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DEVEX 2012 9th European Production and Development Conference
Van Ghent Tri-lateral oil and gas development
An integrated challenge
Completion concept & execution
Dave McKellar
Required
Wanted
Maximum reservoir exposure, tri-lateral, intelligent,
auto-gas lift, subsea well
Is it possible??
Can screens be run in a 2000m horizontal well (P11-A-03 was 1100m
maximum.
Is it possible to install 6 control lines for the downhole valves in a sub-sea
tree?
Do we dare? What are the risks? What are the rewards?
GAS LEG (S3)
TVD S1 = TVD S2
2000M LATERALS COMPLETED WITH
WIRE-WRAPPED SCREENS
WITH ICDS
GAS FLOW
HYDRAULICALLY OPERATED
GAS FLOW CONTROL CHOKE
HYDRAULICALLY OPERATED
OIL FLOW CONTROL VALVE
OIL FLOW FROM 2 LEGS
TAML LEVEL 5 JUNCTION (SEALING)
TAML LEVEL 3 JUNCTION (NON-SEALING)
9 5/8” CASING SHOE
@ 90 DEGREES
CO-MINGLED FLOW
MULTIPLE CONTROL LINES
100-200M LATERAL COMPLETED WITH
SAND SCREENS
PRESSURE & TEMP. GAUGE
PRODUCTION PACKER
4-1/2” TUBING ± 600m AH
3-1/2” TUBING ± 1200m AH
BLUE PIPE IS 13%CR
OIL LEG #2 (S2)
OIL LEG #1 (S1)
P11-C-01 Completion Concept
Oil leg #2
Casing 9-5/8" 53.5#
S1
S2
Liner HangerS-3 HOOK Hanger
S-Liner Swivel Screen Section Bend Joint
Tieback 600m
Casing 9-5/8" 53.5#
S1
S2
Bend Joint
4½" Tubing
Fluid Loss Control Valve
Seal Bore Extension
9.625" Completion Packer
7”cemented liner + gas leg
Casing 9-5/8" 53.5#
S1
S2
Drillable Pack-Off BushingS Liner SwivelHOOK Hanger
Liner Hanger assembly
6" Reservoir Seaction
S3
Gas leg screens & tieback
Casing 9-5/8" 53.5#
S1
S2
Fluid Loss Control Valve
Seal Bore Extension
Completion Packer
S3
Locator Seal Stem
Level 5 dual seal assembly
S1
S2
Lateral Seal Stem
Seal Bore Extension
Dual Seal Module
S3
Tubing Swivel
Tubing Swivel
Main Bore Seal Stem
GT Dual String Packer with Parallel Head
Completion PBR
Upper completion
5.969" OD Shrouded Inforce HMC-Plus. 3-1/2" x 2.812" AOF x2.750 AOF
3-1/2"9.2lb/ft Vam Top
DUAL Gauge Mandrel;
Sure Sens 125 dual gauge (Annulus and Tubing) installed
7.125" OD. Inforce HMC-A. 4-1/2" x 3.688"AOF Profile
Choke settings 100% , 4.5%, 2.6% , 1.6% , 1.0%, 0.7% , 0.5% , 0%
TME-6.5 Tubing Retrievable Subsurface safety
Valve
4.500" x 3.81"BA ; Min ID: 3.81"
80 x 40 Locator with Muleshoe
3-1/2" x 4-1/2" Crossover
8.235" OD. IWS Splice Sub .
For 4 C.L. splices and one Tec Splice
3.750" AOF Nipple Profile also used as locating nipple
14 KNOC Global E&P Technical Symposium 2011
Van Ghent Tri-Lateral Total Configuration
3rd gas lateral was selected as a secondary recovery method and to
provide gas cap blow down without subsea intervention.
Configuration
• Subsea Xmas-Tree
• Dual Permanent Downhole Gauge
• Hydraulic operated Downhole Gas Choke
• Hydraulic operated Open/Close Sleeve
• Level 5 and Level 3 junction
• Screens mounted with Inflow Control Devices
• Long horizontals separated by 23 constrictors and 2 swell packers
HCM-A valve Downhole Gas Choke
HCM-A (Gas Choke) to control entrance of free gas into
tubing (Natural or Auto Gas Lift)
Cycle From To Exp return volume (ml)
Position 1 Fully Closed 2 Fully Open 512
Position 2 Fully Open 3 Diffused 220
Position 3 Diffused 4 4.5% Open 79
Position 4 4.5% Open 5 Diffused 70
Position 5 Diffused 6 2.6% Open 65
Position 6 2.6% Open 7 Diffused 65
Position 7 Diffused 8 1.6% Open 63
Position 8 1.6% Open 9 Diffused 63
Position 9 Diffused 10 1% Open 61
Position 10 1% Open 11 Diffused 61
Position 11 Diffused 12 0.7% Open 61
Position 12 0.7% Open 13 Diffused 57
Position 13 Diffused 14 0.5% Open 57
Position 14 0.5% Open 1 Fully Closed 302
How?
HCM-A™ Jay Manipulation
“Diffused”
Position
0.5 % Open
“Diffused”
Position
0.7 % Open
1 % Open
1.6 % Open
2.6 % Open
4.5 % Open
100% Open
“Diffused”
Position
“Diffused”
Position
“Diffused”
Position
“Diffused”
Position
Fully Closed
How?
Statistics
Added features to the “NLB” , special texas deck, diving spread, TLQs
Drilled and completed 8000m of hole total in 126 days
Drilled 2 oil legs 1600 & 2000m long absolutely horizontally (+/-10 cm) using high tech
rotary steerable drilling system, little friction since the well was so straight.
Maximum measured depth of 4,400m at vertically 1758m
Assembled 36 completion sub-assemblies + back ups
Installed the completion in 8 phases
Loaded and offloaded 53 boats (estimated >1000 trucks) – a normal well is 15 boats
No incidents, accidents or LTIs
Stakeholders – interface management
Well construction stakeholders Dana, Noble, Peterson, CHC, Baker (3 divisions),
Dril-Quip, Cameron, Schlumberger (4 divisions),
Halliburton (3 divisions), Weatherford (3
divisions), 3 x bit suppliers, SCS, CMF, Rederij
Groen, Noordhoek, Aquaterra, Atlas Tristar,
Geolog, SDC, Hunting, Piriplus, OMC, OMD,
VMOG, Tuboscope, Coil Services, IDS, KPN,
Meteo, NRG,
And hundreds of sub-contractors
Partners
SodM, Kustwacht, EZ, TNO
Conclusions
Complex Technical Challenges can only be met by:-
Teamwork
•Very close co-operation and mutual understanding
between the subsurface team, and the well construction /
completion, and project teams
•Contractors have to contribute positively.
•The Project Team must listen
Safety Performance achieved by:-
•Having Management Systems in place
•Commitment to follow them