitates off location operations ieincreased weather window
– facilitates deep water operations
– obsoletes subsea grease injection
• Demo 2000 project supported by Shell and Statoil
Composite Cable Features
PEEK insulationt = 0.4 mm
Copper conductorsø 1.5 mm ~ 1.8 mm2
Carbon fibre in matrix ofepoxy-vinyl-ester
Diameter = Ø 9.00 mm
•Minimum strength: 85 kN (9 tons)
•Smooth and hard surface with
uniform dia for good pressure control
•Low cable weight: 135 kg/km
•Higher toolstring weight
•Lower pull-out forces
•Voltage AC / kW: 3.0 kV / 12 kW
•Voltage DC / kW: 4.2 kV / 20 kW
•Minimum storage diameter: 3.0 m
•Possible to include fibreoptic cable
Length up to 10 000 m
Throuh Tubing Rotary Drilling (TTRD)Statoil Figures
60 MNOK /Point
120 MNOK /Point
Light weight BOP/hp-riser system
Conventional BOP/riser system
Through tubing rotary drilling (TTRD)
• TTRD in place on fixed platform wells
• Cost comparison for operators– Additional well into
existing templates is 70 MUSD
– Side traced well is 10 MUSD
• Coil Tubing Drilling next step?
Focus Area
1. HXT, crown plug seal area
-Crown plug protection
-New TH crown plug
2. DHSV protection
DEBRIS CAP
TREE CAP
BALL VALVE
TUBING HANGER
WELLHEADCONNECTOR
XMAS TREEWING HUB
METHANOLLINE
SERVICELINE
WELLHEADSYSTEM
Thank you !