hpps cleaning flooding hydrotest procedure

SNEPCO-BMIP-BNW and Saipem Consortium – led by SCNL.

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BMIP-BNW-D01938-LA-6180-00129-000

Rev. R01

D01938 - Fabrication of Flowlines & provision of Subsea Installation Services

Document Title:

HPPS FLOWLINE PRECOMMISSIONING – PRODUCTION & WI FLOWLINES CLEANING, FLOODING, PIGGING, GAUGING AND HYDROTESTING PROCEDURE

HPPS Document No: UK-120059-PR-006 Rev R01 Page 2 of 91

Proprietary Information: This document contains proprietary information and may not be partly or wholly reproduced without prior written permission from Shell Nigeria Exploration and Production Company Ltd.

Revision History

Revision No.

Date of issue Reason for change

P01 19/nov/2012

R01 07/dec/2012 Document revised as requested by Saipem, no comments received from rev P01


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TABLE OF CONTENTS

1.0 PROJECT OVERVIEW ............................................................................................................. 4 1.1 Purpose ....................................................................................................................................... 5 1.2 SPHU Operations ....................................................................................................................... 5

2.0 ABREVIATIONS AND DEFINITIONS ................................................................................... 7 2.1 Definitions .................................................................................................................................. 7

3.0 REFERENCES ......................................................................................................................... 10 3.1 Codes and Standards ................................................................................................................. 10 3.2 SNEPCo Reference Documents ............................................................................................... 10 3.3 Contractor Reference Documents ............................................................................................. 11 3.4 Halliburton Reference Documents ........................................................................................... 12 3.5 HPPS Project Organogram ....................................................................................................... 13

4.0 HEALTH, SAFETY ENVIRONMENT ................................................................................... 14 4.1 General Information ................................................................................................................. 14 4.2 Material Handling ..................................................................................................................... 16 4.3 Incident Reporting .................................................................................................................... 16

5.0 PREPARATIONS .................................................................................................................... 21 5.1 Resources Required – HPPS Supply ........................................................................................ 21 5.2 Resources Required – Client Supply ........................................................................................ 25

6.0 OPERATIONAL PROCEDURES ........................................................................................... 26 6.1 SPHU Pre-deployment procedure ............................................................................................ 26 6.2 Deployment of SPHU to Seabed .............................................................................................. 32 6.3 SPHU Pipeline Flooding .......................................................................................................... 37 6.4 Contingency Plans .................................................................................................................... 52 6.5 SPHU Pipeline Hydrotest ......................................................................................................... 54 6.6 Recovery of SPHU to Deck ...................................................................................................... 81 6.7 Calculations Spreadsheets/Results ........................................................................................... 85 6.8 Valve Status Checksheet .......................................................................................................... 86

APPENDIX 1 DRAWINGS .............................................................................................................. 89

APPENDIX 2 RISK ASSESSMENTS .............................................................................................. 90

APPENDIX 3 FIELD REPORT FORMS .......................................................................................... 91


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1.0 PROJECT OVERVIEW

BONGA North West is located in Nigeria OML 118 in approximately 900 to 1200 meters of water to the west and north of the BONGA FPSO. The project scope consists of 6 wells (4 off producers and 2 injectors) tied back to the BONGA MAIN infrastructure, but with subsea infrastructure capacity for 12 subsea wells. Subsea manifolds will be BONGA standard 4-slot manifolds. For the production system, the 10” flowlines 08 / 09 will be extended beyond PM1 and, for the water injection system, the 12” WFL01 will be extended beyond the existing WFTA-01. A topsides scope of work includes the addition of chemical injection systems; subsea controls systems and the tie-in of a dedicated new subsea umbilical. The production lines will be pipe-in-pipe insulated to control wax and prevent hydrate formation. A water-injection flowline will transport treated seawater from the Bonga Main FPSO via the existing Bonga Main water injection system to several subsea injection wells. The flowlines between the existing Bonga Main subsea system and the new Bonga Northwest subsea well manifolds will be:

10”PIP Production Flowlines,

12” Water Injection Flowline.

Fig 1.0: Bonga Northwest Field Layout


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1.1 Purpose The purpose of this document is to describe the pre-commissioning activities to be carried out on the Bonga Production & Water Injection Flowlines systems with respect to preliminary flooding, Cleaning, Gauging & Hydrostatic Testing of the newly installed pipeline and flowline infrastructure as stated below:

4 x Production segment 10.36” OD flowline pipe in pipe 1 x Water injection 12.75” OD flowline

The general layout of the flowline system is illustrated in figure 1 above.

1.2 SPHU Operations

The concept of the Subsea Pigging Unit is to perform controlled free-flooding of a pipeline using ambient seawater. The driving force is the differential pressure between the subsea ambient pressure due to static head and the empty pipeline. Once opened to the pipeline, raw seawater is drawn through a three-stage filter (the final filtration is to 50 micron), then through a Venturi Contraction, which doses chemicals from chemical bags mounted on the unit into the flooding stream. The water then passes through a turbine flowmeter, connected to a subsea datalogger mounted on the SPHU, which logs the flowrate and total fluid used to flood the line. The datalogger has a subsea display, displaying all the flooding and testing parameters, which can be monitored by ROV. The final stage is a flow control device which chokes back the flow to the desired pig speed. The desired flowrate is calculated during the engineering phase of the project and the correct size nozzles fitted to the SPHU before deployment. The flowrate through the SPHU is primarily controlled by the flow control system, but there is also an ROV operable ¼ turn valve to isolate the free-flooding system from the pipeline to stop flow through the SPHU to allow valve operations for pig train launching. Once the pressure in the pipeline has equalised with the ambient seabed pressure; free-flooding ceases. This usually occurs between 90% - 95% of fill volume, depending on water depth and pipeline size and geometry. The ROV supplies hydraulic power to drive a centrifugal boost pump to finish the flooding operations. For hydrotest, a second hydraulic powered pump is used to pressurise the line at agreed flowrates to project specific test pressures; again the test can be monitored by ROV on the datalogger display.


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Fig: 1.1: SPHU Operations Schematic


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2.0 ABREVIATIONS AND DEFINITIONS

The following abbreviations and definitions may be used throughout this document.

2.1 Definitions COMPANY Shell Nigeria Exploration and Production Company Limited (SNEPCo)

CONTRACTOR Consortium comprising Saipem Contracting Nigeria Limited (SCNL) as

Consortium leader, Saipem sa (SAIPEM), Saipem (Portugal) Comércio Marítimo, Sociedade Unipessoal, Lda. (SPCM) and Allied Dominion Oilfield Shipping Services Limited (ADOSS)

Bar Bar (incremental or differential value) Barg Bar Gauge COSHH Control of Substances Hazardous to Health Dep pt Depressurisation Point ENF Early Notification Form FPSO Floating, Production, Storage & Offloading Vessel GA General Arrangement Gal Gallon (US) = 3.785 litres GPS Global Positioning System HMS Halliburton Management System HP High Pressure HPPS Halliburton Pipeline & Process Services HSE Health Safety and Environment

IATA International Air Transport Association


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ICAO International Civil Aviation Organisation

ID Internal Diameter IMO International Maritime Organisation

JSA Job Safety Analysis

L Litre Ltr/min Litres Per Minute LOLER Lifting Operations & Lifting Equipment Regulations MSDS Material Safety Data Sheet

OD Outside Diameter PLET Pipeline End Termination PLR Pig Launcher Receiver PPE Personal Protective Equipment PPM

Parts Per Million

PRV Pressure Relief Valve Psi Pounds per square inch (incremental or differential value) Psig Pounds per square inch gauge PTW Permit to Work PUWER Provision & Use of Work Equipment Regulations P/P

Pressure Pump

RA

Risk Assessment

ROV

Remotely Operated Vehicle


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Sub-Contractor Halliburton Energy Services Nigeria Limited (HESNL) SPHU Sub-sea Pigging & Hydrotesting Unit

SWH Significant Wave Height TBT Tool Box talk


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3.0 REFERENCES

3.1 Codes and Standards No. Designation Document Number

1. Code of Federal Regulations 30, Parts 250, subpart J, “Mineral Resources”.

30 CFR 250

2. Gas Transmission Systems and Distribution Piping Systems – June 2008

ASME B31.8

3. Design, Construction, operation and Maintenance of Offshore Hydrocarbon Pipelines (Limit State Design)

API 1111

4. Pressure testing of Liquid Pipelines API RP 1110

3.2 SNEPCo Reference Documents No. Designation Document Number

1. Bonga Northwest Flowline System Basis and Summary of Design

BNW-SUB-050100-0005

2. Flowlines Precommissioning Plan (2/2007) BNW-SUB-050400-0001 3. Precommissioning of Deepwater pipelines

(3/2006) DEP 31.40.50.30 DWP

4. Deepwater Line fill Treatment (2/2006) DEP 37.81.42.37-EPP 5. Hydrostatic Pressure Testing Of Deep Water

Pipelines (3/2006) DEP 31.40.40.38-DWP

6. Subsea Hydrostatic Pressure Testing Of Deep Water Pipelines (1/2006)

DEP.37.81.42.36-EPP


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3.3 Contractor Reference Documents No. Designation Document Number

1. General Precommissioning Plan BMIP-BNW-D01938-LA-5507-00003-000088549-SAI-000-PCO-PRO-00003-000 Rev C01

2. Bonga Northwest HSE Plan BMIP-BNW-D01938-HX-5798-00003-000088549-SAI-000-HSE-PLA-00003-000 Rev C03

3. Project QA Audit Procedure BMIP-BNW-D01938-QA-6050-00001-000088549-SAI-000-QUA-PRO-00001-000 Rev C01

4. Documentation Management for Subcontractors BMIP-BNW-D01938-JA-6017-00003-000088549-SAI-000-DCO-PRO-00003-000 Rev C02

5. Quality Specification for Subcontractors – High Criticality

BMIP-BNW-D01938-QA-7753-00003-000088549-SAI-000-QUA-PPS-00003-000 Rev C02

6. Requisition For Supply Of Offshore Flowline Commissioning Services

BMIP-BNW-D01938-LA-5507-00003-000 088549-SAI-FLO-PCO-REQ-00036-000 Rev C01

7. Flow Assurance Study for Precommissioning Operations

BMIP-BNW-D01938-PX-4603-00003-000 088549-SAI-000-PCS-CAL-00003-000 Rev C01

8. Specification for Vertical Mechanical Connectors

BMIP-BNW-D01938-MP-7771-00002-000 088549-SAI-FLO-EQP-SPC-00002-000 Rev C03

9. Tagging, Packing, Marking and Shipping Instructions for Subcontractors

BMIP-BNW-D01938-VA-6042-00002-000 088549-SAI-000-SHP-PRO-00002-000 rev C01

10. Final Data Book preparation for Subcontractors

BMIP-BNW-D01938-JA-6017-00004-000 088549-SAI-000-DCO-PRO-00004-000 rev C01

11. Expediting and Correspondence Requirements for Subcontractors

BMIP-BNW-D01938-VA-1780-00002-000 088549-SAI-000-EXP-PRO-00002-000 Rev C01

12. Document Coding and Numbering Procedure

BMIP-BNW-D01938-JA-6017-00001-000 088549-SAI-000-DCO-PRO-00001-000 Rev C02

13. Non Conformities Managements for Subcontractors

BMIP-BNW-D01938-QA-5733-00033-000 088549-SAI-000-PIM-PRO-00033-000 Rev C01

14. Manufacturing Surveillance and Inspection for Subcontractors

BMIP-BNW-D01938-QA-5733-00002-000 088549-SAI-000-PIM-PRO-00002-000 Rev C01


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3.4 Halliburton Reference Documents

No Designation Document Number 1. HPPS Quality Plan FO-GL-HAL-PPS-008 2. HPPS Project HSE Plan FO-GL-HAL-PPS-102 3. Hazard Identification & Risk Assessment BP-GL-BU-HSE-ADM0103 4. General Work Site Activities BP-GL-BU-HSE-FSV0201 5. High Pressure Discharge Hose BP-GL-BU-HSE-FSV0206 6. Noise Management BP-GL-BU-HSE-HYG0306 7. Hand Tools (Non-Powered) BP-GL-BU-HSE-EQP0402 8. Portable Tools (Powered) BP-GL-BU-HSE-EQP0403 9. Contractor Review BP-GL-BU-HSE-GHS0605 10. Fall Protection BP-GL-BU-HSE-GHS0604 11. Work station lighting BP-GL-BU-HSE-GHS0607 12. Proper Lifting Technique BP-GL-BU-HSE-GHS0606 13. Communication Plan FO-GL-HAL-PPS-110 14. Project Management Plan FO-GL-HAL-PPS-102 15. Environmental Precautions Work Method WM-GL-HAL-PPS-420 16. Flooding Work Method WM-GL-HAL-PPS-434 17. Hydrotesting WM-GL-HAL-PPS-461 18. Pressure Test System Devices Standards ST-GL-HAL-PPS-410 19. Confirm Equipment Rig Up Standards ST-GL-HAL-PPS-301 20. Eye Protection BS EN 207/208 21. Environmental Management System Manual ISO 9001 22. Offshore Standard – Submarine Pipeline Systems DNV-OS-101 (2007)


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3.5 HPPS Project Organogram


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4.0 HEALTH, SAFETY ENVIRONMENT

4.1 General Information

4.1.1 All personnel will attend site safety induction prior to commencing any operations. Toolbox talks shall be performed with all relevant personnel and the appropriate form completed.

4.1.2 All relevant generic RA’s for the job MUST be reviewed, amended if necessary and signed off as reviewed by the HPPS Engineer/supervisor.

4.1.3 Workforce leaders will be identified and will be responsible for raising Work Permits and Isolation Certificates to suit site requirements.

4.1.4 HPPS Senior person on site (Project engineer, Field engineer or Supervisor) will ensure that all requirements of the permit are met before commencing work.

4.1.5 Barriers and warning signs will be erected to cordon off the area of testing or other hazard and no unauthorized personnel allowed within the area. Safety PA announcements will also be made before commencement and after completion of testing operations.

4.1.6 All hoses, fittings and instruments will be of a suitable working pressure, and leak tested to a pressure in excess of the highest system test pressure.

4.1.7 Confirm pressure setting of all Pressure Relief Devices and ensure they operate as required.

4.1.8 Ensure valve status check list filled in, signed off and filed as required. Ensure any additional and any special safety equipment is identified and provided before actual operations commence (e.g. special PPE for handling chemicals, eye wash stations, fire extinguishers, etc).

4.1.9 Should any leaks occur, the system will be depressurized to ambient pressure before rectification work may be allowed.

4.1.10 Valves under pressure should be opened and closed carefully (in a controlled manner).

4.1.11 All hoses should be secured (to a permanent fixture, i.e. structural support and not a scaffold) at regular intervals to prevent flailing in the event of a failure.

4.1.12 Pressure must not be allowed to exceed maximum test pressure. Where required, fluid will be bled off in measured amounts to keep pressure below maximum test pressure.

4.1.13 Whilst depressurising, discharge fluid will be routed to a safe area with discharge hose secured sufficiently to prevent flailing.

4.1.14 All personnel will wear personal protective clothing (Coveralls, Steel Toe-cap Boots, Hard-hat, Safety Glasses, and Gloves) at all times on the work site. Additional protective clothing will be worn in accordance with details of any hazardous substances being handled.


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4.1.15 Halliburton diesel driven units can exceed the recommended limit of 85-dB (A) for excessive noise. Personnel in the vicinity of these units shall wear ear protection while the engine in running.

4.1.16 All visitors witnessing the trials will wear PPE required by the Halliburton site (Hard-hat, Safety Glasses, Steel Toe-cap boots, Hi-Vis Vest/Jacket) at all times on the work site.


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4.2 Material Handling

GENERAL INFORMATION

Materials in the offshore environment can place operatives in situations that could be harmful to their health and as such any handling of material should be subject to the Risk Assessment process BP-GL-BU-HSE-ADM0103, in accordance with the requirements of the Control of Substances Hazardous to Health (C.O.S.H.H.) Regulations 1999 (S.I. 1999/437). The C.O.S.H.H. Regulations apply to substances classified as being carcinogenic, very toxic, toxic, harmful, corrosive or irritant under the (Chemicals Hazard Information and Packaging for Supply, CHIP)(Amendment) Regulations 2005 (S.I. 1999/197 as amended). They include substances such as pesticides, biological agents, dust and fumes, etc. Also, in respect of disposal, as a business you have a duty to ensure that any waste you produce is handled safely and within the law. This is your ‘duty of care’.

4.3 Incident Reporting

GENERAL INFORMATION

If the work included in this procedure is being performed at the contractor’s facility: The client reporting and investigating procedure will take precedence in the event of an emergency. However any incidents involving injury to Halliburton personnel, damage to equipment, or high potential “Near Misses” will also be reported through Halliburton’s own reporting system, the Global Crisis Management plan. Synopsis of Global Crisis Management Plan EMERGENCY RESPONSE FRAMEWORK Emergencies are classified, under the Halliburton Company Crisis Management plan, in three general levels. Escalation potential must always be included in assessing the appropriate response levels.


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Level 1 Minor Incident

A worksite incident which can be handled by an on-scene HPPS Project engineer/Field engineer, or Senior Supervisor.

Level 2 Serious Incident

A worksite incident, where the on-scene HPPS Project engineer/Field engineer, or Senior Supervisor requires additional assistance from the offsite Incident Management Team for the Halliburton Production Enhancement PSL.

Level 3 Major Incident

A worksite incident where the Halliburton Production Enhancement Incident Management Team requires assistance from the Halliburton Business Unit Management Team.

Escalation to a Higher Level of Incident The decision on whether to escalate the level of the incident to a higher level, in the Halliburton incident reporting system, is taken by the person in charge of the site (HPPS Project engineer/Field engineer, or Senior Supervisor.). As a general guide the next level of response must always be notified of an emergency situation as near to its onset as practicable. If in doubt, always escalate the response to the next level.


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Duties and Responsibilities

The duties and responsibilities of our onsite personnel, (Project engineer, Field engineer or Supervisor) when involved in any incident or emergency, are outlined below

Assess the situation and decide the Response Level. (1, 2 or 3) Determine the extent of injury/damage Report the full circumstances of the incident, as soon as possible, to the HPPS Service coordinator or

deputy (during working hours), or HPPS duty engineer (if outside working hours) If a Level 2 incident mobilize the Incident Management Team by contacting +234-805-509-

7841/+234-803-681-5737 and request that the Management Rep / HSE Manager be contacted. The person answering the phone will request details of the incident

Do not talk to anyone else outside the company, except the client, about the incident and in particular do not release any information of any nature whatsoever to the media

Complete the Incident early notification form, as soon as possible and within 12 hours of the incident; (see sample of ENF in following page). Subsequently other forms may need to be raised

Keep abreast of the situation as it develops, logging information, time, personnel present, decisions made, etc

Offer assistance wherever possible Be aware of the reactions that any of your actions may have on other personnel or property

nearby Remain calm In an emergency the time of day does not matter. An immediate response and contact with

management is required


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Halliburton Nigeria Emergency Contact

Any incident involving first aid, lost time, leakages, etc. occurring at the job location, operational base or in traffic, needs to be communicated to Halliburton’s Service Supervision/Coordination and to the Emergency Coordinator at the Port Harcourt base. See contact list below:

CONTACT NAME GSM / LAND LINE COMMENTS LAGOS 01-4610780 Radio Room Sanjeev Verma 08055101463 All Bardon Francois 08055097821 BD Blessing Onyeike 08055097929 Security Tony Ezekeke 08055097906 WPS Josephat Edomobi 08055097885 Travels Faith City Hospital 01-2705612, 01-3200189 Ideal Eagle Clinic 08034000911,7757077, Dr. Hobeiche Havana Specialist Hospital 01-4705300, 01-834996 Emergency - 08027272727

SOS Clinic Lagos 01-7756080 (Dr Rutvien Raymon) PORT HARCOURT 084-462160 Radio Room Uche Samuel 08055097897 Mgt Team Lead/ER Anthony Alozie 08055097880 Fin/ER Henry Oki 08055097867 CMT Vincent Onwo 08036815737 HSE/ER Kanayo Nwaojei 08055097888 Security / ER Nobsam Hospital 080 37960393, Morning Star Clinic 084-230775, 08033130778 Princess Medical Clinic 084-233349, 08033373663 SMI Clinic (SOS) PHC 07034118459, 08034086093, 084-612475 Radio 148,880 MHz PHC 084-612475 Radio Room WARRI 053-251739 WPS-S/Line WARRI 053-251739 Radio Room Albert Ehikhuemhen 08055097813 Slick line / ER Kadiri Ahmed 08055097888 Security / ER Gabriel Eduviere 08055097853 Community Vertimon Clinic

08033882397, 053250042

Regal Clinic 08033488830, 08037164639 Westend Clinic 053250333, 08037078988 Lily Clinic 08050858766, 08035201186 SMI Clinic (SOS) WRI 08022906364, 053255023 Radio 148,880 MHz Gbeye Hospital 08033418580, 08034446362 Dr Danagogo and Dr Cyril


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HS & E Incident Early Notification Form

Sample below (FO-UK-HES-HSE-002-1 Rev 4)


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5.0 PREPARATIONS

5.1 Resources Required – HPPS Supply

Equipment

Item Description L

(m) B (m)

H (m)

W (Tons)

Qty

1. SPHU 3.25 1.90 5.74 12.0 12. Lift Pump 3.9 2 2.3 4.5 13. Air Driven Pressurising Pumps

(DHDA 66) 0.7 0.6 0.7 0.16 1

4. Hydraulic Power Unit 1.85 1.3 1.9 3 1 5. Storage Container 3.2 2.4 2.8 10.3 1 6. Test cabin 3.7 2.4 2.95 10 1 7. HP Recorders (0-1000 Bar) 0.35 0.14 0.5 0.01 2 8. Air driven Diaphragm/welding Pump 0.45 0.35 0.57 0.08 2 9. Hydraulic Power Unit 2.50 1.40 2.00 3.6 1 10. 2x Flooding Hose in Transport basket 10.35 1.00 0.65 5.4 111. Halliburton Standalone dataloggers 1 1 1 0.5 2 12. 10” HP Gauges (0-1000 Bar) Contained in item 6 2 13. SPHU Datalogger system Fitted to SPHU 1 14. Tool Kit Contained in item 5 2 15. Harnesses and Fall Arrestors Contained in item 5 2 16. 3m lengths of ¾” Air Hose 10k psi

crowsfoot Contained in item 5

2

17. 3m length x ¼” HP (10k) pressurisation Hose

Contained in item 5 2

18. 20m length x ¼” HP (10k) pressurisation Hose


19. 20m length x ½” HP (10k) pressurisation Hose


20. 40m length x ¾” HP (20k) pressurisation Hose


21. 20m Lengths of ¾” Air Hose 10k psi crowsfoot


22. 20K psi 6 or 10 Way Manifold Contained in item 5 1 23. PRV set at 600 Bar Contained in item 5 1 24. 1/4” NPT Ball Valve SS 15k psi Contained in item 5 3 25. 1/4” BSP Female Tee (Swivel) SS Contained in item 5 3


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26. 1/4” NPT / BSP Male - male SS 15k psi Contained in item 5 3 27. 1/4” BSP / BSP Male - Male SS 15k psi Contained in item 5 3 28. 1/4” BSP Female (Swivel) SS 15kpsi Contained in item 5 3 29. 1/4” BSP Plug SS 15k psi Contained in item 5 3 30. 1/4” NPT / NPT Male - Male, SS 15k psi Contained in item 5 3 31. 1/2” NPT Ball Valve SS 10k psi Contained in item 5 3 32. 1/2” BSP Female Tee (Swivel) SS 10k psi Contained in item 5 3 33. 1/2” BSP Swivel SS 10k psi Contained in item 5 3 34. 1/2” BSP / BSP Male - Male SS 10k psi Contained in item 5 3 35. 1/2” NPT / BSP Male - male SS 10k psi Contained in item 5 3 36. 1/2” NPT Male - 1/4” BSP Male ss 15k psi Contained in item 5 3 37. 1/2” NPT Male - 1/4” NPT Male ss 15k psi Contained in item 5 3 38. Turbine Flowmeters Fitted to SPHU 4 39. Set of SPHU spares Contained in item 5 1 40. Set of Electronics Kit Contained in item 5 1 41. Set of DME irons Contained in item 5 1 42. Hydac spin Oil filters Contained in item 5 2 43. Set of compensators Fitted to SPHU 2


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Consumables

Item Description

Qty

1. Filter Elements – included within spares kit for test pumps 4 2. Shell Tellus 46 Hydraulic Fluid (Saipem supply) 209 ltrs 3. Spare seal kits for pumps 2 4. Work gloves (pack) 1 5. Sticky labels (roll) 1 6. Junior Hacksaw blades (pack) 1 7. Safety glasses – clear (pair) 4 8. Set of Hot stab 2 9. 2” Female Receptacle 1 10. Set of Stab tools & seals 1 11. 6” CNAF Gaskets 2 12. 8” CNAF Gaskets 2 13. 3” 300 R35 Flanges 2 14. R35 Ring Gaskets 2 15. Stud Bolts c/w Nuts: M30 x 180mm 4 16. R45 Ring Gaskets 2 17. Stud Bolts c/w Nuts: 1-1/8” x 1-1/4” 4 18. Spill Kits 2 19. Caution tapes (roll) 2 20. Moffat Stab (Saipem supply) 3 21. Fluoreceine Dye 60 ltrs 22. Norust CR 486 (corrosion inhibitor) 1128 ltrs


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Project Critical Items

Item Description

Qty

1 Spare Harben Pump 1 2 Spare Boost Pump 1 3 Spare Flooding hose (2 per set in transit box) 14 Spare Test Hoses 25 Spare Complete Datalogging System 1 6 Spare Complete Flowmeter Package for SPHU 1 7 Deepstar 3-way Port Connector Seal Kit 3 8 Fittings Package 1 9 Set of Compensators 1 10 Repair Package – Seals/Gaskets (set) 4

Personnel

Item Discipline Qty

1 HPPS Engineer 1 2 HPPS Supervisor 2 3 HPPS Operator/Technician 2


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5.2 Resources Required – Saipem Supply

Equipment/Consmables

Item Description

Qty

1 2” Moffat Hot Stab crossed over to 2”1502 thread 2 2 2” Moffat Hot Stab crossed over to ¾” NPT 2 3 2” Moffat Hot Stab Seal Kit 24 4 Hot Stab seal Replacement Tool 1 5 2” Female Receptacle for Testing on Deck 1 6 Acoustic Signal Detection Equipment 2 7 801 pingers 5 9 Production Pigs (for PFL 13, 14, 15 & 16) 5 10 Water Injection Pigs (WFL-04) 2

Services

Item Description

Qty

1 Crane/ Rigging / Scaffolding support As Req. 2 Transport to and from site As Req. 3 Diesel As Req. 4 Lighting As Req. 5 Water Supply 2.5m³/min @ 7 bar As Req.6 Air Supply 100 psi @ 400 scfm As Req. 7 Electrical Supply 110V 60 Hz single phase As Req. 8 Electrical Supply 220-440V 50-60 Hz three phase As Req. 9 Standard engine lubricants As Req. 10 Disposal Consents As Req. 11 Civil & Mechanical works As Req. 12 Worksite Inductions As Req. 13 Permit to work system As Req. 14 Site Medical Response As Req. 15 Medical Evacuation As Req. 16 Messing, Ablutions and Accommodation As Req.


Document No.:

BMIP-BNW-D01938-LA-6180-00129-000

Rev. R01


Document Title:




6.0 OPERATIONAL PROCEDURES

6.1 SPHU Pre-deployment procedure

6.1.1 Prior to deployment of the SPHU, the HPPS engineer/supervisor will introduce the ROV supervisors and operators to the operation and layout of the SPHU.

6.1.2 Particular attention will be paid to valve arrangement & control, instrumentation & control, pressure gauges, DeepStar 3-way connector positioning and operation.

6.1.3 Before operations commence, the HPPS Test Engineer will perform a Tool Box Talk with the HPPS crew, relevant personnel and Saipem Rep on the Technical and safety aspects of the operations, highlighting as a minimum the following topics:

Safety – MSDS and COSH assessment on site Incident Reporting Process Review of generic Risk Assessments (job specific RA’s will be developed if required) Operational pressures Equipment layout Duration of operations Rectification of leaks Location of and setting of PRV Communications Frequency of PA Announcements Housekeeping Impact on other activities Any questions

6.1.4 ROV supervisor and operations shall sign on the TBT, acknowledging their understanding of the SPHU functions.

6.1.5 Raise Permit for Pre-deployment operations.

Name Permit No. Sign Date

6.1.6 Temporary barriers will be erected around the worksite. Check communication in the Vicinity of test boundaries, prior to applying any pressure.

Name Sign Date


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6.1.7 During pressurisation, stabilization period, hold period and depressurisation of the given system, no personnel will be allowed in the vicinity. Only essential personnel associated with testing shall be allowed within the immediate vicinity of the test ends.

6.1.8 Before any remedial work on a section or associated connection under pressure is permitted, the pressure will be reduced to ambient.

6.1.9 Ensure hydraulic fluid in the SPHU components is compatible with that used by the ROV – Shell Tellus Oil.

6.1.10 If the unit is to be tested on deck, water will be obtained from the vessel mains to an empty IBC.

Chemical Bag Fill

6.1.11 Raise Permit for chemical bag filling operations.

Name Permit No. Sign Date

6.1.12 Check communications between, Deck foreman and Vessel Bridge. Erect temporary barriers around work sites. Inform of commencement of chemical transfer.

Name Sign Date

6.1.13 Rig up clear chemical hoses to chemical bags and insert into the hold at the bottom of the SPHU.

6.1.14 Secure the chemical bags by tying off with rope to the SPHU structure; this will ensure the bags do not slide around during deployment.

Name Sign Date

6.1.15 Rig up chemical transfer equipment as per UK-120059-DR-010. Ensure service air supply to diaphragm pump is connected and open to enable pump operation.

HSE

HSE

HSE


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6.1.16 Open the following valves on the temporary chemical transfer system.

Valve

Identification Description

PID/Drawing Reference

Location Status Check

FV01 Fill Valve 1

UK-120059-DR-010

Temporary chemical transfer

system (IBC isolation Valve)

Open

FV02 Fill Valve 2

UK-120059-DR-010

Temporary chemical transfer

system (Pump Isolation Valve)

Open

CF01 Fill Valve 3

For Chemical Bag 1

UK-120059-DR-010 In SPHU Open

6.1.17 Commence pumping to transfer chemical from the IBC to the chemical bags.

6.1.18 At all times monitor clear hose connected to valve CF01 – just upstream of chemical filter. As soon as chemical is noticed flowing into this valve, shut off the diaphragm pump as depicted below.

Valve Identification

Description PID/Drawing

Reference Location Status Check

FV01 Fill Valve 1 UK-120059-DR-

010 Temporary chemical transfer system (IBC

isolation Valve Closed

FV02 Fill Valve 2

UK-120059-DR-010

Temporary chemical transfer system (Pump Isolation

Valve)

Closed

6.1.19 Break the hose connection at the fitting on the clear hose link to the chemical bag (suction end) – ensure that a chemical spill mat is placed to absorb any spill, and then cap the fitting and secure hose unto the SPHU.

6.1.20 Flush the temporary chemical transfer system thoroughly with clean water into a waste IBC.

6.1.21 Connect the temporary chemical transfer system to the second chemical storage tank.

6.1.22 Reconnect the hose link to the second chemical bag (suction end) and repeat items 6.1.21 to 6.1.25 this time substituting CF02 for CF01.

6.1.23 Flush the temporary chemical transfer system with clean water and store away hoses and pump in tools container.

6.1.24 Break the hose connection at the fitting on the clear hose link to the chemical bag (suction end) –


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ensure that a chemical spill mat is placed to absorb any spill, and then cap the fitting and secure hose unto the SPHU.

6.1.25 Flush the temporary chemical transfer system with clean water and store away hoses and pump in tools container.

Pre-deployment Checklist

6.1.26 Carry out the following checks on the unit. Refer to doc: FO-GL-HAL-PPS-422 – SPHU Pre-Deployment Checklist.

Pump and bleed hydraulic fluid through the Deepstar Stab (3-way port) to ensure it is free of air

Charge hydraulic compensators to 2/3 full

Ensure hydrotest pump crankcase has enough oil

Properly inspect the SPHU, paying special attention to all hydraulic hose/tube connections and fittings, pipework flanges, electrical connections, pump mountings and hydraulic connections as well as filter cage

Check smooth functioning of SPHU valves

Power up the datalogger and function test sensor cables and display lights

Ensure that bolts on dataloggers pod are tight

Check charge on batteries, if needed re-charge them

Inspect the seals on the hydrotest panel hotstabs and if in doubt of their condition replace them

Inspect seals on the Saipem provided hotstabs and if in doubt of their condition replace them

Prepare 2 x 40m lengths of hydrotest hose by connecting the 1” hotstab and client supplied 2” Moffat hotstab at either end

Connect the hydrotest lines to the panel via the 1” stabs. Each hose in use will be demarcated with a different colour and the ports on the SPHU hydrotest panel will be similarly marked to identify each system being tested

Fit Coflexip jumper hose with buoyancy modules (at 50m deployment check if configuration is correct)

Assemble Coflexip hose c/w bouyancy modules unto the SPHU Panel Saddles

Replace the straight lift slings with the offset lifting slings used for lifting and deployment of


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the fully assembled SPHU

Deploy outrigger mats

Fit chemical bags into hold and secure fast with rope (6.1.29 – 6.1.30)

Fill chemical bags with sufficient chemicals for the operation (this operation to be carried out 4-6 hrs before deployment (6.1.31 – 6.1.38)

6.1.27 The following readings of the instrument panel should be recorded in the table below prior to deployment. The data logger will have to be powered up to obtain some of these readings.

6.1.28 Once the readings on the datalogger have been checked and recorded, power down the datalogger.

Instrument Identification

Instrument Description Location Reading/Status Check

V1 Bulk volume – Flood

display Data logger

C1 Chemical volume – Flood

display Data logger

C2 Chemical volume – Flood

display Data logger

P3 Ambient Pressure – Flood

display Data logger

T1 Temperature – Flood

display Data logger

P1 Hydrotest Pressure – Hydro

display Data logger

P2 Ambient Pressure – Hydro

display Data logger

H1 Hydro volume – Hydro

display Data logger

T2 Temperature – Hydro

display Data logger

HG1 Hydraulic pressure –

Supply On Hydrotest

Panel

HG2 Hydraulic pressure –

Return On Hydrotest

Panel

HG3 Hydraulic pressure – Case On Hydrotest

Panel


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6.1.29 Confirm the following valve status on the SPHU (ref drawing no. UK-120059-DR-008 in preparation for the deployment operation.

Valve




LPV1 Filter Isolation valve UK-120059-DR-008 In SPHU Open HPV1 Line Isolation valve UK-120059-DR-008 On top SPHU ½ Open

HPV2 Booster Pump Isolation valve

UK-120059-DR-008 On top SPHU ½ Open

CV01 Chemical Control

valve UK-120059-DR-008 On Hydrotest

Panel 3 Turns Open

CV02 Chemical Control


Panel 3 Turns Open

DV1 Programme Diverter


Panel Set on P1

HTV01 Hydrotest Isolation

valve 1 UK-120059-DR-008 On Hydrotest

Panel ½ Open



Panel ½ Open



Panel ½ Open



Panel½ Open



Panel ½ Open

VV01 Hydrotest Vent valve UK-120059-DR-008 On Hydrotest

Panel ½ Open

N/A Boost pump vent: 4

JIC UK-120059-DR-008

On Boost pump Capped

N/A Boost pump drain: 4

JIC UK-120059-DR-008

On Boost pump Capped

N/A Chemical fill point UK-120059-DR-008 On chemical

bag Capped

N/A Chemical fill point UK-120059-DR-008 On chemical

bag Capped

CF01 Chemical Discharge

Valve UK-120059-DR-008 On chemical

bag Open

CF02 Chemical Discharge

Valve UK-120059-DR-008 On chemical

bag Open


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6.1.30 Confirm checks have been conducted according to this procedure. Ensure TBTs, TRAs, test charts and reports are signed off.

Name HPPS Sign Saipem Sign Date

6.2 Deployment of SPHU to Seabed

6.2.1 Prior to deployment of the SPHU, the HPPS engineer/supervisor will inform the Saipem Rep. and vessel master of the readiness to deploy.

6.2.2 Before operations commence, the HPPS Test Engineer will perform a Toolbox Talk with the HPPS crew, relevant personnel and Saipem Rep on the technical and safety aspects of operations, highlighting as a minimum the following topics.

Safety Incident Reporting

Review of generic Risk Assessments (job specific RA’s will be developed if required) Operational pressures Equipment layout Duration of operations Emergency actions Communications Frequency of PA Announcements Housekeeping Impact on other activities Any questions


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6.2.3 Raise Permit for Deployment operations.

Pipeline Permit No. Name Sign Date

PFL13

PFL14

PFL15

PFL16

WFL04

6.2.4 Check communication between Vessel bridge, ROV/Dive control and Deck Foreman.

Pipeline Name Sign Date

PFL13

PFL14

PFL15

PFL16

WFL04


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6.2.5 The SPHU shall not be deployed in a sea state greater than 2m SWH nor without prior approval of the HPPS project engineer/supervisor.

6.2.6 Only minimum personnel are to be involved in the on-deck lifting and deployment operation.

6.2.7 On attaching the crane hook to the SPHU lifting slings, the slack will be taken up on the sling and shackle lifting assembly and correct orientation established.

6.2.8 The unit houses flexible chemical bags in the bottom hold, for this reason it is important that the unit is carefully lowered through the splash zone.

6.2.9 Once the chemical hold is through the splash zone, the SPHU should be quickly lowered beyond the top of the unit to prevent wave/swell damage to the unit’s internals.

6.2.10 For the remainder of the deployment the SPHU will be deployed at a rate not exceeding 1m/s or as instructed by the HPPS engineer/supervisor.

6.2.11 Once overboard, a flotation check shall be carried out with the SPHU at a depth of 50m. The ROV shall establish that the hose is correctly balanced with the centre latch assembly holding the floating hose in place.

6.2.12 On completion of the flotation check, the SPHU shall be further deployed to a minimum height of 50m, and a maximum of 10m offset from the launching Abandonment PFTA/WFTA.

6.2.13 The SPHU will then be slowly lowered to clear the Abandonment PFTA/WFTA structure, all the time being monitored by the ROV.

6.2.14 Once the Saipem and HPPS engineer/supervisor approve the relative position of the SPHU, the unit shall be safely set down on the Seabed and monitored to establish stability.

6.2.15 If the SPHU is incorrectly positioned, the unit will be raised from the seabed and repositioned in its correct orientation.

6.2.16 When the orientation of the SPHU is correct, the ROV will inspect the Abandonment PFTA/WFTA to establish accessibility of the female stab receptacle.

6.2.17 HPPS engineer shall approve the position of the SPHU relative to the Abandonment PFTA/WFTA female stab receptacle.

6.2.18 HPPS supervisor shall request the ROV to release the crane wire from the master link of the SPHU.

6.2.19 The crane hook shall be offset of the SPHU and recovered to the short mark, so as to prevent collision with the ROV.


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6.2.20 HPPS supervisor shall instruct the ROV to power up the datalogger and function both the Flooding and Hydrotest modes. This should be done before the crane hook is fully recovered to surface.

Task Description Sign Date

1 Power up datalogger

2 Hydrotest and Flood modes properly functioning

6.2.21 If the SPHU datalogger is functioning properly, then the crane operator can recover the crane hook to surface., if however in the unlikely event that the SPHU’s datalogger is malfunctioned, the ROV shall reconnect the crane wire to the master link of the SPHU and the unit shall be recovered to surface according to section 6.6.

Task Description Sign Date

1 Crane hook can be recovered fully to surface.

6.2.22 The Coflexip jumper hose retaining clamp located on the hose saddle frame can be opened by pulling the monkey’s fist on the latch. This will allow the Coflexip jumper hose c/w buoyancy modules to float free of the support frame.

6.2.23 The ROV shall remove the dummy stab inserted in the female receptacle on the Abandonment PFTA/WFTA pressure cap and stow away in a safe location.

6.2.24 The ROV will then grab the handle on the jumper hose-handling clamp c/w 3D swivel assembly and client’s hotstab.

6.2.25 The ROV shall manoeuvre the hotstab towards the female receptacle and engage it completely.


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6.2.26 ROV to configure the following valves: HPV1, HPV2, CV1, HTV01, HTV02, HTV03, HTV04, HTV05, VV1; in preparation for the flooding operation.

Valve




HPV1 Line Isolation

valve UK-120059-DR-008

On top SPHU Closed


UK-120059-DR-008 On top SPHU Closed

CV01 Chemical

Control valve UK-120059-DR-008 On Hydrotest

Panel Closed

CV02 Chemical

Control valve UK-120059-DR-008 On Hydrotest

Panel Closed

DV1 Programme

Diverter valve UK-120059-DR-008 On Hydrotest

Panel Set on P1

HTV01 Hydrotest

Isolation valve 1 UK-120059-DR-008 On Hydrotest

Panel Closed

HTV02 Hydrotest


Panel Closed

HTV03 Hydrotest

Isolation valve 3

UK-120059-DR-008 On Hydrotest Panel

Closed

HTV04 Hydrotest


Panel Closed

HTV05 Hydrotest


Panel Closed

VV01 Hydrotest Vent


Panel Closed


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6.3 SPHU Pipeline Flooding

6.3.1 Before operations commence, the HPPS Test Engineer will perform a Toolbox Talk with the HPPS crew and Saipem Rep on the technical and safety aspects of operations, highlighting as a minimum the following topics.

Safety Incident reporting Process Review of generic Risk Assessments (job specific RA’s will be developed if required) Operational pressures Field, equipment and asset layout Duration of operations Rectification of leaks Location of and setting of PRV Emergency shutdown Communications Frequency of PA Announcements Housekeeping Impact on other activities Any questions

6.3.2 Ensure operational permit is valid.


PFL13

PFL14

PFL15

PFL16

WFL04

HSE


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6.3.3 Check communications between HPPS, and ROV Control.


PFL13

PFL14

PFL15

PFL16

WFL04

6.3.4 The HPPS engineer/supervisor shall be present or in direct contact with ROV control throughout the stages of panel readings/operations to advise and coordinate the ROV-SPHU interface.

6.3.5 If two ROVs are utilized for testing operations, one ROV can be connected to the SPHU via the Deepstar hydraulic stab assembly at all times, while the other ROV will be utilized for valve configuration and hose connection.

6.3.6 The onboard data logging system is activated or deactivated by operating the power on/off switch. This also serves to reset the data logger prior to or following a flooding operation. All data is retained in the logger to be downloaded at a convenient time.

6.3.7 The data logger display backlight is activated by flashing a beam of light on the display light sensor, it deactivates after a couple of minutes.

6.3.8 The following procedure is common to all SPHU flooding operations regardless of the line size.

6.3.9 All pipelines will be flooded from “Abandonment PFTA/WFTA/WFTA to Initiation PFTA/WFTA via the SPHU.

6.3.10 All water entering the pipelines will be filtered to 50 microns and chemically treated with the following chemicals:

Chemical Function Dosage ppmv/v

Norust CR 486 Corrosion Inhibitor, Biocide & Oxygen Scavenger

1000

Fluoresceine dye Dye 50

HSE


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6.3.11 Depending on the given pipeline size and depth, the specific flow rate and pig velocity may vary for each pipeline, but are within the threshold stipulated by Saipem.

6.3.12 Information on the expected flow rate and pig velocity for each pipeline to be flooded is given in the calculations spreadsheet in section 6.7.

6.3.13 If the SPU is being monitored during flooding operations, the following operations will be recorded at 15 minute intervals :

Time Volume of water pumped Flow rates Chemical Injection volumes

6.3.14 Before flooding operations commence, ensure that Saipem Valve checklist in the tables for Northwest system contained in section 6.8 shall be reviewed and signed off by all the concerned parties.

6.3.15 During flooding operations, use the following table to cross reference the corresponding valve status checklist (see section 6) for each pipeline.

Pipeline Operation Procedure Step Check

PFL13 Launch Pig 6.3.21

FCG Completion 6.3.51







WFL04 Launch Pig 6.3.21


6.3.16 Once the above operation has been completed, Saipem Rep. shall be informed of readiness to continue on to the flooding operations.

Name Saipem Sign HPPS Sign Date


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6.3.17 The Saipem Rep. shall give permission for flooding operations to proceed.

Name Saipem Sign HPPS Sign Date

6.3.18 Saipem Rep. / ROV Control to confirm valve status and ensure that the 2" hotstab (c/w check valve assembly) is engaged in the "J" hook at the Initiation PFTA/WFTA (receiving end).

Valve




R1 Receiving Cap valve

N/A Initiation

PFTA/WFTAOpen

PFL13 PFL14 PFL15 PFL16

6.3.19 Vessel to relocate to Abandonment PFTA/WFTA (Pig launch end) and then instruct ROV control to confirm valve status on launching end.

Valve




L1 Launching Cap Valve

N/A Abandonment PFTA/WFTA

Closed


WFL04


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6.3.20 Instruct ROV to be in position 3 metres downstream of where the pig has been installed in the pipeline i.e. at the second weld from the Abandonment PFTA/WFTA. This is so that a confirmation of pig launch is obtained by the acoustic pinger detector.

6.3.21 On approval from the Saipem Rep. and HPPS engineer/supervisor, the designated flooding valve (L1) on the launching Cap will be slowly opened in 30° increments. This will prevent any excessive shock pressure/flow being applied to either the SPHU or the launcher assembly.

Valve




L1 Flooding

valve N/A

Initiation PFTA/WFTA

Open

PFL13 PFL14 PFL15 PFL16 WFL04

6.3.22 On authorization by the HPPS engineer/supervisor, the ROV will land on the top of the SPHU frame to power up the data logger.

6.3.23 Ensure programme selected on the data logger display indicates flooding operations. If not instruct ROV to switch off data logger, toggle the programme switch to FLOOD and power up the logger again.

6.3.24 All readings displayed on the data logger as well as gauges shall be recorded by the HPPS engineer/supervisor.


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Launch Pig

6.3.25 Instruct the ROV to set the Chemical control valve on the SPHU panel at the required number of turns open from its closed position. This is to allow spiking of chemicals from the onset of Pig launch.

Valve




CV01 & CV02

Chemical Control valves

UK-120059-DR-008

On ROV Display Panel

Closed

PFL13

PFL14

PFL15

PFL16

WFL04

6.3.26 On authorization from Saipem Rep., Instruct the ROV to slowly open valve HPV1 enabling the launch of the Pig and the flooding of the flowline with a line volume of treated filtered sea water.

Valve




HPV1 Line Isolation

valve UK-120059-

DR-008 On top SPHU Open

PFL13

PFL14

PFL15

PFL16

WFL04


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6.3.27 ROV to utilize hydrophone and check for signal of acoustic transmitter located in the pig. This signal should be triggered by the water activation mechanism.

Transmitter Pipeline Check

Signal Located


Note: Frequencies of acoustic pingers for any given flowline will be known only after installation into Pig during Pig loading of the PFTA/WFTA s and will be provided prior to mobilisation. This list should be approved of by Saipem.

Free-Flooding

6.3.28 Instruct the ROV to slowly increase or decrease the setting of CV01 & CV02; Chemical Dosing Valves, to regulate the spiking of the filtered Seawater with chemicals.

6.3.29 HPPS engineer/supervisor to advice on dosage level and number of turns, with respect to the given pipeline.

6.3.30 During the flooding operations, the HPPS engineer/supervisor shall monitor the flooding readings on the SPHU’s datalogger and over a 15 minute span record readings in 5 minute intervals, to establish correct bulk water flow and chemical addition. Thereafter, readings will be recorded every 15 minutes. Use record sheet.

6.3.31 From the figures, the correct ppm of chemicals can be established, checked and approved by the client representatives. Concentration levels are to be in accordance to point 6.3.10.

6.3.32 All readings shall be recorded by the HPPS engineer/supervisor on the relevant HPPS form.


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6.3.33 The flow of treated filtered seawater will cease when the line is pressure balanced i.e. the pressure behind the pig matches the pressure of compressed air ahead of the pig. This will be indicated by the datalogger pressure value reading depth pressure.

6.3.34 The HPPS engineer/supervisor will check the data logger display pod and note the bulk flow and chemical flow total. From this a ppm of chemicals injected so far can be calculated for the bulk flow and compared to the line volume table for each flowline.

6.3.35 The ROV shall await instructions from the HPPS engineer/supervisor to carry out Boost pump operations.

Boost Pump Flooding

6.3.36 The boost pump is utilized to complete the final stage of flooding after pressure equalization of the pipeline. This is generally in the region of 5%÷10% of the pipeline volume.

6.3.37 The ROV shall use the bucket wrench to close HPV1 and open HPV2 – Boost pump isolation valve. A 90° rotation of the wrench indicates when the valve is in the fully open position (ref drawing: UK-120059-DR-009).

Valve




HPV1 Line Isolation

valve

UK-120059-DR-009

On top SPHU Closed

PFL13

PFL14

PFL15

PFL16

WFL04

HPV2 Line Isolation

valve

UK-120059-DR-009 On top SPHU Open

PFL13

PFL14

PFL15

PFL16

WFL04

6.3.38 The ROV will then proceed to connect the Deepstar hydraulic umbilical male stab c/w hoses (3 off) to the Deepstar female receptacle located on the SPHU. (Ref. drawing UK-120059-DR-009).

6.3.39 Inform ROV control that the SPHU hydraulic system is designed to function with a 100 ltrs/min supply of hydraulic oil at a max pressure of 200 barg.


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6.3.40 The ROV will engage the Deepstar stab by guiding the probe into its mating bush and allowing the spigot on the opposite side of the connector to self-centre in the guide plate.

6.3.41 When centred the ROV should grasp the centre fish tail or T-bar and push down while rotating to start the screw thread. The screw will enter 10mm into the bush before the flange starts to push the male connectors out of their housing and into the receptacles.

6.3.42 The Deepstar connector stab is properly connected when the back plate is flush with the male connector shroud plate.

6.3.43 The HPPS engineer/supervisor shall witness and advise on correct engagement of the Deepstar hydraulic stab assembly. The locking handle should engage in the female receptacle.

Task Pipeline HPPS Check Saipem Check

Deepstar hydraulic stab assembly properly engaged


6.3.44 The ROV shall power up its auxiliary power pack which will in turn engage the boost pump, to complete flooding of the line.

6.3.45 Instruct the ROV to confirm that the Bulk and Chemical flowmeters are both functioning during pumping operations, indicating that the SPHU Boost pump is operating properly. The pressure displayed on the datalogger will indicate the pressure generated by the Boost pump.


Bulk and Chemical flowmeters registering



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6.3.46 At start of Boost pumping, the ppm of chemicals injected into the pipeline shall be calculated, monitored and regulated if required.

6.3.47 Throughout operation of the Boost pump, ROV control and HPPS engineer/supervisor will monitor the pressures temperature and flow on the ROV hydraulic pack as well as on the SPHU to ensure the hydraulic system is functioning properly.

6.3.48 Ensure that the volume details for the given pipeline are known and noted, see section 6.7-for calculations.

6.3.49 When 100% of line volume has been pumped behind the Pig, and a pressure increase and/or no flow on the bulk flowmeter display is noticed inform ROV Control to stop hydraulic supply to boost pump.

6.3.50 An additional 2 attempts will be carried out to dead head the boost pump to confirm that the pig has arrived at the Initiation PFTA/WFTA pressure cap.


PFL13

PFL14

PFL15

PFL16

WFL04

6.3.51 Instruct ROV to close valve HPV2 – boost pump isolation valve.

Valve




HPV2 Line Isolation

valve UK-120059-

DR-009 On top SPHU Closed


WFL04

HSE


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6.3.52 All readings shall be monitored by the HPPS engineer/supervisor and recorded on the relevant HPPS form. Total volume pumped and the ppm for the line shall be calculated and recorded (concentration levels should be in accordance with section 6.3.10).

6.3.53 On approval from the Saipem Rep., instruct the ROV to close the inlet port valve (L1) on the Abandonment PFTA/WFTA launching Cap.

Valve






Closed



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6.3.54 After completion of flooding operations, the vessel will transit to the Initiation PFTA/WFTA where the ROV will confirm that the acoustic pinger fitted pigs have arrived by detecting the transmitted signal utilizing the ROV mounted hydrophone.

Transmitter Pipeline Check

Signal Located


Note: Frequencies of acoustic pingers for any given flowline will be known only after installation into Pig during Pig loading of the PFTA/WFTA is and will be provided prior to mobilisation. This list should be approved of by Saipem.

6.3.55 If pig receipt is not confirmed, the HPPS engineer/supervisor will decide on a further amount of filtered treated seawater to be pumped into the pipeline. In order to do so, repeat sections (6.2.25 to 6.2.26) to reconnect the SPHU to pipeline (if earlier disconnected) and open launching Cap inlet port valve (L1). Then conduct boost pump flooding according to section (6.3.37 to 6.3.51). HPPS engineer/supervisor will note volumes and pipeline pressures.


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6.3.56 Once Pig receipt is confirmed, and with the Saipem Rep. approval, instruct the ROV to close valve R1 on the Initiation PFTA/WFTA.

Valve




R1 Receiving Cap Valve

N/A Initiation

PFTA/WFTA Closed

PFL13

PFL14

PFL15

PFL16

WFL04

6.3.57 Contractor shall then remove the Initiation PFTA/WFTA hotstab c/w check valve.

6.3.58 Contractor shall remove the Initiation PFTA/WFTA pressure cap.

6.3.59 Contractor shall install a Pig catcher cage.

6.3.60 The vessel shall then transit to the Abandonment PFTA/WFTA and the ROV will configure the inlet valve L1 on the Abandonment PFTA/WFTA to the Open position.

Valve






Open



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6.3.61 The ROV shall then mate the Deepstar hydraulic male hotstab to the female hydraulic hotstab receptacle.

6.3.62 Once the ROV has mated the male and female Deepstar hydraulic hotstab, the boost pump shall be engaged and a client specified volume of water shall be pumped into the system to enable the Pig at the Initiation PFTA/WFTA to be slowly propelled out of the end termination and into the Pig catcher cage.

6.3.63 As soon as the boost pump is engaged, an increase in the pressure displayed on the datalogger should be noticed. The successful removal of the pig shall be indicated by a drop in pressure to ambient subsea pressure on the datalogger display.

6.3.64 The ROV shall then disengage the Deepstar hydraulic hotstab and close the Abandonment PFTA/WFTA Inlet valve, L1.

Valve






Closed


6.3.65 The vessel will transit to the Initiation PFTA/WFTA and the ROV shall visually confirm that the Pig is now located in the Pig catcher cage.

6.3.66 The Pig catcher cage shall then be disconnected from the Initiation PFTA/WFTA and the cage complete with the Pig recovered to the vessel deck.

6.3.67 Once on deck, the gauge plate mounted on the recovered pig will be retrieved and inspected.

6.3.68 Further operations will not commence without prior approval by all parties, i.e. Total, Saipem and HPPS, of the retrieved gauge plate.

6.3.69 Upon approval of the gauge plate, Saipem shall re-instate the pressure cap unto the Initiation PFTA/WFTA and then conduct a back-seal test in preparation for hydrotest operations.


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6.3.70 Upon satisfactory back-seal test, the ROV shall ensure that the Initiation PFTA/WFTA cap valve R1 is in the closed position, the dummy stab will be re-instated and the 2” hotstab c/w check valve recovered to the vessel deck.

Valve




R1 Receiving Cap Valve

N/A Initiation

PFTA/WFTA Closed

PFL13

PFL14

PFL15

PFL16

WFL04

6.3.71 The vessel will then transit to the Abandonment PFTA/WFTA.

6.3.72 At the Abandonment PFTA/WFTA location, instruct the ROV to disengage the 2” Moffat male hot stab from the Abandonment PFTA/WFTA launching Cap, retrieve and reposition the Coflexip jumper hose in its support frame saddle and lock it in position using the retaining clamp.


Return Coflexip hose to panel frame saddle and lock in

position.


6.3.73 For all pipelines to be flooded, cleaned and gauged, repeat sections 6.2.23 to 6.2.26 for hook-up and sections 6.3.16 to 6.3.69 for flooding operations.


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6.3.74 On completion of operation collate and organize all paperwork and present to the Saipem Rep. for acceptance and signature.


PFL13

PFL14

PFL15

PFL16

WFL04

6.4 Contingency Plans

Stuck PIG Dislodging Procedure – Free Flooding

If the pig is believed to be stuck in the pipeline during free flooding operations, the ROV will close the inlet valve L1 on the Abandonment PFTA/WFTA pressure cap, isolating the SPHU.

When the differential pressure behind the pig is deemed to have dissipated, the ROV will quickly re-open the inlet valve on the Abandonment PFTA/WFTA introducing seawater at subsea ambient pressure via the SPHU in a bid to shock the pig into moving.

If the pig remains stuck repeat this process 3 times.

If this process does not produce movement of the pig, check the operational logs and flooding report to ascertain the potential location of the pig in the pipeline.

Inform client representative, investigate possible causes of the problem and propose the use of the boost pump.

The ROV will then engage the 3-way Hydraulic Deepstar hotstab and supply hydraulic power to drive the Boost pump.


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Stuck PIG Dislodging Procedure – Boost Pump Flooding

In the event of a pig becoming stuck in the pipeline whilst boost pumping, the ROV will increase its hydraulic supply to the boost pump to increase the flow delivered by the pump.

Note that the boost pump deadheads at 10 bar and should not be run for more than 10 minutes at any time when deadheading.

Carry out process 3 times in the event the Pig remains stuck.

If this process does not produce movement of the pig, then ROV should close the Abandonment PFTA/WFTA inlet port valve L1 on the pressure cap to lock the 10 bar pressure from the boost pump behind the pig.

The vessel shall then transit to the Initiation PFTA/WFTA and the ROV will quickly open the Initiation PFTA/WFTA valve R1.

Carry out the process 3 times if the Pig is still stuck.

If this process does not produce movement of the pig, the vessel will then begin the search for the acoustic signal from the pinger inserted into the Pig.

If the option of reversing the flow is available, then the SPHU could be relocated to the Initiation PFTA/WFTA, and set up to introduce filtered seawater, to dislodge the stuck pig(s) and transport to the Abandonment PFTA/WFTA.

Note: Any of these methods requires a MOC (Management of Change) and a Deviation to procedure request should be filled out and submitted to the Project Manager by the HPPS engineer/supervisor.


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6.5 SPHU Pipeline Hydrotest

6.5.1 Before operations commence, the HPPS Test Engineer will perform a Toolbox Talk with the HPPS crew, relevant personnel and Saipem Rep on the technical and safety aspects of operations, highlighting as a minimum the following topics:

Safety

Incident Reporting Process

Review of generic Risk Assessments (job specific RA’s will be developed if required)

Equipment layout

Duration of operations

Rectification of leaks

Location of and setting of PRV

Emergency shutdown

Communications

Frequency of PA Announcements

Housekeeping

Impact on other activities

Any questions

6.5.2 The hydrotest panel valves do not require a torque tool and shall be opened using the ROV manipulator.

6.5.3 During operations, pipelines can be pressurized simultaneously using the SPHU. Some pipelines may also be pressurized through the standalone Halliburton Datalogger Units; to allow disconnection of the SPHU, once the test hold period has started, and allow the SPHU to be utilized for work on other pipelines.

6.5.4 Pressure relief valves for the hydrotest panel shall be pre-set to 5% of Test pressure over the TP for each set of pipelines. These shall be attached to a “1” hotstab, and mated with one of the receptacles on the panel.

6.5.5 All instrumentation has been calibrated within two months prior to mobilization with the calibration certificate available on site.

6.5.6 Pressure Relief Valves will be calibrated immediately prior to mobilization.

6.5.7 Pressure gauges and recorders will be chosen such that the test pressure falls within 50%-90% of the range of the instrument.


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6.5.8 Ensure operational permit is valid.


PFL13

PFL14

PFL15

PFL16

WFL04

6.5.9 Check communication between ROV control and client Rep., prior to applying any pressure.


PFL13

PFL14

PFL15

PFL16

WFL04

6.5.10 Before hydrotesting operations commence, ensure that the Saipem Valve checklist in the tables for Northwest system contained in section 6.7 shall be reviewed and signed off by all the concerned parties.

HSE


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RISK

6.5.11 During Hydrotest operations, use the following table to cross reference the corresponding valve status checklist (see section 6.8) for each pipeline.

Pipeline Operation Procedure Step Check

PFL13 Hydrotest 6.5.44

Completion 6.5.60


Completion 6.5.60


Completion 6.5.60


Completion 6.5.60

WFL04 Hydrotest 6.5.44

Completion 6.5.60

6.5.12 Ensure correct test hose identification during hook-up to pipeline and testing.

Pipeline Hose Identification

Name Sign Date

PFL13

PFL14

PFL15

PFL16

WFL04

6.5.13 During the pressurising, stabilization period, hold period and depressurising of the pipelines, HPPS engineer/supervisor shall be in direct contact with ROV control.

6.5.14 If two ROVs are utilized for testing operations, one ROV can be connected to the SPHU via the Deepstar hydraulic stab assembly at all times, while the other ROV will be utilized for valve configuration and hose connection.


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6.5.15 Instruct the ROV to set the 3-way programme diverter valve DV01 on the hydrotest panel to position P2 (Ref. drawing:UK-120059-DR-009). This will switch the hydraulic flow loop from the Boost pump to the Harben pump.

Valve




DV01 Programme

Diverter valve

UK-120059-DR-009

On Hydrotest Panel

Set on P2

PFL13

PFL14

PFL15

PFL16

WFL04

6.5.16 The ROV will then proceed to connect the Deepstar hydraulic umbilical male stab c/w hoses (3 off) to the DeepStar female receptacle located on the SPHU. (Ref. drawing:UK-120059-DR-009). Inform ROV control that the SPHU hydraulic system is designed to function with a 100 ltrs/min supply of hydraulic oil at a max pressure of 200 barg.

6.5.17 The ROV will engage the DeepStar stab by guiding the probe into its mating bush and allowing the spigot on the opposite side of the connector to self-centre in the V-shaped guide plate.

6.5.18 When centred the ROV should grasp the centre fish tail or T-bar and push down while rotating to start the screw thread. The screw will enter 10mm into the bush before the flange starts to push the male connectors out of their housing and into the receptacles.

6.5.19 The DeepStar connector stab is properly connected when the back plate is flush with the male connector shroud plate.


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6.5.20 The HPPS engineer/supervisor shall witness and advise on correct engagement of the DeepStar hydraulic stab assembly. The locking handle should engage in the female receptacle.


Deepstar hydraulic stab assembly properly engaged


WFL04


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RISK

6.5.21 Open the panel valves which have got the required hydrotest hose attached to them.


Panel Valve No. Status Date

PFL13

PFL14

PFL15

PFL16

WFL04

6.5.22 Instruct the ROV to power up the data logger.

6.5.23 Instruct the ROV to activate the data logger backlight by flashing a beam of light on the sensor. Ensure that the data logger is displaying the HYDRO programme. Readings of the displayed parameters shall be taken by the HPPS engineer/supervisor in the daily log.

Task Pipeline HPPS Check

Hydro programme displayed on datalogger


WFL04

6.5.24 Instruct the ROV to charge up the hydraulic supply line to the hydrotest pump by slowly increasing the flow to the pump motor.

6.5.25 This will power up the pump slowly and start pumping filtered seawater through the hydrotest hoses to ensure that they are flushed.


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6.5.26 Once a steady stream is seen to exit the hotstab at the end of the hydrotest hoses, shut of hydraulic supply to the hydrotest pump.


Shut off hydraulic supply to hydrotest pump


6.5.27 Instruct ROV to unreel the 40m ¾” test hose, taking care not to contaminate the hotstab with dirt.

6.5.28 The ROV should connect the hydrotest hose c/w hotstab to the designated inlet port on the Abandonment PFTA/WFTA pressurisation cap.


Connect hydrotest hose c/w hotstab to inlet port on pressurisation cap.


WFL04

6.5.29 PRVs are attached to a 1” hotstab, and are installed in a free panel port on the SPHU. This is to ensure safe testing of the hydrotest hose against the closed inlet valves as well as during pipeline pressurisation and hydrotesting operations.

6.5.30 A connection/leak test of the hydrotest hose (datalogger hose) shall be conducted against the closed inlet valve of the launcher at a pressure of 1.1 x max pressure of given pipeline (or 5bar below PRV set pressure) for 15 minutes. Note: If 1.1 x Max pressure is decided upon, make sure to isolate the PRV.


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RISK

6.5.31 Ensure that prior to testing, the correct line shall be opened using the corresponding panel isolation valves; HTV01 to HTV04.



PFL13

PFL14

PFL15

PFL16

WFL04

6.5.32 Any lines not being tested or connected require their corresponding valves to be closed.

6.5.33 Pressure is to be applied in a controlled manner, utilizing the ROV proportional control or two stage high-low control to drive the pump. Fill out HPPS pressurisation report: FO-GL-HAL-PPS-426.


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6.5.34 On attaining test pressure, a 15 minute hold shall be carried out to confirm connection integrity. Pressure shall be monitored on the SPHU data logger display, confirm operation of flowmeter.

Pipeline Hose Test

Hold Pressure Status Time Date

PFL13

PFL14

PFL15

PFL16

WFL04

6.5.35 On a satisfactory hose and stab integrity test, the ROV will discontinue supply of hydraulic fluid to the pump and then vent the lines via the hydrotest panel by opening HTV05 and VV01 – vent valve.

Pipeline Stop hydraulic

supply Vent to ambient Time Date

PFL13

PFL14

PFL15

PFL16

WFL04


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6.5.36 Pressure is to be confirmed at ambient before closing the vent valve VV01 and hydrotest isolation valve HTV05.

Valve




HTV05 Hydrotest Isolation valve 5

UK-120059-DR-009

On Hydrotest Panel

Closed

PFL13

PFL14

PFL15

PFL16

WFL04

VV01 Hydrotest Vent valve

UK-120059-DR-009 On Hydrotest

Panel Closed

PFL13

PFL14

PFL15

PFL16

WFL04

6.5.37 Confirm function testing completed satisfactorily. Complete function test acceptance sheet. ref: FO-GL-HAL-PPS-604.


PFL13

PFL14

PFL15

PFL16

WFL04

HSE


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6.5.38 ROV shall disconnect the Deepstar Hydraulic stab assembly –if necessary, fly to the Abandonment PFTA/WFTA pressure Cap for the pipeline to be tested, and configure the appropriate valve L1 open, in preparation for pressurisation.

Valve

Identification Description PID/Drawing




Open


6.5.39 The ROV shall return to the SPHU and reconnect the DeepStar hydraulic stab assembly, ready to commence pressurisation of the pipelines.


Reconnect Deepstar hydraulic stab assembly.


6.5.40 The system is to be strength tested using filtered seawater treated with the following chemicals:

Chemical Dosage ppmv/v

Norust CR 486 – Corrosion Inhibitor, Biocide and Oxygen Scavenger 1000 Fluoresceine Dye 50


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6.5.41 Pipeline specification for the given project determines the test pressures and durations.

Pipeline

Specification Required Test Pressure Test Duration

As per Northwest system

Precommissioning Specification

Saipem Supplied in Northwest system Pre-commissioning Specification.

Minimum 8 hour hold period

6.5.42 Test Pressures, the table below outlines test pressures for each system, a maximum of 101% of design pressure as stipulated in Northwest system specification.

Pipeline

Project Test

Pressure (Barg)

*Minimum Test

Pressure (Barg)

*MaximumTest

Pressure (Barg)

Allowable Drop in 8 hr hold period 0.2%

(Barg)

Allowable Drop in 1 hr period 0.2%

(Barg)

Average Pressure change

/°C (Barg)

PRV Relief

Pressure (Barg)

PFL13 413 413 418 0.83 0.104 3.42 434 PFL14 413 413 418 0.83 0.104 3.42 434 PFL15 413 413 418 0.83 0.104 3.42 434 PFL16 413 413 418 0.83 0.104 3.42 434 WFL04 423 413 428 0.85 0.106 3.37 445

*The pressures values displayed on the datalogger will be: Strength Test Pressure (as in table above) plus Subsea Ambient Pressure for the location at the given PFTA/WFTA.

Pressurisation

6.5.43 Inform Saipem Rep. and ROV Control of readiness to commence pressurisation operation. Check radio communications.


PFL13

PFL14

PFL15

PFL16

WFL04


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6.5.44 The hydrotest panel valve for the pipeline to be pressurised shall be in the open position and any unused lines/ports shall be closed.



PFL13

PFL14

PFL15

PFL16

WFL04

6.5.45 The vent valve VV01 and hydrotest panel isolation valve HTV05 shall be closed.

Valve





UK-120059-DR-009

On Hydrotest Panel

Closed

PFL13

PFL14

PFL15

PFL16

WFL04


UK-120059- DR-009 On Hydrotest

Panel Closed

PFL13

PFL14

PFL15

PFL16

WFL04

6.5.46 Hydraulic flowrate is controllable by ROV hydraulic supply percentage control or 2 stage high-low control.


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6.5.47 A pressure reading shall be taken and logged from the SPHU prior to commencement of pressurisation.


Panel Valve No.

Pressure Reading

Time Date

PFL13

PFL14

PFL15

PFL16

WFL04

6.5.48 The ROV hydraulic work pack shall be powered up and the hydraulic gauges monitored to confirm correct function. This will activate the SPHU hydrotest pump and pressurisation of the flow line will commence slowly.

Pipeline Power-up Supply Pressure

Supply Flow

Return Pressure

Case Pressure

Time Date

PFL13

PFL14

PFL15

PFL16

WFL04


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Air Inclusion

6.5.49 Commence pressurising at a rate not exceeding one bar/minute from ambient pressure, until 35% of TP has been reached, with volume of water injected, pressure, temperature and time being logged at 1% of TP intervals. Ref. document - Pipeline Pressurisation Report: FO-GL-HAL-PPS-426.

6.5.50 A 15 minute pause in pressurisation shall be allowed for leak checks to be conducted on the system, and an air inclusion report to be filled out. Ref. document - Pipeline Air Inclusion Report: FO-GL-HAL-PPS-428. The assessed air content shall not exceed 0.2% of the calculated total volume of the pipeline under test.

Pressurisation (Compliant with DNV-OS-101)

6.5.51 Continue pressurising at a rate not exceeding 1 bar/minute, until 80% of TP has been reached, with volume of water injected, pressure, temperature and time being logged at 5% of TP intervals. Ref. document - Pipeline Pressurisation Report: FO-GL-HAL-PPS-426.

6.5.52 At 80% of pressure, the hydraulic supply to the pump shall be reduced to allow a pressurisation rate of 0.69 bar/min with volume of water injected, pressure, temperature and time being logged.

6.5.53 The pressure is then increased without stopping at a rate of 0.69 bar/min (10 psi/min) with injected volumes, rates & pressures recorded.

6.5.54 After a one hour hold, water shall then be released to lower the pressure to 50% of the specified test pressure.

6.5.55 Once the pressure has reached the specified level, the flow line shall be repressurised as mentioned above.

6.5.56 On reaching test pressure isolate the system at the hydrotest panel.

6.5.57 Confirm test pressure has been achieved.


PFL13

PFL14

PFL15

PFL16

WFL04


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Stabilisation

6.5.58 On completion of pressurisation, a period of stabilisation will commence. There is no minimum or maximum period of stabilisation.

6.5.59 During the stabilisation period, readings of time, pressure and temperature are to be logged every 15 minutes and a pressure / temperature versus time graph is to be plotted to help assess when stabilisation is complete. Ref. document - Pipeline Test Report: FO-GL-HAL-PPS-427.

6.5.60 Should the pressure drop below the minimum test pressure at any time during the stabilisation period, it is to be re-pressurised and the stabilisation period extended.

6.5.61 During the stabilisation period, thorough leak checks are to be carried out by ROV on all flanges and connections at regular intervals.

6.5.62 Stabilisation of the line will be considered to be complete when pressure variations could be reconcilable to temperature change (i.e test water temperature stabilization occurance).See table in section 6.5.43 for values).

6.5.63 Confirm stabilisation has been achieved.


PFL13

PFL14

PFL15

PFL16

WFL04


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Removal of the SPHU if using the Standalone Datalogger

6.5.64 If the Halliburton subsea data logging unit only is to be used to collect data during pressurisation, and the SPHU is to be deployed elsewhere to operate, then instruct the ROV to configure valves on the manifold on the datalogger as below.

DPY

p

θ

+

DPY

DL3

DL4

Subsea Datalogger

ROV HotstabFemale Receptacle

ROV HotstabTo Pipeline FLET

Inlet

Vent

Outlet

DL6 DL5

DL1

DL

2

SPHUHydrotest

Hose

Fig: 6.0: Subsea Datalogger (c/w SPHU Interface)


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Valve




DL1 &

DL2

SPHU Double

Isolation Fig 6.3

On subsea datalogger manifold

Closed

PFL13

PFL14

PFL15

PFL16

WFL04

DL3 &

DL4

Pipeline Double

Isolation Fig 6.3


Open

PFL13

PFL14

PFL15

PFL16

WFL04

DL5 &

DL6

Vent Double Isolation

Fig 6.3 On subsea datalogger manifold

Closed

PFL13

PFL14

PFL15

PFL16

WFL04


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6.5.65 Instruct the ROV to slowly open HTV05 and VV01 on the SPHU ROV Panel and de-pressurise the hose between the SPHU and the datalogger to ambient.

Valve





UK-120059-DR-009

On Hydrotest Panel

Open

PFL13

PFL14

PFL15

PFL16

WFL04


UK-120059-DR-009

On Hydrotest Panel

Open

PFL13

PFL14

PFL15

PFL16

WFL04

Task Pipeline Ambient Pressure HPPS sign

Pressure shown on logger at subsea ambient.



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6.5.66 Once at ambient, instruct the ROV to close HTV05 and VV01.

Valve





UK-120059-DR-009

On Hydrotest Panel

Closed

PFL13

PFL14

PFL15

PFL16

WFL04


UK-120059-DR-009 On Hydrotest

Panel Closed

PFL13

PFL14

PFL15

PFL16

WFL04

6.5.67 The ROV is to monitor the pressure in the hose between the SPHU and the datalogger for 15 minutes to ensure that there is no pressure build-up and that the double block valves on the datalogger are not passing.

Task Pipeline Pressure build

up HPPS sign

Monitor for pressure build up in hose b/w SPHU and

standalone datalogger – 15min duration.

PFL13 PFL14PFL15 PFL16 WFL04


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6.5.68 Once the valves on the datalogger have been proven to not be passing, instruct the ROV to open HTV05 and VV01 on the SPHU ROV Panel and disconnect the SPHU from the Standalone Datalogger (Please refer to section on recovery of SPHU).

Valve





UK-120059-DR-009

On Hydrotest Panel

Open

PFL13

PFL14

PFL15

PFL16

WFL04


UK-120059-DR-009

On Hydrotest Panel

Open

PFL13

PFL14

PFL15

PFL16

WFL04

6.5.69 Upon disconnection of the SPHU the ROV will install a dummy stab to act as a block and debris cap at the manifold inlet port.

Task Pipeline HPPS sign

Disconnect SPHU from standalone datalogger.


Task Pipeline HPPS sign

Install debris plug at standalone datalogger

manifold female receptacle.



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Test Hold Period

6.5.70 On completion of a satisfactory stabilisation period and with the consent of the Saipem Rep. the test hold period can now commence.

6.5.71 If monitoring the test during the specified 8 hour hold period, readings of time, pressure and temperature are to be logged every 15 minutes within a test report. A pressure / temperature versus time plot is to be kept up to date during the hold period. Ref. document - Pipeline Test Report: FO-GL-HAL-PPS-427.

Acceptance Criteria

6.5.72 Confirm test hold period is in accordance with specification.


PFL13

PFL14

PFL15

PFL16

WFL04


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6.5.73 The pressure test is to be considered acceptable if the work has been performed in strict accordance with this procedure (and approved variations, if applicable) and any loss of pressure during the test hold period can be attributed to temperature change.

6.5.74 If the pressure rises above the maximum specified limit, due to changes in temperature, water will be bled from the system. Any water removed or injected will be quantified.

6.5.75 If pressure variances are to be taken into account, refer to calculations section for calculations and allowable values.

6.5.76 Once the test has been accepted an Acceptance Certificate is to be completed. Ref. document - Pipeline Acceptance Certificate: FO-GL-HAL-PPS-429.

Acceptance Criteria (Compliant with DNV-OS-101)

6.5.77 The Test shall be considered acceptable if the test pressure is maintained with no loss of internal pressure for the final 4 hours of the hold period.

6.5.78 During the first 4 hours of the hold period, correlation of any internal pressure losses to a corresponding temperature change shall be made for the test to be judged acceptable.

6.5.79 Examination of the visible sections of the pressurized system should reveal no leaks.

6.5.80 Should a drop in pressure occur during the test period that cannot be attributed to changes in the temperatures, the test duration shall be extended.

6.5.81 Additional testing and repressurisation of the line shall be performed until test acceptance criteria are achieved.

6.5.82 If the test pressure falls below the minimum test pressure, the pressure shall be increased to the minimum test pressure and maintained for the required hold period.

6.5.83 At no time shall the maximum allowable test pressure in this specification be exceeded.


Document No.:

BMIP-BNW-D01938-LA-6180-00129-000

Rev. R01


Document Title:




Depressurisation

6.5.84 Ensure that all parties involved have accepted the test hold period and signed off the test acceptance certificate before depressurisation of any pipeline.


PFL13

PFL14

PFL15

PFL16

WFL04

6.5.85 When the acceptance criteria have been met and agreed by Saipem, commence depressurisation at no more than 3.44 bar/min (50 psi/min).

6.5.86 Before any pipeline can be depressurised it should be connected to either the SPHU and depressurised subsea via the SPHU vent valve, or Halliburton Subsea Datalogging Unit.

6.5.87 The hydrotest hose should be connected to the launching cap inlet port valve.

6.5.88 Depressurisation shall be carried out via the hydrotest isolation valve connecting the panel to the pipeline, HTV05 and Vent valve VV01.


Document No.:

BMIP-BNW-D01938-LA-6180-00129-000

Rev. R01


Document Title:




Valve





UK-120059-DR-009

On Hydrotest Panel

Open

PFL13

PFL14

PFL15

PFL16

WFL04


UK-120059-DR-009

On Hydrotest Panel

Open

PFL13

PFL14

PFL15

PFL16

WFL04

6.5.89 OR

6.5.90 If depressurisation is to be carried out through the Standalone Datalogger, then instruct the ROV to slowly open DL2, DL1, DL5 and DL6.

DPY

p

θ

+

DPY

DL1

DL2

DL3

DL4

Subsea Datalogger

ROV HotstabFemale Receptacle

DL5DL6

ROV HotstabTo Pipeline FLET

Inlet

Vent

Outlet

Fig 6.1: Standalone Datalogger (configured for system depressurization)


Document No.:

BMIP-BNW-D01938-LA-6180-00129-000

Rev. R01


Document Title:




Valve




DL1 &

DL2

SPHU Double

Isolation Fig 6.4


Open

PFL13

PFL14

PFL15

PFL16

WFL04

DL3 &

DL4

Pipeline Double

Isolation Fig 6.4


Open

PFL13

PFL14

PFL15

PFL16

WFL04

DL5 &

DL6

Vent Double Isolation

Fig 6.4 On subsea datalogger manifold

Open

PFL13

PFL14

PFL15

PFL16

WFL04

6.5.91 On reaching subsea ambient pressure, instruct the ROV to close the valve L1 on the Abandonment PFTA/WFTA pressure cap.

Task Pipeline Ambient Pressure

HPPS sign

Pressure shown on logger at subsea ambient.



Document No.:

BMIP-BNW-D01938-LA-6180-00129-000

Rev. R01


Document Title:




Valve

Identification Description PID/Drawing




Closed


6.5.92 On reaching ambient pressure, all pressure and temperature charts, plots, calculations and test records are to be signed off by the HPPS Test Engineer and Saipem representatives.

6.5.93 Section (6.5.80 to 5.5.87) shall be repeated for all pipelines to be depressurized.

6.5.94 Whenever the SPHU or Standalone Datalogger is recovered to deck, data for all performed operations shall be downloaded from the data logger onto a laptop by the HPPS engineer/supervisor.

6.5.95 On completion of operation collate paperwork, charts and present to client for acceptance and signature.

6.5.96 Ensure that all paperwork has been completed.


PFL13

PFL14

PFL15

PFL16

WFL04


Document No.:

BMIP-BNW-D01938-LA-6180-00129-000

Rev. R01


Document Title:




6.6 Recovery of SPHU to Deck

6.6.1 This work method comprises steps to be taken when recovering the SPHU to deck as well as prior to conducting a wet transit.

6.6.2 Before operations commence, the HPPS Test Engineer will perform a Toolbox Talk with the HPPS crew and Saipem Rep on the technical and safety aspects of operations, highlighting as a minimum the following topics:

Safety

Incident Reporting Process

Review of generic Risk Assessments (job specific RA’s will be developed if required

Operational pressures

Equipment layout

Duration of operations

Rectification of leaks

Communications

Housekeeping

Impact on other activities

Any questions

6.6.3 Raise Permit for recovery operations.

Name Sign Date

6.6.4 Check communications between ROV Control, Deck foreman and Vessel Bridge. Erect temporary barriers around work sites.

Name Sign Date

HSE

HSE


Document No.:

BMIP-BNW-D01938-LA-6180-00129-000

Rev. R01


Document Title:




6.6.5 Once the pipeline(s) have been depressurised and pressure is confirmed to be at subsea ambient the ROV shall close all the valves on the Abandonment PFTA/WFTA and disconnect the stab and hose assembly.

6.6.6 The hose and stab assembly shall be returned and secured onto the SPHU ready for recovery.

6.6.7 Valves located on the SPHU shall be configured according to the table below. This shall ensure no pressure is trapped in the system during recovery.

Valve




LPV1 Filter Isolation

valve UK-120059-

DR-008 In SPHU Open

HPV1 Line Isolation

valve UK-120059-

DR-008 On top SPHU Open


UK-120059-DR-008

On top SPHU Open

CV01 Chemical

Control valve

UK-120059-DR-008

On Hydrotest Panel

3 Turns Open

CV02 Chemical

Control valve

UK-120059-DR-008

On Hydrotest Panel

3 Turns Open

DV1 Programme

Diverter valve UK-120059-

DR-008 On Hydrotest

Panel Set on

P1

HTV01 Hydrotest

Isolation valve 1 UK-120059-

DR-008 On Hydrotest

Panel ½

Open

HTV02 Hydrotest


DR-008 On Hydrotest

Panel ½

Open

HTV03 Hydrotest

Isolation valve 3

UK-120059-DR-008

On Hydrotest Panel

½ Open

HTV04 Hydrotest


DR-008 On Hydrotest

Panel ½

Open

HTV05 Hydrotest


DR-008 On Hydrotest

Panel ½

Open

VV01 Hydrotest Vent

valve

UK-120059-DR-008

On Hydrotest Panel

3 Turns Open


Document No.:

BMIP-BNW-D01938-LA-6180-00129-000

Rev. R01


Document Title:




6.6.8 The ROV shall inspect the SPHU and ensure that the Coflexip jumper hose is secured and slings are not twisted / snagged prior to connection to the vessel’s crane / winch hook. The HPPS engineer/supervisor shall confirm the unit is ready for recovery.

6.6.9 Lower the crane/winch hook to 5 metres from the seabed using ROV to guide.

6.6.10 ROV to connect hook to master link of the SPHU bridle, paying particular attention to avoid snagging the SPHU framework or panel.

6.6.11 Once the SPHU’s lifting bridle is attached to the hook, the ROV will monitor the unit as it is lifted clear of the seabed.

6.6.12 The SPHU will be recovered to deck following the agreed upon recovery procedure.

6.6.13 Only minimum number of HPPS personnel to be involved with crane lifting. If not required standby at safe distance.

6.6.14 If the SPHU is recovered to deck at any time, the mud mats will be washed down to remove any seabed mud.

Task Pipeline Date Time HPPS sign

Whenever the SPHU is recovered to deck, the unit

will be washed down to remove seabed mud.


WFL04


Document No.:

BMIP-BNW-D01938-LA-6180-00129-000

Rev. R01


Document Title:




Recovery of the Standalone Datalogger

6.6.15 If the Standalone Datalogger is to be recovered to deck, ensure that all valves on the manifold, are open before recovery.

Housekeeping / De-mob

6.6.16 The following steps may be carried out prior to any prolonged dry store of the SPHU or de-mob/backload. HPPS engineer/supervisor has discretion over appropriate actions. Ref. document – Backload check sheet : FO-GL-HAL-PPS-501.

6.6.17 Following approval of Saipem to demob, the SPHU will be prepared for backload.

6.6.18 Remove all electronics and data loggers, flush with fresh water and secure in transit case.

6.6.19 Drain all water / chemical pipework and flush with fresh water. Ensure all valves are half open during and after flushing activities.

6.6.20 Mud mats should be washed down to remove any seabed mud.

6.6.21 Remove hydrotest panel, clean and flush with water.

6.6.22 Uncouple Coflexip hose from SPHU and remove buoyancy modules, flush with fresh water and store in transit boxes.

6.6.23 Flush all used hydrotest hoses with fresh water and store in container.

6.6.24 Empty, flush and store chemical bags in SPHU chemical hold.

6.6.25 Tidy up all SPHU equipment and secure in container for transit.

6.6.26 Lower the crane/winch hook to 5 metres from the seabed using ROV to guide.


Document No.:

BMIP-BNW-D01938-LA-6180-00129-000

Rev. R01


Document Title:




6.7 Calculations Spreadsheets/Results

Date produced: 11-Nov-12

Customer Saipem

Location Bonga Northwest

Pipeline Description: Production Flowline 13 (PFL 13) API-5L-X65 OD:263.1mm Wt:20.64mm x 3.243km

Pipeline Length (km) 3.24 km Outside Diameter (m) 0.263 mInternal Diameter (m) 0.222 m Pipeline Lay UnrestrainedTotal Vol. (imp. gals) 2.76E+04 I.gal Total Volume (m³) 125.3 m³Volume per ft (gals) 2.59 gal Vol. per metre (m³) 0.039 m³Total Volume (ft³) 4.43E+03 ft³ Vol. per metre (ft³) 1.36 ft³

PIGGING PARAMETERS Fill fluid : Water Salinity : 3.5 %

Pig Differential BarPigging Speed (m/s) 0.50 Pump Rate (m³/min) 1.16

Head Loss (metres) 3.48Friction Factor 0.018703922 Reynolds Number 85782

Pressure Drop At Pigging Speed 5.3 psi = 0.37 bar

Chemical Additive Injection Rates

Chemical p.p.m. Injection Rate (litres/min)1 Ihibitor 1000.0 1.1592 Tracer dye 50.0 0.05834

PRESSURE TEST PARAMETERS Test press. 413.0 bar gTemp. 4.0 'C

Volume to pressurise pipeline : 2.510 m³ Corresponding Inlet (0-bar) Volume : 2.555 m³Volume change per bar at test pressure : 5.74 litres

Temp Compressibility Coeff Expan. Pressure changeº C (bar)¯¹ (deg C)¯¹ bar/ºC

4.16E-05 1.83E-04 3.160.7 4.14E-05 1.87E-04 3.251.4 4.13E-05 1.91E-04 3.342.1 4.11E-05 1.94E-04 3.432.8 4.10E-05 1.98E-04 3.523.3 4.09E-05 2.01E-04 3.584.0 4.07E-05 2.04E-04 3.674.0 (Test) 4.07E-05 2.04E-04 3.67

Average pressure change per degree C (bar): 3.42Fraction of external pressure added internally: 0.128


Customer Saipem
















Customer Saipem


Pipeline Description: Water Injection Flowline 04 (WFL 04) API-5L-X65 OD:323.9mm Wt:20.6mm x 4.108km














Document No.:

BMIP-BNW-D01938-LA-6180-00129-000

Rev. R01


Document Title:




6.8 Valve Status Checksheet

Production Flowlines valve status for FCG/Hydrotest/Handover

Note: All valves are ROV operable


Document No.:

BMIP-BNW-D01938-LA-6180-00129-000

Rev. R01


Document Title:




Water Injection Flowlines valve status for FCG/Hydrotest/Handover

Note: All valves are ROV operable

Flowline Characteristics

Production Flowline Characteristics


Document No.:

BMIP-BNW-D01938-LA-6180-00129-000

Rev. R01


Document Title:




Water Injection Flowline Characteristics


Document No.:

BMIP-BNW-D01938-LA-6180-00129-000

Rev. R01


Document Title:




APPENDIX 1 DRAWINGS

Title Drawing Number Sheets Revision

Bonga Northwest Field Layout Fig 1.0 1 0

SPHU Operations Schematic Fig 1.1 1 0

Subsea Datalogger (c/w SPHU Interface) Fig 6.0 1 0

Subsea Datalogger (configured for system depressurisation)

Fig 6.1 1 0

SPHU Equipment Setup without ROV Interface

UK-120059-DR-008 1 0

SPHU Equipment Setup with ROV Interface

UK-120059-DR-009 1 0

Chemical Transfer Equipment set up UK-120059-DR-010 1 0

HARBEN P/P

CHEMICALBAG

HTV-01

HTV-02

HTV-03

HTV-04

HTV-05VV-01

DV-1

CV-02

CV-01

BOOST P/P

DEEPSTAR FEMALERECEPTACLE

HB-1FILTERHPV-01

HPV-02

3/4" HOSE CONNECTION

SPHU

CF-01

CF-02

FILTER

PRV


CHEMICALBAG

LPV-01

FILTERS

INLET

CHEMICALFILL POINTS

OUTLET

HALLIBURTON

0 12-11-12 FIRST ISSUE R.M C.E.

DRAWINGSIZENTS UK-120059-DR-008A3

SPHU EQUIPMENT SETUP WITHOUT ROV INTERFACE

HPU

SUPPLY RETURN CASE

HARBEN P/P

CHEMICALBAG

HTV-01

HTV-02

HTV-03

HTV-04

HTV-05VV-01

DV-1

CV-02

CV-01

BOOST P/P

HYDRAULIC BUNDLE

FLOWMETER

DEEPSTAR FEMALERECEPTACLE

HB-1FILTERHPV-01

HPV-02


SPHU

CF-01

CF-02

FILTER

PRV


CHEMICALBAG

LPV-01

FILTERS

INLET

CHEMICALFILL POINTS

OUTLET

ROV INTERFACE

HALLIBURTON


DRAWINGSIZENTS UK-120059-DR-009

SPHU EQUIPMENT SETUP WITH ROV

INTERFACEA3

I.B.C.TANK

CHEMICALBAG

DIAPHRAGMPUMP

AIR SUPPLY 7 BAR@ 200scfm

FV-01IBC TK.

ISOLATIONV/V

FV-02PUMP

ISOLATIONV/V

CF-01 /CF-02

FILTERS

1/2" B.S.P.HOSE

CROSSOVERFITTING

1/2" PVC CLEARHOSE

SPHU

HALLIBURTON


DRAWINGSIZENTS UK-120059-DR-010

CHEMICAL TRANSFEREQUIPMENT SETUP

A3


Document No.:

BMIP-BNW-D01938-LA-6180-00129-000

Rev. R01


Document Title:




APPENDIX 2 RISK ASSESSMENTS

Title Document Number PPS Manual Handling RA-GL-HAL-PPS-444 Communication RA-GL-HAL-PPS-405 Environment RA-GL-HAL-PPS-406 PPS Rig-Up-Equipment RA-GL-HAL-PPS-407 PPS Rig-Down Equipment & Backload RA-GL-HAL-PPS-408 PPS Hydrotesting RA-GL-HAL-PPS-403 Working At Height RA-GL-HAL-PPS-445 Flooding RA-GL-HAL-PPS-402

RISK ASSESSMENT CARRIED OUT BY: G.Howard DATE: 20/08/09 APPROVED: G. Macnab DATE: 22/08/09

RISK ASSESSMENT Title:

PPS MANUAL HANDLING HALLIBURTON MANAGEMENT SYSTEM

DOCUMENT NUMBER:

RA-UK-HAL-PPS-444 REGION:

Europe West Africa FUNCTION/PSL:

Pipeline & Process Services OWNER:

Iain Shepherd APPROVED BY: Gordon Macnab

REVISION BY: Richard Voisey

REV. DATE: 12th march 2010

REV. NO: 0

PAGE: 1 of 4

RISK ANALYSIS MATRIX

Potential Consequences Probability Rating

Hazard Severity Category

Descriptive Word

Personal Illness/ Injury

Equipment Loss(s)

Environmental (Any incident that…)

A Frequent

B Reasonably

Probable

C Occasional

D Remote

E Extremely

Improbable

F Impossible

1 Catastrophic

Fatal or permanent

disabling injury or illness

>$1,000,000 Potentially harms or adversely affects the general public and has the potential for widespread public concern of Halliburton operations. Can have serious economic liability on the operation.

1 1 1 2 3 3

2 Critical Severe Injury or

illness

$200,000 to

$1,000,000

Potentially harms or adversely affects trained employees and the environment. Requires specialised expertise or resources for correction. 1 1 2 3 3 3

3 Marginal Minor Injury or

Illness

>$10,000 to

$200,000

Presents limited harm to the environment and requires general expertise and resources for correction 2 2 3 3 3 3

4 Negligible No Injury or Illness <$10,000 Presents limited harm to the environment and requires minor corrective actions (CPI). 3 3 3 3 3 3

RISK PRIORITY CODE (RPC)

CODE ACTION REQUIRED

1. HIGH RISK: Imperative to suppress risk to lower level.

2. MEDIUM RISK: Operations may be require waiver endorsed by management.

3. OPERATION PERMISSABLE:

Note: Risk priority code of less than 3 is NOT ACCEPTABLE for hazards that target personnel

PROBABILITY RATING LEVEL DESCRIPTION

A. FREQUENT: Likely to occur repeatedly during activity/operation.

B. REASONABLY PROBABLE: Likely to occur several times.

C. OCCASIONAL: Likely to occur sometime.

D. REMOTE: Not likely but possible. E. EXTREMELY IMPROBABLE:

Probability of occurrence cannot be distinguished from zero.

JOB INFORMATION AND SUPERVISORY COMPLIANCE SIGNATURE

CLIENT JOB DETAILS LOCATION

SUPERVISOR / ENGINEER RESPONSIBLE FOR REVIEWING THE RISK ASSESSMENT WITH HIS CREW

NAME (PRINT) SIGNATURE JOB POSITION DATE

NOTE : The remainder of the HPPS crew should sign the Pipeline or Process Toolbox Talk Checklist FO-UK-HAL-PPS-401/402 to acknowledge that they been involved the risk assessment review of the job.


MANUAL HANDLING HALLIBURTON MANAGEMENT SYSTEM

DOCUMENT NUMBER:






REV. DATE: 12th August 09

REV. NO: 0

PAGE: 2 of 4

Remarks ALL PERSONNEL HAVE THE AUTHORITY AND RESPONSIBILITY TO STOP A JOB IF THEY ARE CONCERNED ABOUT THE SAFETY OF THE OPERATION.

T A R G E T

INITIAL RISK

RISK REDUCTION CONTROL MEASURES RESIDUAL RISK

S E V E R I T Y

P R O B A B I L I T Y

R P C

Note 1: Personnel need to be aware of, & take precautions against, the following

hazards which may be applicable to all steps of the task. Manual Handling / Slips & Trips / Pinch Points

Note 2: Personnel need to wear the appropriate PPE for the task at all times

Note 3: All relevant permits to be in place prior to an operation commencing.

Note 4: Where applicable hold a Toolbox Talk and produce a Lift Plan.

S E V E R I T Y


R P C

A C C E P T A B L E

TASK HAZARD HAZARD EFFECT

TARGETS: P – PEOPLE E – EQUIPMENT ENV – ENVIRONMENTAL DT – DOWNTIME M – MATERIALS

RISK ASSESSMENT CARRIED OUT BY: R. Voisey & J. Page DATE: 12/03/2010 APPROVED: G. Macnab DATE: 15/03/2010

Manual handling

• Slippery or uneven ground • Improper use of lift equip. or

component failure (i.e. slings) • Insufficient Training • Moving equipment/loads • Poor communication • Weather / poor visibility

• Bodily injury P III B 2 • Use proper lifting techniques or equipment • Obtain assistance as required • Appropriate training, authorized personnel only • Be aware of shifting load • Clear area of personnel not required • Communicate instructions clearly to all involved and during job (radios, hand

signals) • Use designated banksman

Use Taglines

III C 3

III C 3 • Equipment damage

E III B 2

Pinch Points

• Hammers • Equipment moves • Truck Tool Boxes • Discharge line/Pump

• Bodily injury P III B 2

• PPE • Proper Body Position • Create a Safe Work Area • Use Appropriate Tools for the job • Use Tools Properly • UtiliseTag Lines • Inspect Tools on a regular basis • Don't rush lifting operations

III C 3

Pulling /Pushing

• Moving Hoses • Uncentered Lifts


• Proper Techniques • Refuse Unsafe Work • Use More People where possible • Balance the loads • Use Tag/Securing lines

III C 3



DOCUMENT NUMBER:







REV. NO: 0

PAGE: 3 of 4


T A R G E T

INITIAL RISK


S E V E R I T Y


R P C






S E V E R I T Y


R P C

A C C E P T A B L E




Congested Area

• Poor Rig Up/Down • Space Constraints • Multi • Site Traffic • Vehicular • People

• Bodily injury P III B 2 • Plans/Schedules for the FPSO PTW system • Signage/Awareness • Effective Communication

Remove all unnecessary equipment from area

III C 3

• Equipment damage E III B 2 III C 3

Lighting • None • Little

• Bodily injury P III B 2 • Provide Light in the right places

III C 3

• Equipment damage E III B 2 III C 3

Improper spotting

of equipment / materials

• Poor weather conditions • Human error • Poor communication • Poor visibility


• Where possible plan laydown of equipment prior to lifting ops being undertaken, walk around equipment to determine hazards.

• Discuss spotting of equipment in ToolboxTalk

II D 3

• Equipment damage E III B 2 II D 3

• Environmental ENV

II C 2 II D 3



DOCUMENT NUMBER:







REV. NO: 0

PAGE: 4 of 4


T A R G E T

INITIAL RISK


S E V E R I T Y


R P C






S E V E R I T Y


R P C

A C C E P T A B L E




Contact of hot/cold surfaces

• Running of pumps • Elevated temperatures

• Bodily injury P III B 2 • Protect exposed skin (e.g.. gloves, coveralls) III C 3

Flying objects Projectiles

• Tools • Foreign objects (i.e. metal

shards) Dropped objects

• Bodily injury P II C 2

• Watch line of fire • Ensure face & eye protection is worn

II D 3

E II C 2 II D 3

Hand tools • Improper handling of tools • Bodily injury P III B 2 • Protect exposed skin (i.e. gloves) • Use tools appropriate to the job • Job specific training

III C 3

Heat stress • Over exertion/fatigue • Bodily injury P III B 2 • Provide sufficient fluids/Breaks as needed III C 3

Title:

PIPELINE – COMMUNICATIONHALLIBURTON MANAGEMENT SYSTEM

DOCUMENT NUMBER:

RA-GL-HAL-PPS-405 REGION:

Global FUNCTION/PSL:


B&C HMS Coordinator APPROVED BY: Steve Arrington

REVISION BY: Malcolm MacMillan

REV. DATE: 01.SEPT.2011

REV. NO: 1.0

PAGE: 1 of 3




Descriptive Word


Equipment Loss(s)


A Frequent

BReasonably

Probable

C Occasional

D Remote

EExtremely

Improbable

F Impossible

1 Catastrophic

Fatal or permanent disabling injury or illness

> $1,000,000

Potentially harms or adversely affects the general public and has the potential for widespread public concern of Halliburton operations. Can have serious economic liability on the operation.

1 1 1 2 3 3

2 Critical Severe Injury or illness

$200,000 to

$1,000,000

Potentially harms or adversely affects trained employees and the environment. Requires specialised expertise or resources for correction.

1 1 2 3 3 3

3 Marginal Minor Injury

or Illness

>$10,000 to

$200,000

Presents limited harm to the environment and requires general expertise and resources for correction

2 2 3 3 3 3

4 Negligible No Injury or

Illness <$10,000

Presents limited harm to the environment and requires minor corrective actions (CPI).

3 3 3 3 3 3


CODE ACTION REQUIRED 1. HIGH RISK: Imperative to

suppress risk to lower level. 2. MEDIUM RISK: Operations may

be require waiver endorsed by management.

3. OPERATION PERMISSABLE: Note: Risk priority code of less than 3 is NOT ACCEPTABLE for hazards that target personnel

PROBABILITY RATING

LEVEL DESCRIPTION A. FREQUENT: Likely to occur

repeatedly during activity/operation. B. REASONABLY PROBABLE:

Likely to occur several times. C. OCCASIONAL: Likely to occur

sometime. D. REMOTE: Not likely but possible. E. EXTREMELY IMPROBABLE:






NOTE : The remainder of the HPPS crew should sign the Pipeline Toolbox Talk Checklist FO-UK-HAL-PPS-401 to acknowledge that they been involved the risk assessment review of the job.



DOCUMENT NUMBER:






REV. DATE: 01.09.11

REV. NO: 0

PAGE: 2 of 3


T A R G E T

INITIAL RISK


S E V E R I T Y


R P C

Note 1: Personnel need to be aware of, & take precautions against, the

following hazards which may be applicable to all steps of the task. Manual Handling / Slips & Trips / Pinch Points Note 2: Personnel need to wear the appropriate PPE for the task at all times Note 3: All relevant permits to be in place prior to an operation commencing. Note 4: Where applicable hold a Toolbox Talk and produce a Lift Plan.

S E V E R I T Y


R P C

A C C E P T A B L E


Communicate all aspects of project/job to

relevant personnel

Personnel not

informed. Lack of

understanding. Misinterpretation of

instruction Ignoring or unaware

of existing procedures.

Lack of cross project briefing.

Radio failure Lack of experience

Personal injury. Damage to plant and /

or equipment. Project impact –

delays -work quality affected.

P E Env DT

II C 2

Permit to work system. Toolbox talks. Written briefing at shift change. Suitable hand over period Planning and schedule meetings. Procedures. Feedback and reporting, (HOC/CPI) Site safety meetings. Supervisory control and awareness. Contractor control. Reporting system for infringements.(HOC) Back up radio and batteries. Pre-job briefing/Post-job review

II

D

3

Damage to environment



DOCUMENT NUMBER:






REV. DATE: 01.09.11

REV. NO: 0

PAGE: 3 of 3


T A R G E T

INITIAL RISK


S E V E R I T Y


R P C



S E V E R I T Y


R P C

A C C E P T A B L E


REVIEW THE RISK ASSESSMENT AND IDENTIFY ANY ADDITIONAL HAZARDS & CONTROL MEASURES IN THIS SECTION FOR THE SPECIFIC TASK TO BE CARRIED OUT. THE HAZARD CHECKLIST BELOW CAN BE USED AS A PROMPT.

HAZARD CHECKLIST 1. CHEMICALS 5. CONFINED SPACES 9. SLIPS, TRIPS, FALLS 13. MECHANICAL LIFTING 17. STORED ENERGY 21. LIGHTING 25. RADIATION 2. ASPHYXIANTS 6. EXCAVATIONS 10. MANUAL HANDLING 14. OPERATION OF VEHICLES 18. IGNITION SOURCES 22. HOT/COLD SURFACE 26. SIMOPS 3. DROWNING 7. HEIGHT 11. INCORRECT POSTURE 15. HAND TOOLS 19. EXPLOSION 23. NOISE 27. WEATHER 4. BIOLOGICAL AGENTS 8. DROPPED OBJECTS 12. USE OF EQUIPMENT 16. PRESSURE 20. ELECTRICITY 24. VIBRATION 28. RELEASE TO ENVIRONMENT

RISK ASSESSMENT

Title:

PIPELINE – ENVIRONMENTHALLIBURTON MANAGEMENT SYSTEM

DOCUMENT NUMBER:







REV. NO: 1.0

PAGE: 1 of 3




Descriptive Word


Equipment Loss(s)


A Frequent

BReasonably

Probable

C Occasional

D Remote

EExtremely

Improbable

F Impossible

1 Catastrophic


>$1,000,000


1 1 1 2 3 3

2 Critical Severe Injury or illness

$200,000 to

$1,000,000


1 1 2 3 3 3

3 Marginal Minor Injury

or Illness

>$10,000 to

$200,000


2 2 3 3 3 3

4 Negligible No Injury or

Illness <$10,000


3 3 3 3 3 3






PROBABILITY RATING











Title:


DOCUMENT NUMBER:







REV. NO: 1.0

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T A R G E T

INITIAL RISK


S E V E R I T Y


R P C



S E V E R I T Y


R P C

A C C E P T A B L E TASK HAZARD

HAZARD EFFECT

ENVIRONMENTAL ASPECT & IMPACT


Environmental precautions

Over filling of fuel

tanks, drums and containers/tanks.

Leaking fuel pipes. Damaged hoses Spill of chemicals Fuel tank split

Personal injury Chemical burns

P Env DT

II

C

2

Level indicators on fuel tanks. Auto cut off fuel filling nozzle. Vigilance during filling operations. Regular maintenance/ inspection of fuel lines. Install bunding/drip trays where required. Pre-start checks. Spill kits Appropriate PPE. Barrier creams to be available. Emergency shower. COSHH & MSDS available for precautionary measures to be taken. Spillages to be cleaned up immediately. Use of PON 15 C complaint chemicals used.

II

D

3

Damage to environment. (unintended discharge to ground or sea)

Title:


DOCUMENT NUMBER:







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HAZARD EFFECT





Title:

PIPELINE – RIG-UP EQUIPMENTHALLIBURTON MANAGEMENT SYSTEM

DOCUMENT NUMBER:







REV. NO: 1.0

PAGE: 1 of 5




Descriptive Word


Equipment Loss(s)


A Frequent

B Reasonably

Probable

C Occasional

D Remote

E Extremely

Improbable

F Impossible

I Catastrophic


> $1,000,000


1 1 1 2 3 3

II Critical Severe Injury or illness

$200,000 to

$1,000,000


1 1 2 3 3 3

III Marginal Minor Injury

or Illness

>$10,000 to

$200,000


2 2 3 3 3 3

IV Negligible No Injury or

Illness <$10,000


3 3 3 3 3 3






PROBABILITY RATING


repeatedly during activity/operation. B. REASONABLY PROBABLE: Likely

to occur several times. C. OCCASIONAL: Likely to occur








RISK ASSESSMENT

Title:

PIPELINE – RIG-UP EQUIPMENT HALLIBURTON MANAGEMENT SYSTEM

DOCUMENT NUMBER:

RA-GL -HAL-PPS-407 REGION:


Pipeline & Process Services

OWNER: B&C HMS Coordinator

APPROVED BY: Steve Arrington



REV. NO: 1.0

PAGE: 2 of 4


T A R G E T

INITIAL RISK


S E V E R I T Y


R P C



S E V E R I T Y


R P C


HAZARD EFFECT



Spotting equipment

Crane operations Movement of heavy

loads Dropped objects Failure of lifting

equipment. Exceeding deck

loading.

Personal injury Damage to plant and

equipment Damage to deck

structure.

P E Env DT

I D 2 Toolbox Talk involving all interested parties, PPS Supv to provide lay

down plan. PTW/ISSOW to be in place as required Obey instructions of deck crew. Non-essential personnel to stay clear of area. Only qualified banks-man to control all lifting operations. Avoid standing or working under suspended loads. Use only certified lifting equipment. Tag lines to be used(There may be local rules preventing this) Check with barge engineer or equivalent, for deck loading (if not already

known) Spill kits available.

I E 3

Chemical Tank splits after dropping

Rigging up hoses and

Iron

Manual handling

injuries, slipping / tripping.

Pinch points. Incompatible

connections made up.

Damaging fittings (over tightening)

Damage to threads and creation of burrs

Personal injury, Damage to fittings. Leaking unions (loss

of containment) Hand injuries due to

burred and sharp threads / surfaces.

P E Env DT

II

C

2

Only personnel trained in manual handling to carry out lifting operations. If the operation involves a significant risk of injury, carry out a Manual

Handling Assessment Address slipping/ tripping hazards, highlight those that cannot be removed

with barrier tape. Personnel to have undergone fittings training. Use of mechanical aids for tightening iron unions. Inspect thread for burrs before applying thread tape or sealant. Clean up

or discard damaged threads. Use sealant brush/applicator; avoid using fingers in direct contact with threads.

II

D

3

RISK ASSESSMENT

Title:


DOCUMENT NUMBER:








REV. NO: 1.0

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INITIAL RISK


S E V E R I T Y


R P C



S E V E R I T Y


R P C


HAZARD EFFECT



on thread Incorrect use of

fittings Hammer injuries

Use correct PPE including suitable gloves.

Function test equipment

Component failure Fuel/ Oil leaks Fitting damage during

assembly, Environmental impact Over-pressurisation

Personal injury Chemical spills Damage to plant and

equipment

P E Env DT

II

C

2

Check PUWER assessment Only certified equipment to be used. Relief Valve to be fitted to all systems All pressure lines to be properly secured. PA announcement. Warning signs and barriers to ensure safe working zone. Fluid spills to be cleaned up immediately using available spill kit Connect to platform ESD system.

II

D

3

Contamination of the ground or sea

RISK ASSESSMENT

Title:


DOCUMENT NUMBER:








REV. NO: 1.0

PAGE: 4 of 4


T A R G E T

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S E V E R I T Y


R P C


HAZARD EFFECT





RISK ASSESSMENT

Title:

PIPELINE – RIG-DOWN EQUIPMENT & BACKLOADHALLIBURTON MANAGEMENT SYSTEM

DOCUMENT NUMBER:







REV. NO: 1.0

PAGE: 1 of 3




Descriptive Word


Equipment Loss(s)


A Frequent

BReasonably

Probable

C Occasional

D Remote

EExtremely

Improbable

F Impossible

I Catastrophic


> $1,000,000


1 1 1 2 3 3


$200,000 to

$1,000,000


1 1 2 3 3 3


or Illness

>$10,000 to

$200,000


2 2 3 3 3 3


Illness <$10,000


3 3 3 3 3 3






PROBABILITY RATING











RISK ASSESSMENT

Title:


DOCUMENT NUMBER:







REV. NO: 1.0

PAGE: 2 of 3


T A R G E T

INITIAL RISK


S E V E R I T Y


R P C



S E V E R I T Y


R P C


HAZARD EFFECT



Rig down pumps and

hoses

Manual handling

injuries, slipping / tripping.

Chemical fluids present in hoses.

Dropped objects Trapped pressure

Personal injury Container

contamination

P E Env DT

II

C

2

Conduct a TBT, involving all affected personnel, include members of the deck crew and crane operator if applicable

Flush through all equipment prior to rigging down. Special care when flushing chemical injection hoses and pumps Carry out a Manual Handling Assessment Confirm system is at ambient pressure before breaking lines. Address slipping/ tripping hazards, highlight those that cannot be removed

with barrier tape. Use of correct hand tools refer to MSDS and COSHH sheets Have suitable absorbent materials available in the event of a spill HES Supervisor to report the existence of chemicals or residues to the

appointed logistics coordinator, or to contact HES Logistics if this facility is unavailable

HES Supervisor to ensure all necessary markings are clearly and appropriately visible on the backload.

II

D

3

Environmental impact – contamination of ground or sea

Backload equipment

Crane operations,

movement of heavy loads.

Dropped objects. Failure of lifting

equipment. Failure to identify

Personal injury. Damage to plant and

equipment Cross contamination

of chemicals Chemical spills in

containers.

P E Env DT

I C I Obey instructions of deck crew. Non-essential personnel to stay clear of area. Only qualified banks-man to control all lifting operations. Avoid standing or working under suspended loads. Use only certified lifting equipment. Tag lines to be used Complete backload manifest

I E 3

RISK ASSESSMENT

Title:


DOCUMENT NUMBER:







REV. NO: 1.0

PAGE: 3 of 3


T A R G E T

INITIAL RISK


S E V E R I T Y


R P C



S E V E R I T Y


R P C


HAZARD EFFECT



hazardous material Movement of objects

inside container.

Potential spillage to ground or sea.

Dangerous goods information should be passed on to store man/or designated person.

Secure equipment in containers Secure cargo net in containers



RISK ASSESSMENT REVIEW CARRIED OUT BY: A Clunie, D Wood, T Connolly, E Emea, J Lee, M Holmes, I Obott. DATE: 01/06/12

RISK ASSESSMENT

Title:

PIPELINE SPU – (SPHU Pipeline Hydrotest)HALLIBURTON MANAGEMENT SYSTEM

DOCUMENT NUMBER:




Douglas Wood APPROVED BY:

Alan Clunie REVISION BY:

ID Obott REV. DATE: 1st June 2012

REV. NO: 01

PAGE: 1 of 4




Descriptive Word


Equipment Loss(s)


A Frequent

B Reasonably

Probable

C Occasional

D Remote

E Extremely

Improbable

F Impossible

I Catastrophic

Fatal or permanent



1 1 1 2 3 3

II Critical Severe Injury or

illness

$200,000 to

$1,000,000


III Marginal Minor Injury or

Illness

>$10,000 to

$200,000


IV Negligible No Injury or Illness <$10,000 Presents limited harm to the environment and requires minor corrective actions (CPI). 3 3 3 3 3 3

RISK PRIORITY CODE (RPC) CODE ACTION REQUIRED


















DOCUMENT NUMBER:







REV. NO: 01

PAGE: 2 of 4


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INITIAL RISK


S E V E R I T Y


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S E V E R I T Y


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A C C E P T A B L E

TASK HAZARD

HAZARD EFFECT




Pre

ss

uri

sati

on

Over-pressurisation. Component /

Equipment failure. Hydraulic oil leaks.

Damage to plant and equipment.

SPHU recovery for unscheduled maintenance.

E

Env

DT

I

D

2

Hold comprehensive Tool Box Talk involving all parties. ROV personnel aware of connection and pressurising procedure. Appropriate pressure relief Valves to be fitted on system. Strict adherence to relevant job procedures.

I

E

3



DOCUMENT NUMBER:







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T A R G E T

INITIAL RISK


S E V E R I T Y


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S E V E R I T Y


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A C C E P T A B L E

TASK HAZARD

HAZARD EFFECT




Dep

res

su

ris

atio

n

Uncontrolled depressurisation.

Component / Equipment failure

Damage to asset. SPHU recovery for

unscheduled maintenance.

E

DT

I

D

2

Controlled venting Strict adherence to relevant Job procedures.

I

E

3



DOCUMENT NUMBER:







REV. NO: 01

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A C C E P T A B L E

TASK HAZARD

HAZARD EFFECT






RISK ASSESSMENTTitle:

PIPELINE – WORKING AT HEIGHTHALLIBURTON MANAGEMENT SYSTEM

DOCUMENT NUMBER:







REV.NO: 1.0

PAGE: 1 of 3




Descriptive Word


Equipment Loss(s)


A Frequent

B Reasonably

Probable

C Occasional

D Remote

E Extremely

Improbable

F Impossible

I Catastrophic


>$1,000,000


1 1 1 2 3 3


$200,000 to

$1,000,000


1 1 2 3 3 3


or Illness

>$10,000 to

$200,000


2 2 3 3 3 3


Illness <$10,000


3 3 3 3 3 3






PROBABILITY RATING











RISK ASSESSMENT

Title:


DOCUMENT NUMBER:







REV. NO: 1.0

PAGE: 2 of 3


T A R G E T

INITIAL RISK


S E V E R I T Y


R P C



S E V E R I T Y


R P C


HAZARD EFFECT



Climbing to height

Falls from height Dropped objects


equipment

P E DT

I C 1 Three points of contact to be maintained whilst climbing to height whether ladder, stairways or other means of access

No personnel to stand below a climbing colleague All tools to be tied off at all times with correct lanyards and securely

stowed whilst climbing to height Slipping/tripping hazards to be addressed; highlight those that cannot be

removed with barrier tape Non-essential personnel to stay clear of the area

I E 3

Working at Height

Falls from height Slipping / tripping Dropped objects


equipment

P E DT

I

C

1

Appropriate safety harness worn when working at height Scaffolding to be used when required No personnel to stand below a colleague working at height All tools to be tied off at all times with correct lanyards and securely

stowed whilst working at height Tools not be left on the walking surface whilst working Slipping/tripping hazards to be addressed; highlight those that cannot be

removed with barrier tape Non-essential personnel to stay clear of the area

I

E

3


RISK ASSESSMENT

Title:

PIPELINE SPU – (SPHU Pipeline Flooding)HALLIBURTON MANAGEMENT SYSTEM

DOCUMENT NUMBER:







REV. NO: 01

PAGE: 1 of 4




Descriptive Word


Equipment Loss(s)


A Frequent

B Reasonably

Probable

C Occasional

D Remote

E Extremely

Improbable

F Impossible

I Catastrophic

Fatal or permanent



1 1 1 2 3 3


illness

$200,000 to

$1,000,000



Illness

>$10,000 to

$200,000





















DOCUMENT NUMBER:







REV. NO: 01

PAGE: 2 of 4


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INITIAL RISK


S E V E R I T Y


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S E V E R I T Y


R P C

A C C E P T A B L E

TASK HAZARD

HAZARD EFFECT




Flo

od

ing

/Pig

gin

g O

pe

rati

on

Equipment / component

failure.

Unplanned recovery for

maintenance. Reduced power supply to

unit. Non Productive Time.

E

ENV

DT

II

D

3

Hold comprehensive Tool-Box Talks involving all parties. Ensure valves checklist is followed diligently. Ensure controlled valve operation. Adherence to relevant Job Procedures. Monitor readings and discharge where possible. If the SPHU recovery for maintenance purposes is imminent, have all equipment and

spares prepared topside on deck, to reduce downtime to a minimum.

II

E

3



DOCUMENT NUMBER:







REV. NO: 01

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INITIAL RISK


S E V E R I T Y


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S E V E R I T Y


R P C

A C C E P T A B L E

TASK HAZARD

HAZARD EFFECT




Ch

em

ica

l In

ject

ion

Equipment / Component

failure

SPHU recovery for

unscheduled chemical loop maintenance.

E

ENV

DT

II

C

2

Monitoring of instrumentation. Adherence to relevant job procedures.

II

D

3

Unplanned release of

chemical to the environment.



DOCUMENT NUMBER:







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S E V E R I T Y


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TASK HAZARD

HAZARD EFFECT







RISK ASSESSMENT

Title:

PIPELINE SPU – (SPHU Pre-mobilisation & Pre-Deployment)HALLIBURTON MANAGEMENT SYSTEM

DOCUMENT NUMBER:







REV. NO: 01

PAGE: 1 of 6




Descriptive Word


Equipment Loss(s)


A Frequent

B Reasonably

Probable

C Occasional

D Remote

E Extremely

Improbable

F Impossible

I Catastrophic

Fatal or permanent



1 1 1 2 3 3


illness

$200,000 to

$1,000,000



Illness

>$10,000 to

$200,000




















PIPELINE SPU – (SPHU Pre-mobilisation & SPHU Pre-Deployment)HALLIBURTON MANAGEMENT SYSTEM

DOCUMENT NUMBER:







REV. NO: 01

PAGE: 2 of 6


T A R G E T

INITIAL RISK


S E V E R I T Y


R P C






S E V E R I T Y


R P C

A C C E P T A B L E

TASK HAZARD

HAZARD EFFECT




Ass

em

bly

& D

isas

sem

bly

of

SP

HU

un

it

(ons

ho

re a

sse

ssm

ent

)

Crushing Manual Handling Injuries Slips and trips Incorrect Use of Tools Dropped objects Lifting Equipment Failure Crane Operations Fall from height Fittings damage Chemical Spills

Entrapment/Loss of Limb Personnel Injury Damage to plant and

Equipment Component damage

during assembly

P

E

DT

ENV

I

C

2

PTW obtained and valid for task - should take into consideration Area Environment

Plan (drainage & spills). Rig-up Unit / spread in approved area. Tool Box Talks with all parties involved to increase awareness of operation - take into

consideration weather conditions and ensure adherence to LOLER. Address slipping/tripping hazards and highlight those that cannot be removed with

barrier tape. Awareness of Manual Handling Procedures. Competent personnel involved in operations – Banks Man to control lifting operations. Assess task before awkward lifts. Ensure personnel involved in the task are aware and trained/instructed in the use of

any lifting accessories used during the SPHU assembly. Correct assembly of Unit / spread, using only certified lifting equipment and

accessories. Awareness of Coflexip hose or loading arm rig up and rig down procedure. Correct safety harness should be worn and used by trained personnel when working at

height. Tag lines to be used where needed. Never stand or work under suspended loads. Non-essential personnel to the operation to stay clear during lifts. Spill kits to be made available and used when disconnecting/disassembling

components of unit / spread.

I

D

3

Environmental impact / contamination from spills.



DOCUMENT NUMBER:







REV. NO: 01

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T A R G E T

INITIAL RISK


S E V E R I T Y


R P C






S E V E R I T Y


R P C

A C C E P T A B L E

TASK HAZARD

HAZARD EFFECT




Ins

pe

ctio

n a

nd

fu

nc

tio

n t

es

t o

f eq

uip

me

nt

(o

nsh

ore

ass

ess

me

nt)

Component failure. Fuel/Oil leaks. Operator error. Uncontrolled pressure

release. Over-pressurisation. Electric shock. Noise.

Personal Injury. Damage to Plant and

Equipment.

P

E

ENV

DT

II

C

2

PTW obtained and valid for task - should take into consideration Area Environment

Plan (drainage & spills). Tool box talk with all parties to ensure awareness of task - take into consideration

weather conditions. Check PUWER assessment - Equipment used should be certified and checked for

general condition and suitability before use. Hoses and fittings in use should be properly connected and rated beyond pumping

pressure. Ensure relief valves are correctly rated, set and fitted as well as included in test loop. Inspect system and ensure use of appropriately rated fittings / electric connections. Ensure correct orientation of NRV’s and flowmeters on unit / test spread. Personnel trained and competent in use of tools and operation of equipment. Use of whip checks, to secure hoses and iron. Warning signs and barriers should be erected to ensure safe working zone. PA announcement of impending operations. Use of drip trays/mats, deployed at connection points. Fluid spills to be cleaned up ASAP using available spill kit. Controlled valve operation. Follow project specific procedure.

II

D

3

Environmental impact /

contamination from spills.



DOCUMENT NUMBER:







REV. NO: 01

PAGE: 4 of 6


T A R G E T

INITIAL RISK


S E V E R I T Y


R P C






S E V E R I T Y


R P C

A C C E P T A B L E

TASK HAZARD

HAZARD EFFECT




Ch

emic

al b

ag

fill

ing

(o

nsh

ore

ass

essm

ent

)

Equipment failure. Chemical spillage. Chemical contact,

inhalation and ingestion.

Personnel injury.

P

E

ENV

DT

I

C

1

PTW obtained and valid for task - should take into consideration Area Environment Plan (drainage & spills).

Tool box talk to ensure awareness of task. MSDS and or COSHH assessment available on site and copies with medic / area

authority. Ensure operations work area is well ventilated and tidy. Be aware of unventilated areas that might collect pockets of chemical fumes. Equipment used should be certified and checked for general condition and suitability

before use. Hoses and fittings in use should be properly connected and rated beyond pumping

pressure. Transfer rig up to be tested with water prior to use and inspected for leaks during

operations. Competent personnel involved in task. Task specific PPE - Chemical suits, gloves and goggles/face visor along with minimum

PPE to be used during operations. Awareness of Chemical transfer procedure. Work area to be cordoned-off with signs erected; Non-essential personnel to stay clear

of the area during operation. PA informing of impending operations. Chemical spill kit to be made available in close proximity to work location. Wash out equipment on completion of transfer. Do not eat, drink or smoke in vicinity of task. Wash hands after task. Shower and eye wash station to be made available and known to all personnel - it

must be in good working condition. If no shower available, then charged water hose will suffice.

III

E

3

Environmental impact / contamination from spills.



DOCUMENT NUMBER:







REV. NO: 01

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INITIAL RISK


S E V E R I T Y


R P C






S E V E R I T Y


R P C

A C C E P T A B L E

TASK HAZARD

HAZARD EFFECT




Pre

par

ati

on

of

SP

HU

fo

r d

ep

loy

me

nt

(on

sho

re a

sse

ssm

ent)

Fall from height. Dropped object. Operator error.

Severe injury. Fatality. Damage to equipment.

P

E

DT

I

D

2

Keep tools and equipment fastened or well away from edges. Be aware of others working in the immediate vicinity. Signs and barriers to be erected to prevent unauthorised access to all relevant

immediate and adjacent work areas. Good housekeeping standards to be maintained on work-site at all times. Safety harness should be worn and used when working at height. Competent personnel to be involved in task. Follow project specific procedure and pre-deployment checklists.

III

E

3



DOCUMENT NUMBER:







REV. NO: 01

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INITIAL RISK


S E V E R I T Y


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S E V E R I T Y


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A C C E P T A B L E

TASK HAZARD

HAZARD EFFECT






RISK ASSESSMENT

Title:


DOCUMENT NUMBER:







REV. NO: 1.0

PAGE: 3 of 3


T A R G E T

INITIAL RISK


S E V E R I T Y


R P C



S E V E R I T Y


R P C


HAZARD EFFECT






Document No.:

BMIP-BNW-D01938-LA-6180-00129-000

Rev. R01


Document Title:




APPENDIX 3 FIELD REPORT FORMS

Title Number PPS Tool Box Talk Checklist FO-GL-HAL-PPS-403 Site Pre Job Briefing FO-GL-HAL-PPS-402 Subsea Pigging Unit Fill report & Chemical Dosing FO-GL-HAL-PPS-423 PPS Operations Log FO-GL-HAL-PPS-401 Function Test Acceptance Certificate FO-GL-HAL-PPS-604 Change control form FO-GL-HAL-PPS-115 Pre-deployment Checklist FO-GL-HAL-PPS-422 Pipeline Pig/Flushing Report FO-GL-HAL-PPS-425 Pipeline Pressurisation Report FO-GL-HAL-PPS-426 Pipeline Test Report FO-GL-HAL-PPS-427 Pipeline Air-Inclusion Report FO-GL-HAL-PPS-428 Pipeline Acceptance Certificate FO-GL-HAL-PPS-429 Pig launch/Receive Register FO-GL-HAL-PPS-430 Backload Check Sheet FO-GL-HAL-PPS-501

FORM

Title: Toolbox Talk Checklist

Halliburton Management System Document Number:

FO-GL-HAL-PPS-403

Region: Global

Function/PSL: Pipeline and Process Services

Owner: Global PE HMS Coord

Approved By: Steve Arrington

Job Revision By: Amy Edwards

Rev Date: 16.Dec.2008

Rev No: 1.0

Page: 1 of 1

Once printed this form is uncontrolled, refer to HMS for controlled copy

Tool Box Talk Checklist

Client: Sales Order: Date:

Project: Location: Index:

Operation:

Preparation Discussed (initial)

1. Establish that all of the equipment, materials, MSDS and COSHH assessments required to complete the job are available.

2. Confirm that the tools & equipment checks have been completed and they are fit for purpose.

3. Discuss in detail the segment of work to be undertaken and any precautions or PTW that will be necessary. Discuss the details of the DOS and any other relevant established procedures.

4. Check permit is valid (if applicable) and endorsed. Discuss the conditions imposed & any safety equipment required. Encourage ALL Performing Authorities to read the permit.

5. Discuss any JSAs that have been completed for the work in hand and any COSHH issues from the MSDS sheets. JSA Nos………………………………………………………………

6. Confirm and discuss other concurrent operation that could impact in our work area.

7. Discuss and confirm individual responsibilities.

8. Confirm primary and secondary access & egress methods and discuss emergency contingency actions.

9. Review that equipment, hoses & lines are installed tidily, correctly secured and do not impair access, egress, lighting. or detection systems.

10. Confirm that the work site is clean and tidy, during and after the work, the PA & Phones are working and can be heard and any lighting is adequate.

11. Confirm that good housekeeping will be maintained at the work site.

12. Ensure personnel have all the correct protective equipment and that it is serviceable.

13. Establish and discuss emergency response actions and methods of communication, radio, emergency phone no…………….., PA………………,Medic……………..

14. Check and confirm that the correct certification is in place as necessary to complete the job -load test, pressure test, IS etc.

15. Discuss any Barriers erected or safety feature lockouts in place and the actions necessary to maintain a safe work area.

16. Discuss the actions required following a platform Emergency Shutdown.

17 Discuss the equipment safety features and the actions necessary to implement an Emergency Shutdown.

18 Where appropriate discuss the operational checklist and pending weather conditions

19 Confirm that stored chemicals have suitable containment bunds, drip trays, spill kits and environmentally friendly drainage.

20 Communications – Ensure effective communications are maintained at all times, and that all communicated commands are confirmed.

Comments:

List of Attendees confirming Tool Box Talk was given and understood: Print Signature Print Signature Print Signature Print Signature 1 2 3 4

5 6 7 8

9 10 11 12

Chairperson Print: Chairperson Signature:

FORM

Title: Site Pre-Job Briefing Checklist


FO-GL-HAL-PPS-402 Region: Global





Rev Date: 22/12/08

Rev No: 1

Page: 1 of 4


The On Site Pre- job Briefing to the Crew should be given in the absence of an office Pre- Job Briefing. Typically the Supervisor would give a briefing prior to Rigging-up, prior to using the equipment to deliver the service and prior to rigging-down. For specific job tasks the Toolbox Talk Checklist would be used.

1. Location Information.

Date : Customer : Location: Sales order No:

Employees attending the Briefing Supervisor:-

2. Work Programme and Procedures

� Review the overall programme and objectives giving detail to the current work phase. Set and agree, with the crew, the job milestones to be reported daily.

� Review the JSAs completed for the current phase of the work and the need to create specific onsite JSA’s for non standard operations. Blank JSA forms w/instructions available in job pack.

� Review other platform operations that may impact on our work or require us to adopt additional control measures.

� Review the Clients objectives and expectations from the work that we are to complete.

� Review the business drivers from our contract with the Client i.e. how we make money, how we can be penalised, how we can be rewarded etc.

� Review and enhance our “Emergency Preparedness Plan”

� Discuss any Safety issues and refer suitable installation issues to the next platform safety meeting. Discuss any CPIs raised.

� Discuss the job documentation required and allocate the responsibilities for providing the necessary information. i.e.EJCS/KPI, job log, status report, skid reports, material reports, etc.

FORM








Rev Date: 22/12/08

Rev No: 1

Page: 2 of 4


3. Emergency Procedures and Essential Information.

� Communications. Provide instruction in normal and emergency communications methods. I.e. Radios, Telephone, P.A., Runners etc.

� Installation Emergencies. Discuss the ESD interfaces, manual actions required and loss of installation services

� Spill control. Discuss measures used for containing spills and the type of drain system at the work-site. I.e. Open, closed or direct to sea.

� Emergency shut down procedures. Discuss when, how, and what to shut down in the event of an emergency.

� Head count. How to establish where on shift employees are located. Establish a "Reporting In" procedure for those on shift during an emergency.

� Recovery procedures. Discuss how to return to normal operating procedures after an emergency.

� Chemicals. Discuss harmful substances on the job site (e.g. H2S, flammable gases, drilling fluids, chemical additives, well bore fluids, LSA scale). Use the MSDS sheets when necessary. Ensure that the Medic is aware of any toxic chemicals we may have.

� Overhead. Discuss overhead hazards (e.g. guy wires, hazards while on the rig floor or under the rig floor, remove any potential dropped objects. Also consider the safeguards required to protect others working below.

4. Identified Hazards.

� Lifting. Discuss proper lifting techniques and ways to eliminate or reduce heavy lifting such as forklifts, cranes, and sharing the load.

� Pressure. Discuss pressure hazards such as DME (discharge manifold equipment)bulk tanks and high pressure jetting equipment.

� Noise. Discuss noise levels from equipment. Avoid placing high noise producing equipment next to workstations, telephones & PA speakers where possible.

� Lighting. Discuss and check that the equipment has obstructed no main or emergency lights and the lights are sufficient & functioning correctly.

� Access & Egress. Discuss the importance of maintaining the designated escape routes and ensuring that our equipment’s normally manned points have good access & egress.

� Communication. Discuss the requirement to have the platform PA announcements audible at our workstations and good access to the platform telephone system.

� Radios. Ensure that our radios are intrinsically safe and that the frequencies do not interfere with platform operations.

� Scale. Discuss if there is a possibility of encountering any Pyrophoric or LSA scale.

5. Hazard Controls

� Personal protective equipment. Discuss required PPE such as respirators, head protection, protective footwear, hand and skin protection, and fall protection.

� Waste Management. Discuss the clients waste management system, the location of segregated skips, waste oil disposal, storage drum drip trays and spent battery disposal.

� Physical barriers. Discuss items such as hose covers, line tie-downs, guards, railings, and inert gas blankets.

� Safety equipment. Discuss safety items such as relief valves, bursting discs, rig savers, and communications.

� Environment. Discuss control measures to prevent environmental pollution. E.g. Closing drains to sea, preventing disruption to the oil in water monitoring instrumentation from washing down chemicals, etc

� Vents & Drains. Discuss vent & drain lines for acid tanks, bulk tanks, bunded areas, work areas etc.

� Good Housekeeping. Discuss the importance of a tidy work-site and the control measures in place to ensure compliance.

� Control of Substances Harmful to Health Discuss any specific problems and review the MSDS information.

8. Permit to work

Discuss any special conditions

9. Roles and Responsibilities

Incidents or Near misses. Make the site safe and if applicable secure the well immediately prior to notifying line management up to Service Co-ordinator level. An Early Notification Form must be completed and sent to town at the earliest opportunity, and at least within 12 hours of the incident.

FORM








Rev Date: 22/12/08

Rev No: 1

Page: 3 of 4


10. Competence

Review opportunities that exist to carry out observations Assessor(s) on the job

Tick YES q NO q

Assessor name(s)

Name Name Name

Review opportunities that exist to carry out Expert Witness testimonies Supervisors available to carry out Expert W.T’s

Name Name Name

Personnel who require Expert W.T’s or Observations

Name Name Name

Name

Name Name

Confirm competence candidates have blank copies of required paperwork with them. Expert witness testimonies, Client/third party/colleague/muster witness testimonies.

YES / NO

Copy of units , Index of evidence and cross referencing index (for matching the evidence with the appropriate PC)

YES / NO

(PPS candidates only) Does the job involve work on an unbilical system

Do PPS candidates have the unbilical units (unit 7), index and cross reference index with them?

(Nitrogen candidates only) Does the job involve helium leak detection work

Do nitrogen candidates have HLD, index and cross reference index with them?

Are ALL competence candidates using the LATEST competence paperwork? How old is the competence paperwork on your 3 ½ “ floppy disks, or hard drives? If more than 6 months old consider updating it.

IF IN DOUBT , check the UK North HMS under : Common Processes -Documentation register. Or see PE competence support staff.

Review evidence collection possibilities that exist on this job If the project is already underway, at what stage is the job at Rig up / Run job / Rig down (prior to new rig up?)

Are any of the job personnel having difficulty obtaining a specific piece of evidence

Name Name Name

Evidence

Evidence Evidence

FORM








Rev Date: 22/12/08

Rev No: 1

Page: 4 of 4


Comments

11. Telephone Numbers and/or Method of Contact

Installation Emergency Telephone No:____ Control Room Telephone No:___

Supervisor Tel No. Cabin:___ Work-site:___ Permit office Telephone Number:___

Safety Rep. Tel No. Cabin:___ Work-site:___ Heli-admin Telephone Number:___

Supervisor’s Signature:_________________

NOTES

of 1

TITLE REV No REV DATE PAGE

1 5-Aug-10

Project: Length in metres Inches ID:

Location: Section ID in Metres

Client: ID in Metres Volume P/M in M3 0.00000 Volume in M3 #REF! ID in MM

Date: Sales Order No ID in MM VolumeP/M in LITRES 0

CHEMICAL 1 CHEMICAL 2

DILUTION Parts Water 4 Parts Chem. 1 Parts Water 4 Parts Chem. 1

TIME OF DAY

TIME TOTAL IN MINUTES

TIME DIFFERENCE

ACTUAL WATER FLOWMETER READING

BULK WATER VOLUME

CHEMICAL FLOWMETER

READING 1

CHEMICAL VOLUME IN

LITRES

CHEMICAL VOLUME

RATEINSTANT PPM ACTUAL PPM

AVERAGE PPM

CHEMICAL FLOWMETER

READING 2

CHEMICAL VOLUME IN

LITRES

CHEMICAL VOLUME RATE

INSTANT PPM ACTUAL PPMAVERAGE

PPMWATER

VOLUME RATEFLOODING DISTANCE

PIPELINE PRESSURE

FLOODING COMMENTS

PIG SPEED IN METRES PER SECOND

ACTUAL MINUTES MINUTES M3 M3 LITRES LITRES LITRES/MIN PPM PPM / 4 PPM LITRES LITRES LITRES/MIN PPM PPM / 4 PPM M3/MIN METRES BARG M/PER/SECOND

Print name:

Pipeline Fill Details

Sign:

Date:

For:

Customer Approval HPPS Supervisor

Date:

For: HALLIBURTON

Sign:

Print name:

DILUTION

FUNCTION / PSLREGION

GlobalPIPELINE & PROCESS

SERVICES

HALLIBURTON MANAGEMENT SYSTEM DOCUMENT NUMBER

FO-GL-HAL-PPS-423 SUBSEA PIGGING UNIT FILL REPORT

& CHEMICAL DOSING (2 Chemicals)PE HMS Coordinator S Arrington M MacMillan

OWNER APPROVED BY REVISION BY

FORM

FORM

Title: Operations Log







Rev Date: 17.Dec2.008

Rev No: 1.0

Page: 1 of 2

Client: Start Date: Sales Order:

Project: Location:

Date Time Log

OPTIONS ON SIGNATURES Customer Acceptance Halliburton Supervisor/Engineer A FULL signature is required only on the last page. The remaining pages MUST be initialled by the client & HPPS, if this option is used.

Name Company: Name:

Signature:

Signature:

Date: Date:

If you wish to add or remove pages use the toolbar Add☺ Remove page (If unable to find, go to ' File/right click/Add pages)

Once printed this document becomes uncontrolled, refer to HMS for controlled copy.

FORM

Title: Operations Log







Rev Date: 17.Dec2.008

Rev No: 1.0

Page: 2 of 2

Client: Start Date: Sales Order:

Project: Location:

Date Time Log

OPTIONS ON SIGNATURES Customer Acceptance Halliburton Supervisor/Engineer A FULL signature is required only on the last page. The remaining pages MUST be initialled by the client & HPPS, if this option is used.

Name Company: Name:

Signature:

Signature:

Date: Date:

If you wish to add or remove pages use the toolbar Add☺ Remove page (If unable to find, go to ' File/right click/Add pages)

Once printed this document becomes uncontrolled, refer to HMS for controlled copy.

FORM

Title: Function Test Acceptance Certificate







Rev Date: 22/12/08

Rev No: 1

Page: 1 of 1


Client:

Date:

Index:

Sales Order:

Project:

Location:

Pressure Test

Details

Duration of Test

Time Date Pressure

From

To

Flow Test Details

Duration of Test

Time Date Flow

From

To

Instrumentation Details

Instrument

Serial Number

Manufacturer Calibration Date Reading

Deadweight/Transducer

Pressure Recorder

Pressure Gauge

Temperature Instrument (1)

Flowmeter

Pump Barrel Counter (MC2)

Stroke Counter

Customer Acceptance Halliburton Supervisor/Engineer

Name:

Date: Name: Date:

Signature: Company Signature:

FORM

Title: Change Control Form




Owner: PPS HMS Coordinator


Job Revision By: M MacMillan

Rev Date: 22 Feb. 2011

Rev No: 7.0

Page: 1 of 1

CHANGE APPROVAL

Accepted Rejected Deferred Name: Signed: Date:

Comments:

CHANGE IMPLEMENTATION

Asset:

Implementer: Date completed: Signature:


Change Control Form This Change Control Form should be completed for each proposed change. All Change Control Forms should be recorded on the Change Control Log (FO-GL-HAL-PPS-116).

Project Title: Job Number:

Project Manager:

CHANGE REQUEST

Originator: Requested by:

Date of Request: Change Request No:

Items to be changed:

Reference(s):

Description of change (reasons for change, benefits, date required):

Estimated cost and time to implement (Engineering; Equipment; Personnel; Mob/Demob; Consumables; Cost Plus Items) Quotation attached? Yes / No

Client Signature (as appropriate) Date:

Priority / Constraints (impact on other deliverables, implications of not proceeding, risks):

CHANGE EVALUATION

What is affected:

Work required (resources, costs, dates):

Related change requests:

Name of evaluator: Date evaluated:

Signature:

Print Name: Print Name:

Sign

Fit securely a client provided transponder on to the SPHU. This is to aid in positing, locating and recovery.

17

18

19

20

Inspect the seals on the client provided hotstabs and if in doubt of their condition replace them.

Pre-Deployment Section:

Date:

Sign

For:

Date:

Calibrate the datalogger/flowmeters if need be.

4

Charge hydraulic compensators to 2/3 full.

15

6

7

Inspect the seals on the hydrotest panel hotstabs and if in doubt of their condition replace them.

24 Fit Coflexip jumper hose with the correct configuration of buoyancy modules.

Prepare 2 x 40m lengths of hydrotest hose by connecting the 1” hotstab and client supplied hotstab at either end.

Hydrotest hoses to have been integrity tested during the function testing.

Fill chemical bags with sufficient chemicals for the operation.

Connect of the hydrotest lines to the panel via the 1” stabs. Each hose in use will be demarcated with a different colour and the ports on the SPHU hydrotest panel will be similarly marked to identify ach system being tested.

Replace the straight lift slings with the offset lifting slings used for lifting and deployment of the fully assembled SPHU.

Deploy outrigger mats.

Fit chemical bags into hold and secure fast with rope.

25

21

22

HPPS SupervisorCustomer Approval

12

Using the HPU, energise the booster pump and ensure that all hydraulic gauges are working and that datalogger is displaying readings.

No

2

10

Power up the datalogger and function test sensor cables and display lights.

Ensure that bolts on dataloggers pod are tight and pod is water tight.

Properly inspect the SPHU, paying special attention to all hydraulic hose/tube connections and fittings, pipework flanges, electrical connections, pump mountings and hydraulic connections as well as filter cage.

Check smooth functioning of SPHU valves.

Calibrate the datalogger/flowmeters if need be.

Connect laptop and download files from the datalogger.

Delete all downloaded files from the datalogger.

Location:

3

13

16

Using the HPU, energise the hydrotest pump and ensure that all hydraulic gauges are working and that datalogger is displaying readings.

11

Check charge on batteries, if needed re-charge them.

23

24

8

5

Ensure hydrotest pump crankcase has enough oil.

14

9

Owner

SAP #

Check [√]

Project:

Date:

Operation:

Contract #Client:

Time:

Description of Action

Pump and bleed hydraulic fluid through the hydraulic system to ensure it is free of air.

Flow control nozzles shall be verfied for size against procedural specifications1

HALLIBURTON MANAGEMENT SYSTEMDOCUMENT NUMBER:

FO-GL-HAL-PPS-422Revision Date Revision No Page

S Arrington M MacMillan 24 MAY. 2010 2 1 of 1

FORMTitle Region Function / PSL

Pre-Deployment Checklist Global Pipeline & Process Services

Approved by Revised by

B&C HMS Coordinator

Km

FO-UK-HAL-PPS-423

Rev No

1

Rev Date

06th AUG. 2010

Revised by

M MacMillan

Page

GlobalPipeline & Process

Services1 of 1

REGION Function/PSL

S Arrington

Approved byOwner

PE HMS Coordinator

FORMTITLE HALLIBURTON MANAGEMENT SYSTEM

DOCUMENT NUMBER

FO-GL-HAL-PPS-425PIPELINE PIG / FLUSHING REPORT

mm

TRUE

ETA in

TRUE

Print Name:

For:

Date:

Sign:

CUSTOMER APPROVAL

Pipeline Sect:

m³

TRUE

Hr/m/ss

TRUE

TRUE

TRUE

TRUE

TRUE

TRUE

TRUE

TRUE

TRUE

TRUE

TRUE

TRUE

TRUE

TRUE

TRUE

TRUE

TRUE

TRUE

TRUE

TRUE

10 23

Index:

Project: Location:

Pipeline Length:

Sales Order:

Client: Date:

Pipeline ID: Fill Volume:

HPPS SUPERVISOR

Distance Km

TimeVolume

m³Velocity

m/s

ONCE PRINTED THIS FORM IS UNCONTROLLED; REFER TO HMS FOR CONTROLLED COPY

19th August 09

Print Name:

Sign:

Date:

Pressure Remarks

FO-UK-HAL-PPS-427, Rev 3 Page 1 of 1 20th August 09

Date:

Date:

For

FORMTITLE

PIPELINE PRESSURISATION REPORT


FO-GL-HAL-PPS-426

Halliburton SupervisorAcceptance:

Time Pressure

Date:Sales Order:

PAGE

GlobalPipeline & Process Services PE HMS Coordinator S Arrington M MacMillan 06 Aug. 2010 1 1 of 1

VolumePressureTime ∆ VolumeVolume∆ Volume Time Pressure

Vol./Stroke:

REGION FUNCTION/PSL OWNER APPROVED BY REVISION BY REV DATE REV No

Index:

Client:

Pipeline ID: Fill Volume:

Location:Project:

Pipeline Section: Pipeline Length:

∆ VolumeVolume

-


Global PE HMS Coordi

Print Name: Print Name:

Sign: Sign:

For: Date:

Date:

FO-UK-HAL-PPS-428 Rev 5 20th August 09


CUSTOMER APPROVAL HPPS SUPERVISOR

Remarks

TimePressure

Bar G

Wall Thickness mmPipeline ID: mm Fill Volume: m³

OWNER APPROVED REVISION BY REV DATE

Pipeline Sect: Pipeline Length: Km

Project: Location:Sales Order:

FORMTITLE HALLIBURTON MANAGEMENT SYSTEM

DOCUMENT NUMBER

FO-GL-HAL-PPS-427PIPELINE TEST REPORT

Client: Date: Index:

REV No PAGE


S Arringotn M MacMillan 06th Aug. 2010

1 1 of 1

REGION FUNCTION/PSL

TITLE

Print Name:

Sign:

Date:

FO-GL-HAL-PPS-428 R

Page

1 1 of 106th Aug. 2010

FORM


FO-GL-HAL-PPS-428

Approved by

S Arrington

Revised by

M MacMillan

Revision date Revision No

PIPELINE AIR INCLUSION REPORTREGION FUNCTION/PSL

Pipeline & Process ServicesGlobal

#DIV/0!

Comments

Vair = (VB-Vt) x stroke volume =

Air Inclusion Graph

151617

Index:

Sign:

35 Vb

Project: Location:Sales Order:

Client:


Rev 5

For:

CUSTOMER APPROVAL HPPS SUPERVISOR Print Name:

06 Aug. 2010

282930

Date:

Date:

Owner

OE HMS Coordinato

31

3334

Pipeline ID:

789

12

Time

56

23

13

1

34

2

1011

14

1819202122

Strokes Stroke

difference

Pressure

Bar G

0

LitresLitres

Air Inclusion

32

Vair x 100 Fill Volume24

25 Va2627

1

Litres

Actual V = VB =Theoretical Vt = (VB-VA)x3.5 =

Pipeline Length:

Vol./Stroke:

KmPipeline Sect:

m³Fill Volume:mm

LitresValues

0

5

10

15

20

25

30

35

40

0 0.2 0.4 0.6 0.8 1

Pre

ssur

e B

ar G

Stk Vol x Stks

FORM Title:

PIPELINE ACCEPTANCE CERTIFICATE HALLIBURTON MANAGEMENT SYSTEM

DOCUMENT NUMBER:

FO-GL-HAL-PPS-429 REGION: Global

FUNCTION/PSL: Pipeline & Process Services

OWNER: PE HMS Coordinator

APPROVED BY: S Arrington

REVISION BY: M MacMillan

REV. DATE: 06th Aug. 2010

REV. NO: 01

PAGE: 1 of 1

Client: Date: Index:

Project: Location: Sales Order #:

FO-GL-HAL-PPS-429 Rev 0 Page 1 of 1 06th Aug 2010


Test Details

This is to certify the

From:

To:

Was tested as outlined below Type of Test

Location of Test Unit

Maximum pressure recorded during the test period

Remarks:

Duration of Test Time Date Pressure

From:

To:

Instrument Details Serial Number Manufacturer Calibration date

Deadweight / transducer:

Pressure Recorder:

Pressure Gauge:

Temperature Instrument 1:



Signed for on behalf of Halliburton Pipeline & Process Services HPPS Supervisor/Engineer

Name Date Signature

Customer Acceptance Signatures

Name Signature/Stamp Name: Signature/Stamp

Company Date Company Date

Name Signature/Stamp Name: Signature/Stamp

Company Date Company Date

F0-UK-HAL-PPS-435, Rev 01 Page 1 of 1 12th August 09

TITLE

Date:

Index:

Pipeline Length: Km

Receive Point:

Gauge Plate

Photo #

Print Name: Print Name Date

Sign: Sign:

For:

FORMREGION FUNCTION/PSL HALLIBURTON MANAGEMENT SYSTEM

DOCUMENT NUMBER

FO-GL-HAL-PPS-430 PIG LAUNCH / RECEIVE REGISTER Global Pipeline & Process Services

Owner Approved by Revision by Revision date Revision # PagePE HMS Coordinator S Arrington M MacMillan 06th Aug. 2010 1 1 of 1

Pipeline Sect:

Launch Point: Pipeline ID:

Client: Sales order #

Project: Location:

Pig Unique NoPig OD (Inches)

Pig TypeLaunch Receive

Pig / Gauge plate - Condition on RemovalTime Date Time Date

CUSTOMER APPROVAL HPPS SUPERVISORDate

FORM

Title: Back-load Checksheet


FO-GL-HAL-PPS-501

Region: Global






Rev No: 1.0

Page: 1 of 3


PRODUCTION ENHANCEMENT BACKLOAD Delivery Address Halliburton Energy Services, Production Enhancement PSL

CUSTOMER

LOCATION

Delete as appropriate

PROJECT

SALES ORDER NUMBER

DATE

BACKLOAD CHECKLIST

TO BE COMPLETED FOR ALL LIFT EQUIPMENT (including PUMPS, TANKS, CONTAINERS, etc.) Serial No

Contents / Description

Length

Width

Height

Weight

(KG)

Backload checklist

complied with

Initial……………….













CONTINUES ON PAGE TWO

PERSONNEL INVOLVED IN BACKLOAD

Name

Signature

Name

Signature

Name

Signature

Name

Signature

Name

Signature

Name

Signature

Name

Signature

Name

Signature

BACKLOAD CONDITION & STATUS

Confirmation that all equipment, chemicals and oils are in a safe and secure condition for backloading. Onsite Job Supervisor/Engineer – NAME (or designated person)

Signature

1. Slings, Shackles & Pins all in place

BACKLOAD CHECKLIST

2. Checked containers & equipment (including

TOP), for loose items. (Potential for Dropped Objects)

3. ALL Loose items in closed containers & half

heights containers secured. 4. Cargo nets replaced in containers & baskets

or half heights.

FORM



FO-GL-HAL-PPS-501

Region: Global






Rev No: 1.0

Page: 2 of 3


BACKLOAD CHECKLIST - CONTINUATION Serial No

Contents / Description

Length

Width

Height

Weight

(KG)

Backload checklist

complied w ith












STATUS OF BACKLOADED CHEMICAL TANKS used on job

Tank Serial Number

Tank Size & Contents

RETURNED TANK STATUS

Tank Full

Tank Part filled

Tank Empty Tank access cover closed & secured

Dirty NOT Flushed out

Clean Flushed out

Contents Approx Volume Tick (Approx Volume) Tick Tick Tick

US gal M³

..………usg / M³

US gal M³

...………usg / M³

US gal

M³

...………usg / M³

US gal

M³

...………usg / M³

US gal

M³

...………usg / M³

US gal

M³

...………usg / M³

US gal

M³

...………usg / M³

US gal

M³

...………usg / M³

US gal M³

...………usg / M³

US gal

M³

...………usg / M³

US gal M³

...………usg / M³

US gal

M³

...………usg / M³

US gal M³

...………usg / M³

DO NOT REMOVE CHEMICAL HAZARD STICKERS FROM EMPTY ‘UNCLEANED’ TANKS

FORM



FO-GL-HAL-PPS-501

Region: Global






Rev No: 1.0

Page: 3 of 3


STATUS OF CHEMICAL DRUMS/SACKS RETURNED IN SHIPPING CONTAINERS

CONTAINER NUMBER Do not remove chemical hazard labels from EMPTY UNCLEANED Drums

Chemical

Drum size

No Full Drums

returned

No Part filled Drums

returned

No EMPTY Drums

returned

No Sacks

Chemical / oil drums sealed and secured. Drums placed INSIDE container bunded areas (where fitted).

Initial as

Correct

………

Full Opened

Remarks

CONTAINER NUMBER

Do not remove chemical hazard labels from EMPTY UNCLEANED Drums

Chemical

Drum size

No Full Drums

returned


returned

No EMPTY Drums

returned

No Sacks


Initial as

Correct

………

Full Opened

Remarks

CONTAINER NUMBER


Chemical

Drum size

No Full Drums

returned


returned

No EMPTY Drums

returned

No Sacks


Initial as

Correct

………

Full Opened

Remarks

CONTAINER NUMBER


Chemical

Drum size

No Full Drums

returned


returned

No EMPTY Drums

returned

No Sacks


Initial as

Correct

………

Full Opened

Remarks

CONTAINER NUMBER Do not remove chemical hazard labels from EMPTY UNCLEANED Drums

Chemical

Drum size

No Full Drums

returned


returned

No EMPTY Drums

returned

No Sacks


Initial as

Correct

………

Full Opened

Remarks