c 84514 bk kk0 pro gn 00 0014; subsea pre commissioning procedure_rev.0b

Originator: : PT.TIMAS SUPLINDO COPI Group Owner: : Project Area: : Belanak Location: : Belanak General System: : General System Document Type: : Procedure Discipline / Subdiscipline: : Pipeline / Riser / Subsea Old COPI Document No.: : ‐

Document Title : Eastern Hub Mercury Removal ( EHMR ) – Water Project

Subsea Pre-commissioning Procedure COPI Doc No. : C‐84514‐BK‐KK0‐PRO‐GN‐00‐0014

0B IFA 10-06-

13 Issued For Approval SS AW MBN

0A IFC 14-05-

13 Issued For Comment SS AW MBN

Rev Status Issue Date

Reason for Issue Prepared Checked Approved

Project Engineer

Project Manager

Contractor Approvals COPI Approvals

Procedure Subsea Pre‐commissioning Procedure C‐84514‐BK‐KK0‐PRO‐GN‐00‐0014 Rev.0B ConocoPhillips Indonesia Inc.Ltd of 25

Printed initials in the approval boxes confirm that the document has been signed. The originals are held within Document Management.

Additional Approvers (If Applicable)

Name Designation Signature Date

Revision Sheet

REVISION DATE DESCRIPTION OF CHANGE

0A 14‐May‐13 Issued For Comment

0B 10‐June‐13 Issued For Approval

ConocoPhillips Indonesia Inc. Ltd


TABLES OF CONTENTS

DESCRIPTION PAGE

1.0 INTRODUCTION ............................................................................................................ 4

2.0 PIPELINE DETAILS ......................................................................................................... 7

3.0 PROJECT ORGANIZATION ............................................................................................. 8

4.0 SAFETY, HEALTH AND ENVIRONMENT .......................................................................... 9

5.0 OVERVIEW OF PROJECT PRELIMINARIES ..................................................................... 12

6.0 PERFORMANCE OF OPERATIONS ................................................................................ 14

7.0 INSPECTION AND TEST PLAN ...................................................................................... 16

Appendix A – Drawings .................................................................................................................. 21

Appendix B – Calculation ................................................................................................................ 22

Appendix C – Chemical Datasheet .................................................................................................. 23

Appendix D – Bi‐di Pig Drawings and Foam Pig Catalog................................................................... 24

Appendix E – NOV Factory Acceptance Test (FAT) Report ............................................................... 25

Appendix F – Reporting Format ...................................................................................................... 26


1.0 INTRODUCTION

1.1 General

The project concept is to install produced water reinjection facilities on the Belanak FPSO and Wellhead Platform A (WHP‐A) to inject produced water into four depleted Gabus Massive wells in the Belanak Field., located in the Natuna Sea Eastern Hub Block B PSC. The facilities are required to ensure compliance with the Belanak Operating Permit which stipulates a maximum mercury content of 10 µg/l in overboared produced water.

PT. Timas Suplindo has been awarded the contract to execute the Eastern Hub Mercury Removal (EHMR) Water Project under contract CS15869798 as EPCI contract for Subsea & Topsides Facilities

1.2 Purpose of this Document

The purpose of this document is to provide sufficient data for implementing pre‐commissioning work in line with international industry standards and to deliver a “fit for purpose” system and facilities. This document outlines the methodology for flooding, gauging, leak testing of subsea system. This procedure has been prepared as a working document to ensure that the operations shall be carried out in accordance with the specified project requirements.

1.3 References

The following documents have been referenced for the development of this procedure:

Rev Document Reference No. Document Title

2007 DNV‐OS‐F101 Submarine Pipeline Systems

2002 API 17 B Recommended Practice for Flexible Pipe

2002 API 17 J Specification for Unbinded Flexible Pipe

1 CPMS‐PPL‐EP‐004 Offshore Pipeline Hydrostatic Testing, Drying and Pre‐Commissioning

1 CPMS‐PPL‐EP‐022 Offshore Pipeline Pigging


1.4 Definitions and Abbreviations

Throughout this procedure, the following definitions will be used:

Definitions

Project EHMR Project

Company CONOCOPHILLIPS INDONESIA, Ltd

Contractor PT. Timas Suplindo

Subcontractor Offshore Construction Specialist

Vendor Any vendor supplying materials or equipment

Abbreviations

CFIM Company Free Issued Material

COG Center of Gravity

CSR Company Site Representative

DGPS Differential Global Positioning System

DNV Det norske Veritas

DP Dynamic Positioning

DSV Diving Support Vessel

FE Field Engineer

HP High Pressure

Hs Significant Wave Height

MBR Minimum Bending Radius

MMscfd Million standard cubic feet of gas per day

MWS Marine Warranty Surveyor

NDT Non Destructive Testing

P&ID Piping and Instrument Diagram

PSI Pounds per Square Inch

ROV Remotely Operated Vehicle

RTJ Ring Type Joint

SAT Diving Saturation Diving

HSE Health, Safety and Environment

SMYS Specified Minimum Yield Strength

SWL Safe Working Load

TBC To be Confirmed

TMS Tether Management System


TRA Task Risk Assessment

USBL Ultra Short Base Line

UT Ultrasonic Test

1.5 Flooding, Cleaning, Gauging and Leak testing Scope of Works

The actual scope of work for the Flexible pipelines are summarized below: Flooding equipments set‐up on DSV Ullswater

Fill treated fresh water and run foam pig upon completion of surface tie‐in 3000m flexible flowline with 1000m flexible flowline. Refer to "Flooding procedure" which shall be provided by Antares.

Flooding equipments set‐up on DSV Ullswater

Fill treated fresh water on Dynamic riser upon completion of dynamic riser pull‐in. Refer to document number C‐84514‐BK‐KK0‐PRO‐GN‐00‐0010;Dynamic riser Installation Procedure.

Gauging of subsea system (Rigid riser, Flexible flowlines, PLEM pipe spool and Dynamic Riser) from FPSO Dynamic Riser top of flange to WHP‐A Rigid Riser top of flange.

Leak testing of subsea system from FPSO Dynamic Riser top flange to WHP‐A Rigid Riser top flange by attached test blinds to each ends.

1.6 Acceptance Criteria

1.6.1 Pipeline Gauging

As per specification, pipeline shall be “No damage to one (1) of the gauge plates within the gauging run. In case of damage to both gauge plates, the gauging pigs shall be re‐run with new gauging plates of the same size”.

1.6.2 Pressure Testing

Leak test pressure hold of 6 hours. A pressure variation should there be any can be attributed to temperature fluctuation and shall be documented.

1.7 Procedural Changes

Site conditions may warrant changes to offshore installation procedures and planning for the work to be undertaken in a safe and expedient manner. In such an event, a Offshore Installation Manager, Captain, and Field engineer shall consult with COPI CSR, the marine surveyor and with its onshore management. Following agreement between all parties, any part of this procedure may be revised to suit the prevailing installation conditions. The site memo and/or technical query will be generated and documented.


2.0 PIPELINE DETAILS

2.1.1 Dynamic Riser and Flexible flowlines

Description

Parameter Units 3642NKT001 3642NKT002 3642NKT003

Dynamic Riser Flexible Flowline Flexible Flowline

Pipe OD mm 218.1 214.1 206.1

Pipe ID mm 139.7 139.7 139.7

Length Approx m 358 1000 3014

Volume Approx m3 5.49 15.33 46.22

Design Pressure psi 3600 3600 3600

Test Pressure (1.1 DP) psi 3960 3960 3960

2.1.2 Rigid Riser

Parameter Units Rigid Riser

Pipe OD mm 168.3

Pipe ID mm 139.76

Length Approx m 95

Volume Approx m3 1.46

2.1.3 PLEM Pipe spool

Parameter Units PLEM Pipe Spool

Pipe OD mm 168.3

Pipe ID mm 139.76

Length Approx m 12.8

Volume Approx m3 0.20


3.0 PROJECT ORGANIZATION

Day Shift Night Shift Field Engineer One Field Engineer would be in overall charge of the operation. His duties include:

Overall co‐ordination Providing continuity between shifts Ensuring adherence to all procedures/permits Collating and presenting all handover documentation Responsible for all matters concerning safety, quality and technical and operational

activities

Supervisor Reporting to the Field Engineer will be supervisor who will look after the night shift. His duties would include:

Liaising with Client Shift Supervisor Adherence to permits that may be in place Preparing all logs and reports of work carried out Implementation of all safety and quality measures Ensuring compliance with working procedure

Mechanic / Technician Reporting to the project engineer and the shift supervisor will be Mechanic/Technician working 12‐hour shifts. Their main function is to carry out the service in a safe and expedient manner. Such duties would include:

Operating all equipment safely Liaising with mechanical and pipe fitters Carrying out preparation work on systems to be tested

Timas Site Rep

OCS Pre‐Com Engineer

OCS Management Team

Mechanic Supervisor

Technician


4.0 SAFETY, HEALTH AND ENVIRONMENT

4.1 General

Subcontractor's target for the project is zero injuries and incidents. All personnel will be trained in Subcontractor's HSE systems. Briefings and inspections will be conducted before, during and after the operations. Onsite a bunding will be installed around any containers/tanks, containing hazardous liquids, fuel storage areas and machines. Any waste will be disposed off in accordance with appropriate procedures. Subcontractor is committed to providing a safe environment for its employee’s, clients and third parties to work in and this will not be compromised by any other factor. Subcontractor consider safety to be an inherent value associated with everything it does and Subcontractor will not jeopardize own or our colleagues well‐being for any reason. Subcontractor believe that all accidents and injuries are preventable and regard the promotion of health and safety as an obligation and mutual objective for all employees at all levels, whether working offshore, customer land locations or our premises. Our target is that no employee gets injured. All personnel involved in pre‐commissioning shall be pre‐briefed on the operating procedures and the potential hazards in a pre‐mobilization Job Safety Analysis (JSA). The JSA shall be reviewed prior to commencing any operation activities during pre‐commencement tool box talk. A walk through shall be conducted to inspect the arrangement of the equipment on site prior to commencing of operations. Subcontractor personnel shall adhere and conduct all activities in accordance with site and client operating procedures (including the permit to work system). Applicable permit for using of site fire water shall be applied prior to use. Contractor site representative shall liaise with Company Site Representative when applying for such permits. The contractor field engineer shall be responsible for ensuring all permit requirements are fully complied with. The immediate vicinity around the work area shall be cordoned off with signage stating “Pre‐Commissioning On‐Going, All Unauthorized Personnel Please Keep Off”.


4.2 Tool Box Talk

A Tool Box Safety Talk shall be conducted on‐site before each new phase of operations. The talk shall outline the work to be carried out and shall include but not limited to the following:

Sequence, co‐ordination and details of work to carried out

Hazards/control measures/emergency response contingency plans

Safe areas/escape routes/muster points

Barriers and signs

4.3 Personnel Safety

All personnel shall wear personal protective equipment (PPE) provided for their use. Protective safety hard hat, steel toe safety boots and flame retardant coveralls shall be the minimum safety clothing worn at all times when on‐site. All personnel shall carry safety glasses, ear protection and gloves with them at all times and use them in the appropriate situations. Waterproof jacket and trousers shall be worn in adverse weather conditions. Contractor personnel shall wear ear defenders at all times when running diesel powered equipment with a sound power level in excess of 85 dB(A). Portable eye wash available on‐site shall be properly identified prior any commencement of any phase of the works scope.

4.4 System Safety

Pre‐commissioning involves the application of pressure and volume displacement to confined structures such as pipelines and there is a risk of failure and subsequent release of pressure energy. The following safety rules shall be adhered to at all times:

Never open a pig trap or flange unless you have checked by carefully opening vent valves to ensure there is no pressure in the system.

Make sure no one or any equipment is in line with the route of the pig passage and ensure the launcher/receiver is well secured.

Be aware of the pressure in the hose, valve, gauges and fittings.

Never attempt any remedial work on any equipment and system under pressure.

Never apply pressure to an untested hose, test them before connecting to the pipeline or system.

Always secure hoses to prevent whipping in the event of failure.

Always checked that no low pressure fitting or instruments have been used in the rig up or system.

Always check that all connection is fully secure.


4.5 Equipment Safety

All equipment shall be located when onsite in a manner which leaves suitable and safe escape routes. Equipment shall be positioned so as to leave 0.6m access in between, in order to minimize:

• Prevent trip hazards • Prevent damage to hoses • Protect all personnel and site equipment in the event of hose failure (i.e. away from

access routes) etc.

4.6 Environmental Control

All equipment with the potential for spill causing environmental damage will have drip pans or tarpaulin sheets installed to contain any spillage. Drip tray or tarpaulin sheets shall be utilised for retrieval of pig. Contractor has written approval from the relevant Indonesia government agencies having authority and jurisdiction for environmental matters for the use of the test chemical and its disposal. (Clariant brand)

4.7 Actions in the event of Emergency

In the event of an emergency during operations, all equipment shall be shut down immediately. The power and air supply to the test equipment container shall be properly isolated. If a system is under pressure at the time of an emergency, the injection point must be closed as soon as pumping has stopped. Non return valves (NRV) shall be fitted to injection points of systems to ensure that pressure is contained in the event of hose failure. Work permits (if any) are to be returned to the permit office/control room. Personnel shall proceed to their allocated emergency muster point in accordance with the vessel on‐going response procedure.


5.0 OVERVIEW OF PROJECT PRELIMINARIES

5.1 Water Supply

Flooding and gauging work scope shall make use of available fresh water from DSV Ullswater approximate 83 m3 (including 20% contingency of total subsea pipeline volume). DSV Ullswater shall be positioned on DP on port side of FPSO. The water hose shall be laid across FPSO from DSV Ullswater to Pre‐com spread location.

5.2 Instrumentation

Instruments supplied will be calibrated to traceable reference standards no more than 6 months prior to mobilization and shall conform to the following levels of accuracy:

● Hydrostatic pressure gauges ............................................................................ +0.01%, 0.25% ● Pressure Transducers ...................................................... +0.2%, sensitivity better than 0.1% ● Pressure Chart Recorders ........................................................................... 24 hour type, +1% ● Flow Meters ........................................................................ +1%, sensitivity better than 0.1% ● Temperature Probes, Recorders, Read‐out devices .......... +10C, sensitivity better than 0.10C ● All other measuring equipment ....................................................................................... +1 % Any pressure retaining equipment shall be tested to at least 10% over maximum possible working pressure during function test at OCS base.

5.3 Chemicals

Multi Treat 5549R being a cocktail of biocide and corrosion inhibitor will be injected to the pipeline at a dosage of 500 ppm and SeaDye of Clariant brand will also be injected at 50 ppm. The chemical dosage is sufficient to protect the pipeline for 3‐6 months. Chemical MSDS and TDS are provided in appendix C section.

5.4 Pigs

Bi‐di Pig to be used will be in‐pipe brand, having four sealing discs and two guiding discs. The number of pigs to be used for base case (gauging) will be as follows: DSV Ullswater

2 no. Foam pig on 3000m+1000m flexible flowline on 3000m flexible line at WHP‐A end and 1000m flexible line at PLEM end.

FPSO

1 no. Foam pig on Dynamic riser at PLEM end

1 no. Bi‐ directional gauging pig (subsea system)


Prior to back loading of any pigs into the pig launcher, dimensions of gauging plate will be checked and a photographic record of pig loading taken.

5.5 Gauge Plates

Recommended Gauging plate size is 129.8mm dia x 10mm thick. Refer to Appendix E; NOV Factory Acceptance Test (FAT) Report


6.0 PERFORMANCE OF OPERATIONS

6.1 Gauging

Upon the construction has been completed. The subsea system will be cleaned and gauged from a temporary launcher on FPSO to a temporary receiver on WHP‐A using treated fresh water. The launcher and receiver will be sufficiently sized to contain only 1 foam pig or 1 Bi‐di pig at a time. Spread of equipment will be set‐up on FPSO and hoses will be connected to pig launcher. Upon completion of all preparation works, the initial cleaning and gauging will commence in the below detailed sequence.

Subsea system: • Introduction of chemically treated fresh/portable water in flooding the flexible flow line.

Additional, 20% of pipeline line volume will be pumped to ensure full pipeline length has been flooded in preparation for Leak testing. Once the desired volume has been achieved, the operation has deemed to be completed.

The approaching of the pigs to the receiver will be indicated by variations on the chart of the pressure recorder. However, in case no clear signs are noted, an extra volume of approx. 20% of pipeline volume will be pumped. Upon the last pig being received, the pump spread will be stopped and the system will again be depressurized to ambient conditions. All injection and discharge valves will be set in closed position.

Once gauging and flooding have been performed to the subsea system (Dynamic Riser, Pipe spool, Flexible flowline and Rigid riser), the pig receiver and launcher shall be removed. The pig received/retrieved will be inspected together with the Contractor and Company. The gauging plate re‐measured and data will be recorded as well as photograph will be taken. The gauging of pipeline shall then be signed off on the plate and on the gauging log by all parties. During cleaning, gauging and flooding the following parameters will be recorded and logged at regular interval. • Pipeline pressure behind pig train .............................................................................. bar / psi • Volume of water injected ahead, between & behind pigs ............................................ m3/gal • Volume and dosage of chemicals (once applicable) .................................................. Ltr/ppm • Pig speed ............................................................................................................................ m/s

6.2 Leak testing

Subsea system: Once subsea termination have been completed, the hydrostatic testing will be performed as per requirements using chemically treated fresh/portable water from FPSO Dynamic riser test flange to WHP‐A Rigid riser test flange at each end. Before commencement of operations, if and where applicable, all temporary pumping pipework will be walked through and inspected together with Contractor and Company representatives.


• Top up and vent all pipework. • Hold for 15 minutes for stabilization and leak check. • Continue pressurization to 100% of test pressure at a rate of about 0.1 barg./min (1.45

psi/min). • Once 100 % of test pressure has been achieved. Approximate 50 psi will be added to the

test pressure to allow for stabilization. • Hold for approx. 6 hours for stabilization and leak check. Upon attaining the specified test pressure, the pumping equipment will be isolated from the pipeline by removal and plugging. During the pressurization phases above, the dedicated test engineer will maintain a graph of pressure verse volume and any criteria not conforming to standard expectancies, which indicate leaks or other problem areas will be immediately brought to the Contractor's attention. Upon completion of an adequate post pressurization stabilization period for test medium, the test pressure hold period will be started. The pipeline test pressure will be held for a period of at least six (6) consecutive hours. During the pressurization and hold period phases, if and where applicable, the following parameters will be recorded and logged: Note: For Flexible flow line, air inclusion shall be accepted at 0.5% of the pipeline volume & 6

hours hold shall be deemed acceptable. As an alternative pressurization of flexible flowline shall may also be performed at 5 bar/min interval.

• Pressurization rate .....................................................................................................barg/min • Flow injection rate ................................................................................... Liter /barg (Liter/psi) • Volume of water injected .................................................................................................. Liter • Volume of chemicals added .............................................................................................. Liter • Injection water temperature ................................................................................................. °C • Seabed temperature ............................................................................................................ °C • Ambient temperature ........................................................................................................... °C • Pipeline pressure ...................................................................................................... barg / psi • Pressure versus volume plot ................................................................................................... ‐ • Pressure / temperature versus time graph ............................................................................. ‐ The specified hold period will only be terminated when written acceptance has been obtained from the Contractor and the specification criteria have been successfully attained. Upon receipt of written acceptance of the controlled test, the pressure will be released from the system in a controlled and safe manner.


7.0 INSPECTION AND TEST PLAN

7.1 Gauging

ID ID Activity Responsible Verified Approve

1 Carryout a pre‐job safety meeting with all personnel in attendance.

OCS Timas COPI

2 Carry out site operations safety checklist, request Permit to Work and rig up equipment as per operational layout.

OCS Timas COPI

3

Ensure that all hoses are tied down at regular intervals to prevent whipping in the event of failure. Also ensure hoses are clearly visible and clear of walkways. Erect safety barriers.

OCS Timas COPI

4 On WHP‐A, the temporary 6" #1500 Ball valve shall be installed between Rigid riser and Pig receiver

Timas Timas COPI

5 Inspect Receiving Head OCS Timas COPI

6 Inspect Launching End OCS Timas COPI

7 Connect flooding hose to the temporary launcher head

OCS Timas COPI

8

Once finished connection to the temporary pig launcher has been prepared, start the flooding pump and fill the hose with treated fresh water to confirm injection & flow of water.

OCS Timas COPI

9

Connect the flooding hose into the WECO connection on the temporary launcher head. Technician should at this point standby in preparation to operate the valves.

OCS Timas COPI

10 Start flooding spread, ensure all instruments are online and working.

OCS Timas COPI

11 Launch Bi‐di Pig with gauging plate OCS / Timas ‐ COPI

12

Inject water behind the Bi‐di Pig. This water is required chemical treatment Pipeline Length Volume Pig Purpose6" 4500 m ~ 69 m3 Gauging This stage chemically treated water will be introduced until the pig has been confirmed to be received on the receiving end. Flooding spread pumps will be run to maintain the flowrate to run the pig at speed of about 0.5 m/s. Simultaneously the chemical injection pumps will be run to maintain 500 ppm (Multi Treat) & 50 ppm (Sea Tracer Dye)

OCS Timas COPI

13 During gauging, the parameters in the Recording Section as below will be recorded and logged at 30 minute intervals.

OCS Timas COPI

14

The receipt of the pig train at the receiving end of the Rigid riser will be indicated by a increase in the flowrate and pressure. If there is no clear indication of the pig being received then flooding should

OCS Timas COPI


ID ID Activity Responsible Verified Approve

continue until 120% (83 m3) of the theoretical flexible flowline volume has been pumped behind the last pig in the train. If there is very positive indication then flooding can conclude.

15

Prior to retrieve pig(s) from Pig receiver, the temporary 6" #1500 Ball valve shall be 100% closed and re‐open (100%) again upon completion of pig retrieval.

Timas OCS COPI

16 Acceptance & completion report shall be signed off. To include valve status check sheet.

Timas OCS COPI

17 Once Pigs have been retrieved, gauge plates will be inspected and photographed.

OCS Timas COPI

18 Gauge plate certificate will then be signed off Timas OCS COPI

Note: Temporary 6" #1500 Ball valve shall be removed prior to install test blind on rigid riser at WHP‐A

7.2 Leak testing

Description

Design Pressure (DP) 3,600 psi

Pipeline System Leak test (PLT = 1.1 DP) 3,960 psi

75% Test Pressure 2,970 psi

95 % Test Pressure 1,980 psi

Holding Period 6 hours

ID ID Activity Responsible Verified Approved

1 Carryout a pre‐job safety meeting with all personnel in attendance.

OCS Timas COPI

2 Carry out site operations safety checklist, request Permit to Work and rig up equipment as per operational layout.

OCS Timas COPI

3

Ensure that all hoses are tied down at regular intervals to prevent whipping in the event of failure. Also ensure hoses are clearly visible and clear of walkways. Erect safety barriers.

OCS Timas COPI

4 Install "Leak Test" Test Blinds for both ends OCS Timas COPI

6 WHP‐A End: Technician to survey the blind flange. OCS Timas COPI

7 FPSO (Pressurization) End: Technician to survey the blind flange

OCS Timas COPI

8 Connect the Leak Test hose & instrumentation hose to test flange.

OCS Timas COPI

9

Once finished connection to the test flange has been prepared, start the Leak Test pump and fill the hose with treated fresh/portable water to confirm injection & flow of water. Bleed residual air. Once injection &

OCS Timas COPI



Leak Test spread has been proven to be leak free, stop pumping. As necessary perform pressurization of test spread.

10

Connect the pressurization hose into the 1" ball valve (BFV 01) connection on the blind flange. Technician should at this point standby in preparation to operate the valves.

OCS Timas COPI

11 Start Leak Test spread, ensure all instruments are online and working.

OCS Timas COPI

12

Techinician open BFV 01, BFV 02 to bleed residual air (tentative for 2 mins), on Blind flange. Once bleeding of residual air has been completed, close BFV 02.

OCS / Timas Timas COPI

13

Engage the pressurising pump and commence pressurising the system to 35 barg (507.5 psi) at a rate not to exceed 5 barg per min. Record readings of time, pipeline/flowline pressure, and volume injected at 1 Barg intervals.

OCS Timas COPI

14

At 35 barg pressure (507.5 psi), calculate the volume of air entrapped in the pipeline. If the volume of air is > 0.5% of the pipeline volume, then depressurize the pipeline to ambient and depressurize. If the volume of air is < 0.5% of the pipeline volume. Pressurization can resume.

OCS Timas COPI

15 Continue pressurization to 75 % of test pressure at a rate not exceeding 1.0 barg./min (14.5 psi/min).

OCS Timas COPI

16 Hold for 15 minutes for stabilization and leak check. OCS Timas COPI

17

Continue pressurization to 100 % of test pressure at a rate not exceeding 0.25 barg/min (3.625 psi/min). Note: Approximately 50 psi will be pumped in to allow for stabilization.

OCS Timas COPI

19

Hold for approx. 4 hours for stabilization and leak check. Once pressure has been stabilized, isolate the pressurization line & commence 6 hours hold. Stabilization period may be subject for change due to length & condition of system on test.

OCS Timas COPI

20 Record Pressure & Temperature reading every 30 minutes.

OCS Timas COPI

21 As necessary should it be required to add or remove water due to pressure fluctuation it shall be noted by Contractor & Company.

OCS Timas COPI

22

Once the 6 hours hold period has been successful and acceptance of the test shall be signed off. Depressurize the pipeline at a rate of not exceeding 3 bar/min (43.5 psi/min).

OCS Timas COPI



24 Once the pressure has been put into ambient and declared safe, remove the hoses installed in the blind flanges.

OCS Timas COPI

25 Sign off acceptance certificates & valve status check sheet.

OCS Timas COPI

Procedure Subsea Pre‐commissioning Procedure C‐84514‐BK‐KK0‐PRO‐GN‐00‐0014 Rev.0B ConocoPhillips Indonesia Inc.Ltd of 25 APPENDICES


Appendix A – Drawings

1

1

2

2

3

3

4

4

5

5

6

6

7

7

8

8

9

9

10

10

11

11

12

12

A A

B B

C C

D D

E E

F F

G G

H H Built-in angle 11° Azimuth 315 °N MWL

BS Flange 5.5” WIR Bend stiffener length 2.951m

5.30m Fully loaded draught

Detail A

MWL 90.0m

Detail A

Midship PLEM

Detail B

Mudline

FPSO keel

21.90m

Bend stiffener flange

Fully loaded draught, 16.60m

56.90m


5.5” WIR Touchdown point

PLEM flange


15.02m 222.93m

5.5” Riser System Configuration Riser/view plan: azimuth 315 °N, perpendicular to the FPSO bow-aft direction

Detail B View plan: Azimuth 315.67 °N, perpendicular to the PLEM flange Residual tension: ~50kN at PLEM interface

Midship PLEM

EF length 1.226m

1.40m

15.02m

6 No. BR Elements assemblies, nominal length 2.420m


Flange interface

BR steel work length, to first element face 0.427m

Detail B, oblique view Detail A, oblique view

Nominal Configuration: Fully loaded draught – 16.60m Pipe content density, minimum operation – 956kg/m3

No marine growth Zero FPSO offset

Belanak FPSO

Note that hang-off details are given in 3642-DWG-HO-100 Rev.3.

This document contains confidential information. All rights are owned by National Oilwell Varco Denmark I/S. No use or disclosure is to be made without prior written permission of National Oilwell Varco Denmark I/S. .

Client Projection method

Project

EASTERN HUB MERCURY REMOVAL - WATER Standard tolerance

- Title

GA Drawing, Riser Configuration

Part No.

- Client Doc No.

Location: COPI Group Owner:

System No.: Document type:

Discipline/ SUB-Discipline: K-Pipelines/Risers – K0

Rev. Date Description By Chk Appr Proj

0A Issued for Comments ELI PDR MSN AGC

ID-F-BK-P-SCH003-B01-0003

12-Feb-2013

Area Code:

Size State

Released

Sheet

1/2

Drawing No.

3642-DWG-CONF-100

PDM Ver. Scale

FP-Belanak FPSO Projects B01 A4-Water Injection

BK – Belanak

- N/A -

0B Issued for Approval ELI PDR MSN AGC 09-Apr-2013

01 Issued for Construction ELI RLF MSN AGC 16-Apr-2013

1

1

2 3

3

4

4

5

5

6

6

7

7

8

8

9

9

10

10

11

11

12

12

A A

B B

C C

D D

E E

F F

G G

H H

2

315.67°N

315.00°N

Center of Belanak FPSO 636 318.27 E 460 587.99 N (WGS 84)

PLEM ref. point 636 093.24 E 460 840.39 N (WGS 84)

Top View of Riser System Configuration, nominal

56.90m +9/-5*



PLEM flange


15.02m

222.93m

Detail A

PLEM tie in flange 636 097.30 E 460 835.65 N (WGS 84)

Detail A

225.00°N

* The touchdown point – BS flange horizontal distance is given for three conditions: Nominal: As described on page 1(Nominal Configuration). 56.90m Compressed System: Minimum water level, fully loaded draught, max pipe length. 51.90m Stretched System: Maximum water level, ballasted draught. 65.90m

Riser Section DescriptionSectionLength[m]

Acc. Length From End A

[m]

1.226 1.226

0.700 1.926

2.951 4.877

349.004 353.881

2.847 356.728

1.226 357.954

Total [m] 357.954

A Topside End-Fitting

Spool Piece

Bend Stiffener

Bare Flexible Pipe

Bend Restrictor

B Subsea End-Fitting

This document contains confidential information. All rights are owned by National Oilwell Varco Denmark I/S. No use or disclosure is to be made without prior written permission of National Oilwell Varco Denmark I/S. .

Client Projection method

Project

EASTERN HUB MERCURY REMOVAL - WATER Standard tolerance

- Title

GA Drawing, Riser Configuration

Part No.

- Client Doc No.

Location: COPI Group Owner:

System No.: Document type:

Discipline/ SUB-Discipline: K-Pipelines/Risers – K0

Rev. Date Description By Chk Appr Proj

0A Issued for Comments ELI PDR MSN AGC

ID-F-BK-P-SCH003-B01-0003

12-Feb-2013

Area Code:

Size State

Released

Sheet

2/2

Drawing No.

3642-DWG-CONF-100

PDM Ver. Scale

FP-Belanak FPSO Projects B01 A4-Water Injection

BK – Belanak

- N/A -

0B Issued for Approval ELI PDR MSN AGC 09-Apr-2013

01 Issued for Construction ELI RLF MSN AGC 16-Apr-2013

F

1 2

D

E

3 4

C

A

1 2

B

3 4

5 6 7

F

8

D

E

5 6

C

7

A

8

B

Scale Size

Title

Project

Client

Drawing No.

Client Doc No.

This document contains confidential information. All rights are owned by National Oilwell Varco Denmark I/S.No use or disclosure is to be made without prior written permission of National Oilwell Varco Denmark I/S.

State

Part No.

Rev. Date By Chk Appr Proj

Standard Tolerance

Description

PDM Ver.

Projectionmethod

Sheet

Location: COPI Groupowner:

Discipline/SUB-Discipline:

System No.: Area Code:Documenttype:

9200

4400

5000

5898

9355

6000 6000

700

1096

R2500

1400

1600

Te NOV Reel

40.0

NOV Cradle 4.5

Empty pipe incl. all equipment 207.5

Packing Rigging 2.0

Total weight 254.0

3642-DWG-PCK-200D.2Released1/1A21:50

K-Pipelines/Risers - K0BK -

BelanakA4-Water InjectionB01ProjectsFP-Belanak

FPSO

ID-F-BK-P-SCH003-D06-0003

General Packing Arrangement

Flowline - WHPA

-EASTERN HUB MERCURY REMOVAL - WATER

0A 12-Feb-13 CHR JBM BJP AGC

1 19-Apr-13 Issued for Construction CHR JBM BJP AGC

SECTION B-B SECTION A-A

Notes: 1. Pipe Info: 5.5" WIF NKT Pipe Serial No.: 3642NKT003 Pipe OD: 206.1 mm Pipe length: 3014 m MBR: 1.59 m 2. The reel can be lifted using a standard spreader beam. 3. Pipe and end fittings secured to reel using lever hoists. For rigging details refer to: 3642-DWG-LPP-200/ID-F-BK-P-SCH003-D06-0005 4. 5 Te Hold Back Wire 50 m. 5. Hold Back Wire Bracket placed on spoke. 6. First end off reel 3642NKT003B 7. End fitting to be packed in rubber and foam to protect pipe and end fitting. 8. Expanded polystyrene support blocks. 9. Actual winding of pipe may be slightly different. 10. Weight info:

FRONT ISO VIEW BACK ISO VIEW

FR

ON

T

Note 9

Note 7

Note 8

Note 6

Note 7

Note 5

Note 4

F

1 2

D

E

3 4

C

A

1 2

B

3 4

5 6 7

F

8

D

E

5 6

C

7

A

8

B

Scale Size

Title

Project

Client

Drawing No.

Client Doc No.

This document contains confidential information. All rights are owned by National Oilwell Varco Denmark I/S.No use or disclosure is to be made without prior written permission of National Oilwell Varco Denmark I/S.

State

Part No.

Rev. Date By Chk Appr Proj

Standard Tolerance

Description

PDM Ver.

Projectionmethod

Sheet

Location: COPI Groupowner:

Discipline/SUB-Discipline:

System No.: Area Code:Documenttype:

5600

5000

6000 6000

700

5898

9355

9200

16003200

700

1000

4573

79

992

700

R31

00

Te NOV Reel

40.0

NOV Cradle 4.5

NOV Dividerring 4.5

Empty pipe 3642NKT001 incl. all equipment 35.2

Empty pipe 3642NKT002 incl. all equipment 89.1

Packing Rigging 4.0

Total weight 177.3

Pipename

NOV pipeSerial No.

Pipe ODPipe

LengthMBR

5.5 WIR 3642NKT001 218.1 mm 358 m1.59 m

5.5 WIF 3642NKT002 214.1 mm 1000 m

3642-DWG-PCK-100E.2Released1/1A21:50

K-Pipelines/Risers - K0BK -

BelanakA4-Water InjectionB01ProjectsFP-Belanak

FPSO

ID-F-BK-P-SCH003-D06-0002

General Packing Arrangement

Riser / Flowline - PLEM

-EASTERN HUB MERCURY REMOVAL - WATER

0A 12-Feb-13 Issued for Comment CHR BDJ BJP AGC

1 19-Apr-13 Issued for Construction CHR JBM BJP AGC

Note 8

SECTION B-B SECTION A-A

Notes: 1. Pipe Info: 2. The reel can be lifted using a standard spreader beam. 3. Pipe and end fittings secured to reel using lever hoists. For rigging details refer to: 3642NKT001: 3642-DWG-LPP-100/ID-F-BK-P-SCH003-D06-0001 3642NKT002: 3642-DWG-LPP-101/ID-F-BK-P-SCH003-D06-0004 4. 5 Te Hold Back Wire 50 m. 5. Hold Back Wire Bracket placed on spoke. 6. First end off reel 3642NKT001A /3642NKT002B 7. End fitting to be packed in rubber and foam to protect pipe and end fitting. 8. Expanded polystyrene support blocks. 9. Actual winding of pipe may be slightly different. 10. Weight info:

FRONT ISO VIEWBACK ISO VIEW

SECTION C-C

CoG

FR

ON

T

FR

ON

T

Note 7

Note 8

Note 9

Note 6Note 7

3642NKT0023642NKT001

3642NKT001A

3642NKT002B

Note 5

Note 4

3642NKT002A Dividerring

Identical Polystyrene ramps

Note 5Note 4

Note 2

3642NKT001B

Procedure Subsea Pre‐commissioning Procedure C‐84514‐BK‐KK0‐PRO‐GN‐00‐0014 Rev.0B ConocoPhillips Indonesia Inc.Ltd Page 22 of 25

Appendix B – Calculation

Project Name

Project Number

Pipeline Reference

Company

Contractor

Subcontractor

Location

Scope of Work

Start Point

End Point

Enter Pipeline Data 6"

Section 1 Section 2 Section 3Outer Diameter 168.3 mm mm mmWall Thickness 14.27 mm mm mmInternal Diameter 139.76 mm 0 0Length 4500 m m mDesign Pressure 3600 PSI PSI PSITest Pressure 273.10 barg 0 barg 0 bargTest Pressure (DP x 1.1) 3960 PSI 0 PSI 0 PSIWater Depth / Elevation 90 m m m

NOTE DNV: TP = 1.25 DP; ASME: 1.4 DP

CALCULATION

Eastern Hub Mercury Removal ( EHMR ) – Water Project

R1812

6" 4.5KM FLEXIBLE FLOWLINE - FPSO TO WHP-A

CONOCOPHILLIPS INDONESIA, Ltd

PT. Timas Suplindo

OFFSHORE CONSTRUCTION SPECIALISTS (OCS)

Belanak Field, Indonesia

Gauging and Leak Testing

Belanak FPSO

Wellhead Platform A (WHP-A)

OFFSHORE CONSTRUCTION SPECIALISTS PTE LTD.

SUBSEA PRE-COMMISSIONING

;

Volume per meter 0.01534 m30.00 m3

0.00 m3

0.54 ft3 0.00 ft3 0.00 ft3

4.05 Us gal 0.00 Us gal 0.00 Us gal

Pipeline Volume 69.03 m30.00 m3

0.00 m3

2437.94 ft3 0.00 ft3 0.00 ft3

18237.07 Us gal 0.00 Us gal 0.00 Us gal

Total Volume 69.03 m3

2437.94 ft3

18237.07 Us gal

Launching Sequence

Lubrication / Flushing 300 m 4.60 m3162.53 ft2 1215.80 Us gal

Post Pig 1 m 0.00 m3 0.00 ft3 0.00 Us gal








Flooding

Distance Volume Equivalent

Project Name

Project Number

Pipeline Reference

Company

Contractor

Subcontractor

Location

Scope of Work

Start Point

End Point

CALCULATION

Eastern Hub Mercury Removal ( EHMR ) – Water Project

R1812

6" 4.5KM FLEXIBLE FLOWLINE - FPSO TO WHP-A

CONOCOPHILLIPS INDONESIA, Ltd

PT. Timas Suplindo

OFFSHORE CONSTRUCTION SPECIALISTS (OCS)

Belanak Field, Indonesia

Gauging and Leak Testing

Belanak FPSO

Wellhead Platform A (WHP-A)

OFFSHORE CONSTRUCTION SPECIALISTS PTE LTD.

SUBSEA PRE-COMMISSIONING

Gauge Plate InformationGauge Plate Sizing 129.80 mm Gauge Plate Quantity 2Gauge Plate Thickness 10 mm

Refer to Appendix E; NOV Factory Acceptance Test (FAT) Report

Pig Speed [m/sec] m3/hr m3/min m3/sec ft3/min Us gpm Minutes Hours Days0.1 5.52 0.09 0.00 3.25 24.32 750.00 12.50 0.520.2 11.05 0.18 0.00 6.50 48.63 375.00 6.25 0.260.3 16.57 0.28 0.00 9.75 72.95 250.00 4.17 0.17

Flooding Projection Summary Duration

TIO

NS

Gauging

0.4 22.09 0.37 0.01 13.00 97.26 187.50 3.13 0.130.5 27.61 0.46 0.01 16.25 121.58 150.00 2.50 0.100.6 33.14 0.55 0.01 19.50 145.90 125.00 2.08 0.090.7 38.66 0.64 0.01 22.75 170.21 107.14 1.79 0.070.8 44.18 0.74 0.01 26.00 194.53 93.75 1.56 0.070.9 49.71 0.83 0.01 29.26 218.84 83.33 1.39 0.061 55.23 0.92 0.02 32.51 243.16 75.00 1.25 0.05

1.5 82.84 1.38 0.02 48.76 364.74 50.00 0.83 0.032 110.46 1.84 0.03 65.01 486.32 37.50 0.63 0.033 165.68 2.76 0.05 97.52 729.48 25.00 0.42 0.02

Line Volume 69.03 m3 Contingency 20.00%

Pressurization Volume 1.22 m3 Total Volume to Treat + Contingency 84.30 m3

Total Volume to Treat 70.25 m3

Required Volume BaseDescription Dosage m3 L L

Cocktail Chemical 550 0.05 46.36 38.64Corrosion Inhibitor 0.00 0.00 0.00Biocide 0.00 0.00 0.00Oxygen Scavenger 0.00 0.00 0.00Dye 50 0.00 4.21 3.51

Multitreat 5549R 0 0 0 Tros Seadye

Pig Speed [m/sec] m3/hr m3/min ft3/min Us gpm L/min L/min L/min L/min L/min0.1 5.52 0.09 3.25 24.32 0.05 0.000 0.000 0.000 0.0050.2 11.05 0.18 6.50 48.63 0.10 0.000 0.000 0.000 0.0090.3 16.57 0.28 9.75 72.95 0.15 0.000 0.000 0.000 0.0140.4 22.09 0.37 13.00 97.26 0.20 0.000 0.000 0.000 0.0180.5 27.61 0.46 16.25 121.58 0.25 0.000 0.000 0.000 0.0230.6 33.14 0.55 19.50 145.90 0.30 0.000 0.000 0.000 0.0280.7 38.66 0.64 22.75 170.21 0.35 0.000 0.000 0.000 0.0320.8 44.18 0.74 26.00 194.53 0.41 0.000 0.000 0.000 0.0370.9 49.71 0.83 29.26 218.84 0.46 0.000 0.000 0.000 0.0411 55.23 0.92 32.51 243.16 0.51 0.000 0.000 0.000 0.046

1.5 82.84 1.38 48.76 364.74 0.76 0.000 0.000 0.000 0.0692 110 46 1 84 65 01 486 32 1 01 0 000 0 000 0 000 0 092

Summary

Chemical Injection Rate

Chemical Name

Multitreat 5549R

Tros Seadye

ES

TIM

AT

ED

DU

RA

T

Chemical Injection

2 110.46 1.84 65.01 486.32 1.01 0.000 0.000 0.000 0.0923 165.68 2.76 97.52 729.48 1.52 0.000 0.000 0.000 0.138


Appendix C – Chemical Datasheet

REVISION DATE: January 2009

SAFETY DATA SHEET

MULTITREAT 5549R

1 IDENTIFICATION OF THE SUBSTANCE/PREPARATION AND COMPANY/UNDERTAKING

PRODUCT NAME MULTITREAT 5549R

PRODUCT NO. MT5549R

APPLICATION BIOCIDE OXYGEN SCAVENGER

Clariant Oil ServicesSUPPLIER

Howe Moss Place, Kirkhill Industrial Estate,

Dyce,

AB21 0GS Aberdeen (SCOTLAND)

+44 1224 797400

+44 1224 770118

2 COMPOSITION/INFORMATION ON INGREDIENTS

EC No. CAS-No.Name Content Classification

233-469-7 10192-30-0AMMONIUM BISULPHITE 10-30% Xi;R36/37/38. R31.

Coco alkyl dimethyl benzyl ammonium chloride 10-30% Xn;R22. C;R34. N;R51/53.

The Full Text for all R-Phrases are Displayed in Section 16

3 HAZARDS IDENTIFICATION

Contact with acids liberates toxic gas. Causes burns. Harmful to aquatic organisms, may cause long-term adverse effects in the aquatic

environment.

CLASSIFICATION C;R34. R31,R52/53.

4 FIRST-AID MEASURES

INHALATION

Fresh air and rest. Get medical attention if any discomfort continues. In contact with acids this product may liberate toxic gas. If inhaled

seek medical attention.

INGESTION

Rinse nose, mouth and throat with water. DO NOT INDUCE VOMITING! NEVER MAKE AN UNCONSCIOUS PERSON VOMIT OR

DRINK FLUIDS! Get medical attention immediately!

SKIN CONTACT

Immediately remove contaminated clothing. Rinse immediately with plenty of water. Get medical attention immediately.

EYE CONTACT

Make sure to remove any contact lenses from the eyes before rinsing. Promptly wash eyes with plenty of water while lifting the eye lids.

Get medical attention immediately. Continue to rinse.

5 FIRE-FIGHTING MEASURES

EXTINGUISHING MEDIA

Water spray. Foam, carbon dioxide or dry powder.

SPECIFIC HAZARDS

Fire creates: Hydrogen chloride (HCl). Nitrous gases (NOx). Sulphurous gases (SOx).

PROTECTIVE MEASURES IN FIRE

Full protective equipment including suitable respiratory protection

6 ACCIDENTAL RELEASE MEASURES

PERSONAL PRECAUTIONS

Wear suitable protective clothing to prevent skin contact. Use respiratory protection in confined areas.

ENVIRONMENTAL PRECAUTIONS

Take appropriate steps to prevent discharges to drains and watercourses. Causes depletion of oxygen in watercourses.

/ 41


MULTITREAT 5549RSPILL CLEAN UP METHODS

Absorb with vermiculite or dry sand. Collect spillage in containers, seal securely and deliver for disposal according to local regulations.

Flush area with plenty of water. Do not let washing down water contaminate ponds or waterways. Inform Authorities if large amounts are

involved.

7 HANDLING AND STORAGE

USAGE PRECAUTIONS

Avoid spilling, skin and eye contact.

STORAGE PRECAUTIONS

Store in tightly closed original container in a cool, dry well-ventilated place. Do NOT use container made of: polyethylene Mild Steel.

8 EXPOSURE CONTROLS/PERSONAL PROTECTION

PROTECTIVE EQUIPMENT

HAND PROTECTION

Impermeable material.

EYE PROTECTION

Use approved safety goggles or face shield.

HYGIENE MEASURES

When using do not eat, drink or smoke. DO NOT SMOKE IN WORK AREA! Wash at the end of each work shift and before eating, smoking

and using the toilet. Promptly remove any clothing that becomes contaminated. Wash promptly if skin becomes contaminated. Use

appropriate skin cream to prevent drying of skin.

9 PHYSICAL AND CHEMICAL PROPERTIES

APPEARANCE Liquid

COLOUR Clear Yellow

ODOUR Mild (or faint). Sulphur dioxide.

RELATIVE DENSITY 1.00 – 1.10 25 pH-VALUE, DILUTED SOLUTION 4 - 7 10

VISCOSITY Less than 50 cps 25

10 STABILITY AND REACTIVITY

STABILITY

No particular stability concerns.

MATERIALS TO AVOID

Oxidising agents and acids

HAZARDOUS DECOMPOSITION PRODUCTS

Contact with acids liberates toxic gas. Sulphurous gases (SOx).

11 TOXICOLOGICAL INFORMATION

INHALATION

Contact with acids liberates toxic gas.

INGESTION

Causes burns.

SKIN CONTACT

Causes burns.

EYE CONTACT

Causes burns.

12 ECOLOGICAL INFORMATION

ECOTOXICITY

Causes depletion of oxygen in watercourses. Degrades to form sulphates in the natural environment. Harmful to aquatic organisms, may

cause long term adverse effects in the aquatic environment for a continuous high concentration disposal.

/ 42


MULTITREAT 5549R

BIOACCUMULATION

Log Pow < 3

DEGRADABILITY

Readily Biodegradable; >60%

13 DISPOSAL CONSIDERATIONS

DISPOSAL METHODS

Dispose of waste and residues in accordance with local authority requirements.

14 TRANSPORT INFORMATION

UK ROAD CLASS 8

PROPER SHIPPING NAME CORROSIVE LIQUID, N.O.S (alkyl dimethyl benzyl ammonium chloride)

1760UN NO. ROAD IIIUK ROAD PACK GR.

Class 8: Corrosive substances.ADR CLASS 80 Corrosive or slightly

corrosive substance.

HAZARD NO. (ADR)

2XHAZCHEM CODE 1760UN NO. SEA

8IMDG CLASS IIIIMDG PACK GR.

F-A, S-BEMS Yes.MARINE POLLUTANT

1760UN NO. AIR 8ICAO CLASS

IIIAIR PACK GR.

15 REGULATORY INFORMATION

LABELLING

Corrosive

CONTAINSCoco alkyl dimethyl benzyl ammonium chloride

RISK PHRASES

R31 Contact with acids liberates toxic gas.

R34 Causes burns.

R52/53 Harmful to aquatic organisms, may cause long-term adverse effects in the aquatic

environment.

SAFETY PHRASES

S26 In case of contact with eyes, rinse immediately with plenty of water and seek medical

advice.

S45 In case of accident or if you feel unwell, seek medical advice immediately (show label

where possible).

S24/25 Avoid contact with skin and eyes.

S36/37/39 Wear suitable protective clothing, gloves and eye/face protection.

S60 This material and its container must be disposed of as hazardous waste.

/ 43


MULTITREAT 5549RUK REGULATORY REFERENCES

The Approved Supply List

STATUTORY INSTRUMENTS

Chemicals (Hazard Information and Packaging) Regulations.

APPROVED CODE OF PRACTICE

Safety Data Sheets for Substances and Preparations.

GUIDANCE NOTES

The Approved Classification & Labelling Guide

16 OTHER INFORMATION

ISSUED BY

SPS

REVISION DATE January 2009

REV. NO./REPL. SDS GENERATED Rev 1 / November 2006

SDS NO. O 797

RISK PHRASES IN FULL

Harmful if swallowed.R22

Contact with acids liberates toxic gas.R31

Causes burns.R34

Irritating to eyes, respiratory system and skin.R36/37/38

Toxic to aquatic organisms, may cause long-term adverse effects in the aquatic environment.R51/53

/ 44

Product Bulletin

Clariant Oil Services www.clariantoil.com

MULTITREAT 5549R SCAVENGER Description MULTITREAT 5549R is an aqueous solution of oxygen scavenger, biocide and corrosion inhibitor. It is based on a combination of ammonium bisulphite and amine, and is classified as readily biodegradable (>60% in 28 days). This product has already been approved by Lemigas (Indonesia R&D Center for Oil and Gas Technology) as material for hydrostatic test in seawater. Application MULTITREAT 5549R is used to prevent corrosion in oilfield pipelines and process facilities that are filled with water during hydrostatic testing operations or temporary mothballing of facilities. The product controls the propagation of corrosion-causing sulphate reducing bacteria (SRB), scavenges oxygen (which can also cause severe corrosion) and forms a protective film on the metal surfaces. The treatment rate depends on the source of water used and the length of testing / mothballing. Typical doses for seawater are shown below: Duration of test Dose rate (ppm) < 3 months 400 - 500 3 - 12 months 500 - 700 1 - 5 years 700 - 1000 Typical properties*

• Appearance (QPI 1) Clear Colourless to Yellow Liquid • Specific Gravity @ 25°C (QPI 2) 1.0 - 1.1 • pH 10% (QPI 3) 4 - 7 • Viscosity @ 25°C (QPI 4) Less than 50 cps

o * these do not constitute a specification

Handling** MULTITREAT 5549R is a corrosive liquid and should be handled with care. Avoid contact with skin and eyes. Wear appropriate safety clothes to minimise skin and eye contact. Consult MSDS for further details. ** Refer to MSDS for specific safety and health hazards.

This information is based on our present state of knowledge and is intended to provide general notes on our products and their uses. It should not therefore be construed as guaranteeing specific properties of the products described or their suitability for a particular application. Any existing industrial property rights must be observed. The quality of our products is guaranteed under our General Conditions of Sale.

PB-MULTITREAT 5549R-A4-January 09

Exactly your chemistry.

SEADYE/1Exactly your chemistry.The information in this publication corresponds to the present state of our knowledge and intends to describe our products and their possible applications. It is notintended to guarantee the suitability of particular product characteristics for a specific use. Any existing industrial rights are to be taken into consideration. Quality isguaranteed in accordance with our general conditions of sale.

Clariant Oil ServicesInternet: www.clariantoil.com

[Product Bulletin]SEADYE – LEAK DETECTION DYE

DescriptionSEADYE is a solution of the dye compound fluorescein in aqueous solution. The fluorescein dye is present asthe sodium salt, rendering it water-soluble.

ApplicationSEADYE is particularly recommended for systems where leaks and flow paths are required to be checked. Thefluorescent colour can be seen visually and with optical instruments if the system is under water.

SEADYE should be injected neat into the flowing water stream at 50 to 100 ppm depending on the potentialproblem to be checked. At these concentrations, the alkalinity of the product will be buffered by the salts inseawater.

Typical properties** (these do not constitute a specification)

Appearance Red liquidSpecific Gravity 1.07 – 1.10 at 25ºCpH (20 g/l) 7.0 – 11.0Viscosity < 10 cps at 25ºCFlash Point Above 65ºCPour Point Minus 5ºCSolubility Soluble in water and brines

HandlingSEADYE is irritant to the skin and eyes. Wear neoprene gloves, safety goggles and protective clothing. Consultproduct MSDS prior to handling.


Appendix D – Bi‐di Pig Drawings and Foam Pig Catalog

iNPIPE PRODUCTS™ Foam Pig Data Sheet

International Pipeline Products Ltd, Walkerville Industrial Estate, Catterick Garrison, North Yorkshire, England, DL9 4RRTel: (+44) 01748-834 577 Fax: (+44) 01748-834 121 - E-mail: [email protected] - [email protected]

Registered in England 1852899

Foam Pig Data Sheet

iNPIPE PRODUCTS™ manufacture a comprehensive range of foam pigging products which are designed for a variety of pipeline pigging applications including:

• Available in 4 standard densities of foam, Low Density (1.5-2lb/Cu.ft), Medium Density (5-7lb/Cu.ft), Heavy Density (8-10lb/Cu.ft) and Extra Heavy (20lb/Cu.ft)

• Therangeincludesanumberofdifferentfinishesdesignedforspecificapplications.TheseincludeBareFoam,FullyCoated, Criss Cross, Silicone Carbide and both Wire & Nylon Brushdesigns

• Foam pigs can be adapted to include transmitter cavities ,tow loops, gauge plates and encapsulated magnets for tracking

• Dual densities are available on request• Sizes ranging from 1/2” to 74”

Features:

Nominal Size A B C

2 58 86 113

3 82 117 149

4 108 163 205

6 159 240 304

8 212 318 402

10 266 375 450

12 318 460 580

14 350 550 695

16 403 605 750

18 454 680 850

20 504 752 950

22 552 818 1028

24 609 912 1140

26 660 1000 1260

28 707 1062 1334

30 765 1145 1423

32 810 1229 1546

34 850 1260 1586

36 909 1370 1710

38 970 1435 1795

40 1020 1515 1895

42 1066 1600 2005

44 1100 1600 2005

46 1225 1825 2286

48 1237 1780 2250

ProvingSwabbingDryingWipingDe-watering

ScrapingProduct RemovalDebris RemovalCleaningAggressive Cleaning

• Maintenance free, disposable product• Capable of travelling long distances• Can be customised to meet client requirements • Can reduce through a pipeline by up to 50% in diameter • Capable of negotiating short radius 90° bends and elbows• Able to traverse bends, mitres, tees and various valve

configurations• Can be used on pipelines not originally designed for pigging

activities

Benefits:

Standard Foam Dimensions

A comprehensive range of additional moulds are available to suit client specificpipeschedules.Dimensionsareapproximationsinmm.



• Proving: Ensuring that pig travels from one end of pipeline to the other

• Swabbing: Removing moisture from pipeline until dry• Drying: Initial drying of pipeline prior to air drying and

vacuum drying• Wiping: Removal of small particles/debris from pipe wall

Pig Application Key:

Foam Pig Selection Matrix:

• De-Watering: Removing water from pipeline • Scraping: Abrasive cleaning of the pipeline• Product Removal: Removal of product from pipeline• Debris Removal: Removing debris from pipeline

Foam Pig Data Sheet



Solution:

• Long run standard duty foam (LRSD)• Cleaninginepoxycoatedline(NFB)• Front pulling/handling rope (PF-F)• Transmitter cavity (TF-T)

Foam Pig Selection Example:

Foam Pig Data Sheet

Purpose: Cleaning (Debris Removal)

Pipeline Size & Length:

20” x 30km

Wall Thickness: 15.09-26.19mm (Sch 40-Sch 80)

Pipeline Material: API 5L Gr x 60. C.Steel w/internal epoxy coating

Barred Tees: YesAdditional Requirements:

Front pulling/handling rope requiredEM transmitter cavity required

Pulling Facility(Front, Rear, Dual)

Ref: PF-F/R/D

Double Nose

Ref: DN

Double Dish

Red: DD

NonFerrousBrush(For use on internally coated pipelines)Ref:NFB

Extra Long(Extended sealing applications)Ref: ExL

MaxiBrush(Total Coverage)

Ref:MB

Gauge Plate Facility

Ref: GPF

Tracking Facility(Transmitter or Magnet insert)Ref: TF-T/M

Maxi-Silicone Carbide(Total Coverage)

Ref: MSC

Single Spiral(Econo Pig)

Ref: SS

Extra Short(Ballvalve-Launch&Receiving facilities)Ref: ExS

By-PassFacility(Pluggable)

Ref:BPF

Foam Pig Extras:

In conjunction with the standard range of foam pigs iNPIPE PRODUCTS™ also offer a large range of special pig options to cater for a wide range of pigging applications:

REF: 20” LRSD-NFB-PF-F-TF-T

Client Reference List:

Foam Pig Data Sheet


Appendix E – NOV Factory Acceptance Test (FAT) Report

EASTERN HUB MERCURY REMOVAL - WATER (EHMR-W) Page 13 of 28

Factory Acceptance Test (FAT) Procedure Doc. no. 3642-DOC-FAT-100 Rev. 3

This document contains confidential information. All rights (including copyright, confidential information, trade secrets, and design rights) are owned by National Oilwell Varco Denmark I/S No use or disclosure is to be made without the prior written permission of National Oilwell Varco Denmark I/S. All rights reserved.

TM-ENG-028 Rev 17

5 GAUGE TESTING/PIGGING The gauge test is not applicable for the following cases:

• Pipes with reduced ID in both end-fittings/flanges, i.e. the above gauge disc criteria cannot be fulfilled.

• For smooth bore pipes, i.e. pipes with no internal carcass, a foam pig will be used for filling of the pipe.

Table 5-1 Gauge testing

Description Pipe No Gauge testing Min. gauge disc OD (mm)

5.5” WIR

5.5” WIF Plem

5.5” WIF Wellhead

3642NKT001

3642NKT002

3642NKT003

YES

YES

YES

129.8

129.8

129.8

5.1 GAUGE TESTING A bi-directional pig will be used during filling of the pipe in order to minimise the amount of trapped air. The pig will remain in the flexible pipe section during the hydrostatic pressure test. The pig will be equipped with a gauge disc capable of detecting any unacceptable obstruction. The gauge disc is made of aluminium with a thickness between 5 to 10 mm and is equipped with radial cuts with a spacing of 30° or 45°. The clearance between ID of the pipe and the OD of the gauge disc shall not exceed 10 mm, for pipes with an ID of less than 200 mm. For pipes with an ID of more than 200 mm, the gauge disc shall have an OD of no less than 95% of the pipe’s ID, ref. to Table 3-1.

5.2 ACCEPTANCE CRITERIA The acceptance criterion is the gauge disc/pig showing no sign of damage after having passed through the bore of the pipe. Minor scratches and scuffs are acceptable.


Appendix F – Reporting Format

Project Name Report No.

Discipline Document Type

Originator NATA Accreditation No. 19122

Revision date

Page 1 of 1

LEAK TESTING ACCEPTANCE CERTIFICATE

Project Name:

Date:

Client:

Time:

Location:

Operational Description:

Pipeline Description:

Pipeline ID

Length (Actual) Wall Thickness

Location of Test Equipment

Test Pressure

Initial Test Pressure at Test Location

Final Test Pressure at Test Location

Initial Subsea Temperature at Test Location

Final Subsea Temperature at Test Location

Duration of Hold Period

Description of Leak (if any)

Remarks

Detail OCS Engineer Timas Representative COPI Representative

Name

Date

Signature

c 84514 bk kk0 pro gn 00 0014; subsea pre commissioning procedure_rev.0b

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