Valhall Field. Valhall PL006B On Stream in 1982 OOIP: 2,7 bnstb oil Reserves: 1060 MMstb oil Cum prod: 420 MMstb oil Current Prod: 85 mbbls oil

Valhall Field QP DP NORWAY STAVANGER VALHALL DENMARK HOD UNITED KINGDOM 0 Valhall – PL006B On Stream in 1982 OOIP: 2,7 bnstb oil Reserves: 1060 M...
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Valhall Field QP DP

NORWAY STAVANGER

VALHALL

DENMARK HOD

UNITED KINGDOM 0

Valhall – PL006B On Stream in 1982 OOIP: 2,7 bnstb oil Reserves: 1060 MMstb oil Cum prod: 420 MMstb oil Current Prod: 85 mbbls oil

WP

GERMANY

100 km

Projects: Infill Drilling – WP and DP 2003: Water Injection Project 2002/03: Valhall Flank Development

PCP

Valhall Depletion Strategy •

Short term (2000 - 2003): – Valhall field primary depletion, Tor and Lower Hod formation - drill up WP slots and ‘repair’ DP slots.



Medium term (2003 - 2006): – – – –



Secondary recovery: Phase 1 Waterflood Valhall Tor formation Develop Valhall flanks - primary depletion Appraise Flank upside and Area prospects Continued infill drilling / ’repair’ wells

Long term (2006 ->): – – – –

Optimize Valhall Waterflood Opportunities for Valhall EOR Continued infill drilling / ’repair’ wells Re-development ?

Current Valhall Wells

• Wellhead and drilling platforms - 49 wells – – – – – –

Monobore horizontal completions Designed for multiple proppant fracturing Designed for SIMOPS completion Coil tubing access for completion and well clean out Completed with heavy wall liner for collapse resistance Completion designed for primary depletion

Current Valhall Wells Tubing Hanger

5 1/2" TRSCSSV

Producer Well Completion Current Design

5 1/2" ASV

13 3/8" 72# csg

5 1/2" 20# Tubing

Control Line Color Code Hydraulic Line DHPG Line

x-over 5 1/2" x 4 1/2"

4 1/2" Gas Lift Mandrel 4 1/2" 12.6# Tubing

4 1/2" DHPG

9 5/8" 53.5# csg

7" x 4 1/2" Packer

3.750" Landing Nipple

4 1/2" Mule Shoe

6 5/8" 66# Liner

Challenges Ahead - Waterflood

• Possible flow anisotropy and direction − Risk of premature water breakthrough along faults/fractures • Water injectivity − Effect of pressure/temperature induced fracturing • Effect of Water weakening of the Chalk • Scaling • Water management • Chalk influxes

Developed Completion Schematic 21 1/4" Tubing Hanger 8 Feed Through

5 1/2" TRSCSSV

Producer Well Completion Perf Valve System

5 1/2" ASV 13 3/8" 72# csg

5 1/2" 20# Tubing Control Line Color Code Hydraulic Line DHPG Line Fibre Optic Line

x-over 5 1/2" x 4 1/2" 4 1/2" Gas Lift Mandrel 4 1/2" 12.6# Tubing

4 1/2" DHPG

9 5/8" 53.5# csg

9 5/8" Packer 2 x 1/4" Feed Through 4 1/2" Gas Lift Mandrel Landing Nipple No Seal Expansion Joint

9 5/8" 53.5# csg

DTS Line 2 x 1/4" CL Hydraulic Wet Connector

10K Liner Hanger

6 5/8" Perf-Valve

6 5/8" Perf-Valve

6 5/8" Perf-Valve

6 5/8" 66# Liner 6 5/8" Perf-Valve

6 5/8" Perf-Valve

Development Challenges

Packer performance Barrier issues

Cementing Resources

Liner rotation

Deployment

Collapse resistance

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et s

Control line integrity

Groove in liner

Time Alignment

Protectors Centalizers

Pipe connections

Functional Requirement

Liner Installation

UpperCompletion Installation

Proppant Stimulation Contingent Perforating

Well Intervention

Re-Stimulation

Workover

Functional Requirement

Production

Fiber Optic Installation

Acid Stimulation

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Environment

Modes

System Requirement

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Joint Development Project

Prestudy/work 15/5 '02

Agreement PV Redesign Packer Design Expansion Joint Connection & flatpack design

10-14/3 ’03

Stack-up Test

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DTS Completion Schematic Upper Completion Components: – Wet Connect – Expansion Joint – Retrievable Production Packer

9 5/8" 53.5# csg

Feed Through Packer

U

pp e

r

Co m

pl

et io n

Lower Completion Components: – Perf Valve – Liner Hanger System – Timed Connection-slotted pipe – Casing Receptacle

Hydraulic Wet Connector

Lower Completion Parts

Pa rt s

6 5/8" 66# Liner

Perf Valve

DTS Lines

Perf Valves

Turnaround sub

Lower Completion: Perf Valve Feature

Benefit:

Multiple Piston:

No perforation Proppant Frac Resistant Adjustable flow area Contaminate cement

Sliding Sleeve:

Selective production/injection Maintain Well Integrity

Liner Mounted:

Cemented in place

Lower Completion: Timed Connections

Standard NSCC connection

Lower Completion: Turnaround Sub

Lower Completion: Casing Receptacle • Liner mounted part of Wet Connect • Provides the reconnect point for the 1/4” control lines • Contains the male half of the hydraulic connector. • Allows the control line to pass from inside the liner to outside.

Upper Completion: Wet Connect

Indicating Collet

Feed Thru’ Lock

Reconnect Lock Assembly

Cylinder Spring

• Run at the bottom of the completion • Locates, aligns and locks into the Casing Receptacle. • Connects the control lines from the completion to the liner

Alignment Profile

Upper Completion: Expansion Joint

Expansion Joint • Run between packer and wet connect • Rotational locked • 2 meter stroke • 2 ea ¼” control line by-pass

Upper Completion: Feed Through Packer

• Retrievable Packer, 7.5k Rated • Up to 7 feed troughs (1/4” lines)

Ullrigg Stack-Up Test Achievements • Convey “Perf Valve Liner” w/ timed connection and dual control line. Set hanger, simulated cement job and actuated perf valve pistons • Run upper completion w/dual control line. Oriented and connected the wet connect. Function tested the Expansion Joint and set the packer. • Deployed Optical Fiber to the toe of well and back to surface. Logged temperature as function of depth • Opened Perf Valve sliding sleeve, ruptured disc’s and simulated fracturing job • Released the Packer and retrieved upper completion, pulled lower completion

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System Benefits Perf Valve: • Initial Installation: − Allows DTS deployment •Stimulation − Increased Proppant size − Eliminate Perforating − Selective stimulation •Zonal Isolation −Reduce Chalk influxes −Water shut-off −Remedial work −Selective production

DTS: •Flow into liner − Production − Water breakthrough − Gas lift monitoring • Flow out of liner − Injection − Stimulation − Scale squeezes

Implementation

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• Staged approach – Control new elements and associated risks – Prove Perf Valve functionality first

PV redesign Packer design Exp Joint Connection & flatpack design 10-14/3 ’03

Stack-up Test

PV Implementation DTS Implementation 04

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