DEVEX 2012 9th European Production and Development Conference

Van Ghent Tri-lateral oil and gas development

An integrated challenge

Completion concept & execution

Dave McKellar

Final concept after reservoir work

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?

Final Well Plan

Final Plan Detail

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

Main bore

Casing 9-5/8" 53.5#

S1

Knock Out Isolation Valve

Screen AssemblyLiner Hanger Assembly

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 Oil shut off valve

SHROUDED

SLIDING

SLEEVE

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?

Days - Depth

Completion spaghetti

Subsea tree – Arriving “Noble Lynda Bossler”

Testing the subsea tree

Running the Subsea Tree

WHPS

Total view

Deck

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

End

Questions?