HPPS Cleaning Flooding Hydrotest Procedure
description
Transcript of HPPS Cleaning Flooding Hydrotest Procedure
SNEPCO-BMIP-BNW and Saipem Consortium – led by SCNL.
Document No.:
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
SNEPCO-BMIP-BNW and Saipem Consortium – led by SCNL.
Document No.:
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 3 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.
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
SNEPCO-BMIP-BNW and Saipem Consortium – led by SCNL.
Document No.:
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 4 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.
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
SNEPCO-BMIP-BNW and Saipem Consortium – led by SCNL.
Document No.:
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 5 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.
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.
SNEPCO-BMIP-BNW and Saipem Consortium – led by SCNL.
Document No.:
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 6 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.
Fig: 1.1: SPHU Operations Schematic
SNEPCO-BMIP-BNW and Saipem Consortium – led by SCNL.
Document No.:
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 7 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.
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
SNEPCO-BMIP-BNW and Saipem Consortium – led by SCNL.
Document No.:
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 8 of 91
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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
SNEPCO-BMIP-BNW and Saipem Consortium – led by SCNL.
Document No.:
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 9 of 91
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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
SNEPCO-BMIP-BNW and Saipem Consortium – led by SCNL.
Document No.:
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 10 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.
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
SNEPCO-BMIP-BNW and Saipem Consortium – led by SCNL.
Document No.:
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 11 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.
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
SNEPCO-BMIP-BNW and Saipem Consortium – led by SCNL.
Document No.:
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 12 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.
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)
SNEPCO-BMIP-BNW and Saipem Consortium – led by SCNL.
Document No.:
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 13 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.
3.5 HPPS Project Organogram
SNEPCO-BMIP-BNW and Saipem Consortium – led by SCNL.
Document No.:
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 14 of 91
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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.
SNEPCO-BMIP-BNW and Saipem Consortium – led by SCNL.
Document No.:
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 15 of 91
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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.
SNEPCO-BMIP-BNW and Saipem Consortium – led by SCNL.
Document No.:
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 16 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.
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.
SNEPCO-BMIP-BNW and Saipem Consortium – led by SCNL.
Document No.:
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 17 of 91
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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.
SNEPCO-BMIP-BNW and Saipem Consortium – led by SCNL.
Document No.:
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 18 of 91
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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
SNEPCO-BMIP-BNW and Saipem Consortium – led by SCNL.
Document No.:
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 19 of 91
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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
SNEPCO-BMIP-BNW and Saipem Consortium – led by SCNL.
Document No.:
BMIP-BNW-D01938-LA-6180-00129-000
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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 20 of 91
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HS & E Incident Early Notification Form
Sample below (FO-UK-HES-HSE-002-1 Rev 4)
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Document No.:
BMIP-BNW-D01938-LA-6180-00129-000
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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 21 of 91
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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
Contained in item 5 2
19. 20m length x ½” HP (10k) pressurisation Hose
Contained in item 5 2
20. 40m length x ¾” HP (20k) pressurisation Hose
Contained in item 5 2
21. 20m Lengths of ¾” Air Hose 10k psi crowsfoot
Contained in item 5 2
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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Document No.:
BMIP-BNW-D01938-LA-6180-00129-000
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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 22 of 91
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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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Document No.:
BMIP-BNW-D01938-LA-6180-00129-000
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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 23 of 91
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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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Document No.:
BMIP-BNW-D01938-LA-6180-00129-000
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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 24 of 91
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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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Document No.:
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 25 of 91
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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.
SNEPCO-BMIP-BNW and Saipem Consortium – led by SCNL.
Document No.:
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 26 of 91
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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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Document No.:
BMIP-BNW-D01938-LA-6180-00129-000
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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 27 of 91
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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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Document No.:
BMIP-BNW-D01938-LA-6180-00129-000
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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 28 of 91
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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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Document No.:
BMIP-BNW-D01938-LA-6180-00129-000
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D01938 - Fabrication of Flowlines & provision of Subsea Installation Services
Document Title:
HPPS FLOWLINE PRECOMMISSIONING – PRODUCTION & WI FLOWLINES CLEANING, FLOODING, PIGGING, GAUGING AND HYDROTESTING PROCEDURE
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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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BMIP-BNW-D01938-LA-6180-00129-000
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D01938 - Fabrication of Flowlines & provision of Subsea Installation Services
Document Title:
HPPS FLOWLINE PRECOMMISSIONING – PRODUCTION & WI FLOWLINES CLEANING, FLOODING, PIGGING, GAUGING AND HYDROTESTING PROCEDURE
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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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Document No.:
BMIP-BNW-D01938-LA-6180-00129-000
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D01938 - Fabrication of Flowlines & provision of Subsea Installation Services
Document Title:
HPPS FLOWLINE PRECOMMISSIONING – PRODUCTION & WI FLOWLINES CLEANING, FLOODING, PIGGING, GAUGING AND HYDROTESTING PROCEDURE
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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
Identification Description
PID/Drawing Reference
Location Status Check
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
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 Isolation
valve 2 UK-120059-DR-008 On Hydrotest
Panel ½ Open
HTV03 Hydrotest Isolation
valve 3 UK-120059-DR-008 On Hydrotest
Panel ½ Open
HTV04 Hydrotest Isolation
valve 4 UK-120059-DR-008 On Hydrotest
Panel½ Open
HTV05 Hydrotest Isolation
valve 5 UK-120059-DR-008 On Hydrotest
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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BMIP-BNW-D01938-LA-6180-00129-000
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D01938 - Fabrication of Flowlines & provision of Subsea Installation Services
Document Title:
HPPS FLOWLINE PRECOMMISSIONING – PRODUCTION & WI FLOWLINES CLEANING, FLOODING, PIGGING, GAUGING AND HYDROTESTING PROCEDURE
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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
SNEPCO-BMIP-BNW and Saipem Consortium – led by SCNL.
Document No.:
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 33 of 91
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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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HPPS FLOWLINE PRECOMMISSIONING – PRODUCTION & WI FLOWLINES CLEANING, FLOODING, PIGGING, GAUGING AND HYDROTESTING PROCEDURE
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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.
SNEPCO-BMIP-BNW and Saipem Consortium – led by SCNL.
Document No.:
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 35 of 91
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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.
SNEPCO-BMIP-BNW and Saipem Consortium – led by SCNL.
Document No.:
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 36 of 91
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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
Identification Description
PID/Drawing Reference
Location Status Check
HPV1 Line Isolation
valve UK-120059-DR-008
On top SPHU Closed
HPV2 Booster Pump Isolation valve
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
Isolation valve 2 UK-120059-DR-008 On Hydrotest
Panel Closed
HTV03 Hydrotest
Isolation valve 3
UK-120059-DR-008 On Hydrotest Panel
Closed
HTV04 Hydrotest
Isolation valve 4 UK-120059-DR-008 On Hydrotest
Panel Closed
HTV05 Hydrotest
Isolation valve 5 UK-120059-DR-008 On Hydrotest
Panel Closed
VV01 Hydrotest Vent
valve UK-120059-DR-008 On Hydrotest
Panel Closed
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Document No.:
BMIP-BNW-D01938-LA-6180-00129-000
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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 37 of 91
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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.
Pipeline Permit No. Name Sign Date
PFL13
PFL14
PFL15
PFL16
WFL04
HSE
SNEPCO-BMIP-BNW and Saipem Consortium – led by SCNL.
Document No.:
BMIP-BNW-D01938-LA-6180-00129-000
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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 38 of 91
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6.3.3 Check communications between HPPS, and ROV Control.
Pipeline Name Sign Date
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
SNEPCO-BMIP-BNW and Saipem Consortium – led by SCNL.
Document No.:
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 39 of 91
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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
PFL14 Launch Pig 6.3.21
FCG Completion 6.3.51
PFL15 Launch Pig 6.3.21
FCG Completion 6.3.51
PFL16 Launch Pig 6.3.21
FCG Completion 6.3.51
WFL04 Launch Pig 6.3.21
FCG Completion 6.3.51
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
SNEPCO-BMIP-BNW and Saipem Consortium – led by SCNL.
Document No.:
BMIP-BNW-D01938-LA-6180-00129-000
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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 40 of 91
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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
Identification Description
PID/Drawing Reference
Location Status Check
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
Identification Description
PID/Drawing Reference
Location Status Check
L1 Launching Cap Valve
N/A Abandonment PFTA/WFTA
Closed
PFL13 PFL14 PFL15 PFL16
WFL04
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Document No.:
BMIP-BNW-D01938-LA-6180-00129-000
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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 41 of 91
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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
Identification Description
PID/Drawing Reference
Location Status Check
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.
SNEPCO-BMIP-BNW and Saipem Consortium – led by SCNL.
Document No.:
BMIP-BNW-D01938-LA-6180-00129-000
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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 42 of 91
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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
Identification Description
PID/Drawing Reference
Location Status Check
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
Identification Description
PID/Drawing Reference
Location Status Check
HPV1 Line Isolation
valve UK-120059-
DR-008 On top SPHU Open
PFL13
PFL14
PFL15
PFL16
WFL04
SNEPCO-BMIP-BNW and Saipem Consortium – led by SCNL.
Document No.:
BMIP-BNW-D01938-LA-6180-00129-000
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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 43 of 91
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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
PFL13 PFL14 PFL15 PFL16 WFL04
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.
SNEPCO-BMIP-BNW and Saipem Consortium – led by SCNL.
Document No.:
BMIP-BNW-D01938-LA-6180-00129-000
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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 44 of 91
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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
Identification Description
PID/Drawing Reference
Location Status Check
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.
SNEPCO-BMIP-BNW and Saipem Consortium – led by SCNL.
Document No.:
BMIP-BNW-D01938-LA-6180-00129-000
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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 45 of 91
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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
PFL13 PFL14 PFL15 PFL16 WFL04
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.
Task Pipeline HPPS Check Saipem Check
Bulk and Chemical flowmeters registering
PFL13 PFL14 PFL15 PFL16 WFL04
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Document No.:
BMIP-BNW-D01938-LA-6180-00129-000
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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 46 of 91
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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.
Pipeline Name Sign Date
PFL13
PFL14
PFL15
PFL16
WFL04
6.3.51 Instruct ROV to close valve HPV2 – boost pump isolation valve.
Valve
Identification Description
PID/Drawing Reference
Location Status Check
HPV2 Line Isolation
valve UK-120059-
DR-009 On top SPHU Closed
PFL13 PFL14 PFL15 PFL16
WFL04
HSE
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BMIP-BNW-D01938-LA-6180-00129-000
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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 47 of 91
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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
Identification Description
PID/Drawing Reference
Location Status Check
L1 Launching Cap Valve
N/A Abandonment PFTA/WFTA
Closed
PFL13 PFL14 PFL15 PFL16 WFL04
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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
PFL13 PFL14 PFL15 PFL16 WFL04
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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BMIP-BNW-D01938-LA-6180-00129-000
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D01938 - Fabrication of Flowlines & provision of Subsea Installation Services
Document Title:
HPPS FLOWLINE PRECOMMISSIONING – PRODUCTION & WI FLOWLINES CLEANING, FLOODING, PIGGING, GAUGING AND HYDROTESTING PROCEDURE
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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
Identification Description
PID/Drawing Reference
Location Status Check
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
Identification Description
PID/Drawing Reference
Location Status Check
L1 Launching Cap Valve
N/A Abandonment PFTA/WFTA
Open
PFL13 PFL14 PFL15 PFL16 WFL04
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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
Identification Description
PID/Drawing Reference
Location Status Check
L1 Launching Cap Valve
N/A Abandonment PFTA/WFTA
Closed
PFL13 PFL14 PFL15 PFL16 WFL04
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.
SNEPCO-BMIP-BNW and Saipem Consortium – led by SCNL.
Document No.:
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 51 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.
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
Identification Description
PID/Drawing Reference
Location Status Check
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.
Task Pipeline HPPS Check Saipem Check
Return Coflexip hose to panel frame saddle and lock in
position.
PFL13 PFL14 PFL15 PFL16 WFL04
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.
SNEPCO-BMIP-BNW and Saipem Consortium – led by SCNL.
Document No.:
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 52 of 91
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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.
Pipeline Name Sign Date
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.
SNEPCO-BMIP-BNW and Saipem Consortium – led by SCNL.
Document No.:
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 53 of 91
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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.
SNEPCO-BMIP-BNW and Saipem Consortium – led by SCNL.
Document No.:
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 54 of 91
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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.
SNEPCO-BMIP-BNW and Saipem Consortium – led by SCNL.
Document No.:
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 55 of 91
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6.5.8 Ensure operational permit is valid.
Pipeline Permit No. Name Sign Date
PFL13
PFL14
PFL15
PFL16
WFL04
6.5.9 Check communication between ROV control and client Rep., prior to applying any pressure.
Pipeline Name Sign Date
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
SNEPCO-BMIP-BNW and Saipem Consortium – led by SCNL.
Document No.:
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 56 of 91
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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
PFL14 Hydrotest 6.5.44
Completion 6.5.60
PFL15 Hydrotest 6.5.44
Completion 6.5.60
PFL16 Hydrotest 6.5.44
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.
SNEPCO-BMIP-BNW and Saipem Consortium – led by SCNL.
Document No.:
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 57 of 91
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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
Identification Description
PID/Drawing Reference
Location Status Check
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.
SNEPCO-BMIP-BNW and Saipem Consortium – led by SCNL.
Document No.:
BMIP-BNW-D01938-LA-6180-00129-000
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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 58 of 91
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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.
Task Pipeline HPPS Check Saipem Check
Deepstar hydraulic stab assembly properly engaged
PFL13 PFL14 PFL15 PFL16
WFL04
SNEPCO-BMIP-BNW and Saipem Consortium – led by SCNL.
Document No.:
BMIP-BNW-D01938-LA-6180-00129-000
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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 59 of 91
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RISK
6.5.21 Open the panel valves which have got the required hydrotest hose attached to them.
Pipeline Hose Identification
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
PFL13 PFL14 PFL15 PFL16
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.
SNEPCO-BMIP-BNW and Saipem Consortium – led by SCNL.
Document No.:
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 60 of 91
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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.
Task Pipeline HPPS Check
Shut off hydraulic supply to hydrotest pump
PFL13 PFL14 PFL15 PFL16 WFL04
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.
Task Pipeline HPPS Check
Connect hydrotest hose c/w hotstab to inlet port on pressurisation cap.
PFL13 PFL14 PFL15 PFL16
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.
SNEPCO-BMIP-BNW and Saipem Consortium – led by SCNL.
Document No.:
BMIP-BNW-D01938-LA-6180-00129-000
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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 61 of 91
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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.
Pipeline Hose Identification
Panel Valve No. Status Date
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.
SNEPCO-BMIP-BNW and Saipem Consortium – led by SCNL.
Document No.:
BMIP-BNW-D01938-LA-6180-00129-000
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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 62 of 91
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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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BMIP-BNW-D01938-LA-6180-00129-000
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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 63 of 91
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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
Identification Description
PID/Drawing Reference
Location Status Check
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.
Pipeline Name Sign Date
PFL13
PFL14
PFL15
PFL16
WFL04
HSE
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BMIP-BNW-D01938-LA-6180-00129-000
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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 64 of 91
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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
Reference Location Status Check
L1 Launching Cap Valve
N/A Abandonment PFTA/WFTA
Open
PFL13 PFL14 PFL15 PFL16 WFL04
6.5.39 The ROV shall return to the SPHU and reconnect the DeepStar hydraulic stab assembly, ready to commence pressurisation of the pipelines.
Task Pipeline HPPS Check
Reconnect Deepstar hydraulic stab assembly.
PFL13 PFL14 PFL15 PFL16 WFL04
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.
Pipeline Name Sign Date
PFL13
PFL14
PFL15
PFL16
WFL04
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HPPS Document No: UK-120059-PR-006 Rev R01 Page 66 of 91
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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.
Pipeline Hose Identification
Panel Valve No. Status Date
PFL13
PFL14
PFL15
PFL16
WFL04
6.5.45 The vent valve VV01 and hydrotest panel isolation valve HTV05 shall be closed.
Valve
Identification Description
PID/Drawing Reference
Location Status Check
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
6.5.46 Hydraulic flowrate is controllable by ROV hydraulic supply percentage control or 2 stage high-low control.
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BMIP-BNW-D01938-LA-6180-00129-000
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6.5.47 A pressure reading shall be taken and logged from the SPHU prior to commencement of pressurisation.
Pipeline Hose Identification
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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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 68 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.
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.
Pipeline Name Sign Date
PFL13
PFL14
PFL15
PFL16
WFL04
SNEPCO-BMIP-BNW and Saipem Consortium – led by SCNL.
Document No.:
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 69 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.
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.
Pipeline Name Sign Date
PFL13
PFL14
PFL15
PFL16
WFL04
SNEPCO-BMIP-BNW and Saipem Consortium – led by SCNL.
Document No.:
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 70 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.
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)
SNEPCO-BMIP-BNW and Saipem Consortium – led by SCNL.
Document No.:
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 71 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.
Valve
Identification Description
PID/Drawing Reference
Location Status Check
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
On subsea datalogger manifold
Open
PFL13
PFL14
PFL15
PFL16
WFL04
DL5 &
DL6
Vent Double Isolation
Fig 6.3 On subsea datalogger manifold
Closed
PFL13
PFL14
PFL15
PFL16
WFL04
SNEPCO-BMIP-BNW and Saipem Consortium – led by SCNL.
Document No.:
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 72 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.
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
Identification Description
PID/Drawing Reference
Location Status Check
HTV05 Hydrotest Isolation valve 5
UK-120059-DR-009
On Hydrotest Panel
Open
PFL13
PFL14
PFL15
PFL16
WFL04
VV01 Hydrotest Vent valve
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.
PFL13 PFL14 PFL15 PFL16 WFL04
SNEPCO-BMIP-BNW and Saipem Consortium – led by SCNL.
Document No.:
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 73 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.
6.5.66 Once at ambient, instruct the ROV to close HTV05 and VV01.
Valve
Identification Description
PID/Drawing Reference
Location Status Check
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
6.5.67 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
SNEPCO-BMIP-BNW and Saipem Consortium – led by SCNL.
Document No.:
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 74 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.
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
Identification Description
PID/Drawing Reference
Location Status Check
HTV05 Hydrotest Isolation valve 5
UK-120059-DR-009
On Hydrotest Panel
Open
PFL13
PFL14
PFL15
PFL16
WFL04
VV01 Hydrotest Vent valve
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.
PFL13 PFL14 PFL15 PFL16 WFL04
Task Pipeline HPPS sign
Install debris plug at standalone datalogger
manifold female receptacle.
PFL13 PFL14 PFL15 PFL16 WFL04
SNEPCO-BMIP-BNW and Saipem Consortium – led by SCNL.
Document No.:
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 75 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.
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.
Pipeline Name Sign Date
PFL13
PFL14
PFL15
PFL16
WFL04
SNEPCO-BMIP-BNW and Saipem Consortium – led by SCNL.
Document No.:
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 76 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.
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.
SNEPCO-BMIP-BNW and Saipem Consortium – led by SCNL.
Document No.:
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 77 of 91
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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.
Pipeline Name Sign Date
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.
SNEPCO-BMIP-BNW and Saipem Consortium – led by SCNL.
Document No.:
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 78 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.
Valve
Identification Description
PID/Drawing Reference
Location Status Check
HTV05 Hydrotest Isolation valve 5
UK-120059-DR-009
On Hydrotest Panel
Open
PFL13
PFL14
PFL15
PFL16
WFL04
VV01 Hydrotest Vent valve
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)
SNEPCO-BMIP-BNW and Saipem Consortium – led by SCNL.
Document No.:
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 79 of 91
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Valve
Identification Description
PID/Drawing Reference
Location Status Check
DL1 &
DL2
SPHU Double
Isolation Fig 6.4
On subsea datalogger manifold
Open
PFL13
PFL14
PFL15
PFL16
WFL04
DL3 &
DL4
Pipeline Double
Isolation Fig 6.4
On subsea datalogger manifold
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.
PFL13 PFL14 PFL15 PFL16 WFL04
SNEPCO-BMIP-BNW and Saipem Consortium – led by SCNL.
Document No.:
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 80 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.
Valve
Identification Description PID/Drawing
Reference Location Status Check
L1 Launching Cap Valve
N/A Abandonment PFTA/WFTA
Closed
PFL13 PFL14 PFL15 PFL16 WFL04
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.
Pipeline Name Sign Date
PFL13
PFL14
PFL15
PFL16
WFL04
SNEPCO-BMIP-BNW and Saipem Consortium – led by SCNL.
Document No.:
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 81 of 91
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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
SNEPCO-BMIP-BNW and Saipem Consortium – led by SCNL.
Document No.:
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 82 of 91
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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
Identification Description
PID/Drawing Reference
Location Status Check
LPV1 Filter Isolation
valve UK-120059-
DR-008 In SPHU Open
HPV1 Line Isolation
valve UK-120059-
DR-008 On top SPHU Open
HPV2 Booster Pump Isolation valve
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
Isolation valve 2 UK-120059-
DR-008 On Hydrotest
Panel ½
Open
HTV03 Hydrotest
Isolation valve 3
UK-120059-DR-008
On Hydrotest Panel
½ Open
HTV04 Hydrotest
Isolation valve 4 UK-120059-
DR-008 On Hydrotest
Panel ½
Open
HTV05 Hydrotest
Isolation valve 5 UK-120059-
DR-008 On Hydrotest
Panel ½
Open
VV01 Hydrotest Vent
valve
UK-120059-DR-008
On Hydrotest Panel
3 Turns Open
SNEPCO-BMIP-BNW and Saipem Consortium – led by SCNL.
Document No.:
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 83 of 91
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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.
PFL13 PFL14 PFL15 PFL16
WFL04
SNEPCO-BMIP-BNW and Saipem Consortium – led by SCNL.
Document No.:
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 84 of 91
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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.
SNEPCO-BMIP-BNW and Saipem Consortium – led by SCNL.
Document No.:
BMIP-BNW-D01938-LA-6180-00129-000
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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 85 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.
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
Date produced: 11-Nov-12
Customer Saipem
Location Bonga Northwest
Pipeline Description: Production Flowline 14 (PFL 14) API-5L-X65 OD:263.1mm Wt:20.6mm x 3.165km
Pipeline Length (km) 3.17 km Outside Diameter (m) 0.263 mInternal Diameter (m) 0.222 m Pipeline Lay UnrestrainedTotal Vol. (imp. gals) 2.69E+04 I.gal Total Volume (m³) 122.4 m³Volume per ft (gals) 2.59 gal Vol. per metre (m³) 0.039 m³Total Volume (ft³) 4.32E+03 ft³ Vol. per metre (ft³) 1.37 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) 3.40Friction Factor 0.018702562 Reynolds Number 85813
Pressure Drop At Pigging Speed 5.2 psi = 0.36 bar
Chemical Additive Injection Rates
Chemical p.p.m. Injection Rate (litres/min)1 Ihibitor 1000.0 1.1602 Tracer dye 50.0 0.05834
PRESSURE TEST PARAMETERS Test press. 413.0 bar gTemp. 4.0 'C
Volume to pressurise pipeline : 2.452 m³ Corresponding Inlet (0-bar) Volume : 2.496 m³Volume change per bar at test pressure : 5.60 litres
Temp Compressibility Coeff Expan. Pressure changeº C (bar)¯¹ (deg C)¯¹ bar/ºC
4.16E-05 1.83E-04 3.150.7 4.14E-05 1.87E-04 3.241.4 4.13E-05 1.91E-04 3.332.1 4.11E-05 1.94E-04 3.422.8 4.10E-05 1.98E-04 3.513.3 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
Date produced: 11-Nov-12
Customer Saipem
Location Bonga Northwest
Pipeline Description: Production Flowline 15 (PFL 15) API-5L-X65 OD:263.1mm Wt:20.6mm x 3.182km
Pipeline Length (km) 3.18 km Outside Diameter (m) 0.263 mInternal Diameter (m) 0.222 m Pipeline Lay UnrestrainedTotal Vol. (imp. gals) 2.71E+04 I.gal Total Volume (m³) 123.1 m³Volume per ft (gals) 2.59 gal Vol. per metre (m³) 0.039 m³Total Volume (ft³) 4.35E+03 ft³ Vol. per metre (ft³) 1.37 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) 3.42Friction Factor 0.018702562 Reynolds Number 85813
Pressure Drop At Pigging Speed 5.2 psi = 0.36 bar
Chemical Additive Injection Rates
Chemical p.p.m. Injection Rate (litres/min)1 Ihibitor 1000.0 1.1602 Tracer dye 50.0 0.05834
PRESSURE TEST PARAMETERS Test press. 413.0 bar gTemp. 4.0 'C
Volume to pressurise pipeline : 2.465 m³ Corresponding Inlet (0-bar) Volume : 2.509 m³Volume change per bar at test pressure : 5.63 litres
Temp Compressibility Coeff Expan. Pressure changeº C (bar)¯¹ (deg C)¯¹ bar/ºC
4.16E-05 1.83E-04 3.150.7 4.14E-05 1.87E-04 3.241.4 4.13E-05 1.91E-04 3.332.1 4.11E-05 1.94E-04 3.422.8 4.10E-05 1.98E-04 3.513.3 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
Date produced: 11-Nov-12
Customer Saipem
Location Bonga Northwest
Pipeline Description: Production Flowline 16 (PFL 16) API-5L-X65 OD:263.1mm Wt:20.6mm x 3.216km
Pipeline Length (km) 3.22 km Outside Diameter (m) 0.263 mInternal Diameter (m) 0.222 m Pipeline Lay UnrestrainedTotal Vol. (imp. gals) 2.74E+04 I.gal Total Volume (m³) 124.4 m³Volume per ft (gals) 2.59 gal Vol. per metre (m³) 0.039 m³Total Volume (ft³) 4.39E+03 ft³ Vol. per metre (ft³) 1.37 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) 3.45Friction Factor 0.018702562 Reynolds Number 85813
Pressure Drop At Pigging Speed 5.2 psi = 0.36 bar
Chemical Additive Injection Rates
Chemical p.p.m. Injection Rate (litres/min)1 Ihibitor 1000.0 1.1602 Tracer dye 50.0 0.05834
PRESSURE TEST PARAMETERS Test press. 413.0 bar gTemp. 4.0 'C
Volume to pressurise pipeline : 2.491 m³ Corresponding Inlet (0-bar) Volume : 2.536 m³Volume change per bar at test pressure : 5.70 litres
Temp Compressibility Coeff Expan. Pressure changeº C (bar)¯¹ (deg C)¯¹ bar/ºC
4.16E-05 1.83E-04 3.150.7 4.14E-05 1.87E-04 3.241.4 4.13E-05 1.91E-04 3.332.1 4.11E-05 1.94E-04 3.422.8 4.10E-05 1.98E-04 3.513.3 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
Date produced: 11-Nov-12
Customer Saipem
Location Bonga Northwest
Pipeline Description: Water Injection Flowline 04 (WFL 04) API-5L-X65 OD:323.9mm Wt:20.6mm x 4.108km
Pipeline Length (km) 4.11 km Outside Diameter (m) 0.324 mInternal Diameter (m) 0.283 m Pipeline Lay UnrestrainedTotal Vol. (imp. gals) 5.67E+04 I.gal Total Volume (m³) 257.9 m³Volume per ft (gals) 4.21 gal Vol. per metre (m³) 0.063 m³Total Volume (ft³) 9.11E+03 ft³ Vol. per metre (ft³) 2.22 ft³
PIGGING PARAMETERS Fill fluid : Water Salinity : 3.5 %
Pig Differential BarPigging Speed (m/s) 0.50 Pump Rate (m³/min) 1.88
Head Loss (metres) 3.30Friction Factor 0.017826732 Reynolds Number 109326
Pressure Drop At Pigging Speed 5.0 psi = 0.35 bar
Chemical Additive Injection Rates
Chemical p.p.m. Injection Rate (litres/min)1 Ihibitor 1000.0 1.8832 Tracer dye 50.0 0.09434
PRESSURE TEST PARAMETERS Test press. 423.0 bar gTemp. 4.0 'C
Volume to pressurise pipeline : 5.430 m³ Corresponding Inlet (0-bar) Volume : 5.530 m³Volume change per bar at test pressure : 12.12 litres
Temp Compressibility Coeff Expan. Pressure changeº C (bar)¯¹ (deg C)¯¹ bar/ºC
4.14E-05 1.85E-04 3.120.7 4.13E-05 1.89E-04 3.211.4 4.11E-05 1.93E-04 3.292.1 4.10E-05 1.96E-04 3.382.8 4.09E-05 2.00E-04 3.473.3 4.08E-05 2.03E-04 3.534.0 4.06E-05 2.06E-04 3.614.0 (Test) 4.06E-05 2.06E-04 3.61
Average pressure change per degree C (bar): 3.37Fraction of external pressure added internally: 0.154
SNEPCO-BMIP-BNW and Saipem Consortium – led by SCNL.
Document No.:
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 86 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.
6.8 Valve Status Checksheet
Production Flowlines valve status for FCG/Hydrotest/Handover
Note: All valves are ROV operable
SNEPCO-BMIP-BNW and Saipem Consortium – led by SCNL.
Document No.:
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 87 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.
Water Injection Flowlines valve status for FCG/Hydrotest/Handover
Note: All valves are ROV operable
Flowline Characteristics
Production Flowline Characteristics
SNEPCO-BMIP-BNW and Saipem Consortium – led by SCNL.
Document No.:
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 88 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.
Water Injection Flowline Characteristics
SNEPCO-BMIP-BNW and Saipem Consortium – led by SCNL.
Document No.:
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 89 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.
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
3/4" HOSE CONNECTION
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
3/4" HOSE CONNECTION
SPHU
CF-01
CF-02
FILTER
PRV
3/4" HOSE CONNECTION
CHEMICALBAG
LPV-01
FILTERS
INLET
CHEMICALFILL POINTS
OUTLET
ROV INTERFACE
HALLIBURTON
0 12-11-12 FIRST ISSUE R.M C.E.
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
0 12-11-12 FIRST ISSUE R.M C.E.
DRAWINGSIZENTS UK-120059-DR-010
CHEMICAL TRANSFEREQUIPMENT SETUP
A3
SNEPCO-BMIP-BNW and Saipem Consortium – led by SCNL.
Document No.:
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 90 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.
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.
RISK ASSESSMENT Title:
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 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
P R O B A B I L 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
• Bodily injury P III B 2
• Proper Techniques • Refuse Unsafe Work • Use More People where possible • Balance the loads • Use Tag/Securing lines
III C 3
RISK ASSESSMENT Title:
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 August 09
REV. NO: 0
PAGE: 3 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
P R O B A B I L 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
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
• Bodily injury P III B 2
• 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
RISK ASSESSMENT Title:
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 August 09
REV. NO: 0
PAGE: 4 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
P R O B A B I L 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
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:
Pipeline & Process Services OWNER:
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
RISK ANALYSIS MATRIX
Potential Consequences Probability Rating
Hazard Severity Category
Descriptive Word
Personal Illness/ Injury
Equipment Loss(s)
Environmental (Any incident that…)
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
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 Toolbox Talk Checklist FO-UK-HAL-PPS-401 to acknowledge that they been involved the risk assessment review of the job.
RISK ASSESSMENT Title:
PIPELINE – COMMUNICATIONHALLIBURTON MANAGEMENT SYSTEM
DOCUMENT NUMBER:
RA-GL-HAL-PPS-405 REGION:
Global FUNCTION/PSL:
Pipeline & Process Services OWNER:
B&C HMS Coordinator APPROVED BY: Steve Arrington
REVISION BY: Malcolm MacMillan
REV. DATE: 01.09.11
REV. NO: 0
PAGE: 2 of 3
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
P R O B A B I L I T Y
R P C
A C C E P T A B L E
TARGETS: P – PEOPLE E – EQUIPMENT ENV – ENVIRONMENTAL DT – DOWNTIME M – MATERIALS
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
RISK ASSESSMENT Title:
PIPELINE – COMMUNICATIONHALLIBURTON MANAGEMENT SYSTEM
DOCUMENT NUMBER:
RA-GL-HAL-PPS-405 REGION:
Global FUNCTION/PSL:
Pipeline & Process Services OWNER:
B&C HMS Coordinator APPROVED BY: Steve Arrington
REVISION BY: Malcolm MacMillan
REV. DATE: 01.09.11
REV. NO: 0
PAGE: 3 of 3
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
P R O B A B I L I T Y
R P C
A C C E P T A B L E
TARGETS: P – PEOPLE E – EQUIPMENT ENV – ENVIRONMENTAL DT – DOWNTIME M – MATERIALS
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:
RA-GL-HAL-PPS-406 REGION:
Global FUNCTION/PSL:
Pipeline & Process Services OWNER:
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
RISK ANALYSIS MATRIX
Potential Consequences Probability Rating
Hazard Severity Category
Descriptive Word
Personal Illness/ Injury
Equipment Loss(s)
Environmental (Any incident that…)
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
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 Toolbox Talk Checklist FO-UK-HAL-PPS-401 to acknowledge that they been involved the risk assessment review of the job.
Title:
PIPELINE – ENVIRONMENTHALLIBURTON MANAGEMENT SYSTEM
DOCUMENT NUMBER:
RA-GL-HAL-PPS-406 REGION:
Global FUNCTION/PSL:
Pipeline & Process Services OWNER:
B&C HMS Coordinator APPROVED BY: Steve Arrington
REVISION BY: Malcolm MacMillan
REV. DATE: 01.SEPT.2011
REV. NO: 1.0
PAGE: 2 of 3
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
P R O B A B I L I T Y
R P C
A C C E P T A B L E TASK HAZARD
HAZARD EFFECT
ENVIRONMENTAL ASPECT & IMPACT
TARGETS: P – PEOPLE E – EQUIPMENT ENV – ENVIRONMENTAL DT – DOWNTIME M – MATERIALS
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:
PIPELINE – ENVIRONMENTHALLIBURTON MANAGEMENT SYSTEM
DOCUMENT NUMBER:
RA-GL-HAL-PPS-406 REGION:
Global FUNCTION/PSL:
Pipeline & Process Services OWNER:
B&C HMS Coordinator APPROVED BY: Steve Arrington
REVISION BY: Malcolm MacMillan
REV. DATE: 01.SEPT.2011
REV. NO: 1.0
PAGE: 3 of 3
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
P R O B A B I L I T Y
R P C
A C C E P T A B L E TASK HAZARD
HAZARD EFFECT
ENVIRONMENTAL ASPECT & IMPACT
TARGETS: P – PEOPLE E – EQUIPMENT ENV – ENVIRONMENTAL DT – DOWNTIME M – MATERIALS
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
Title:
PIPELINE – RIG-UP EQUIPMENTHALLIBURTON MANAGEMENT SYSTEM
DOCUMENT NUMBER:
RA-GL-HAL-PPS-407 REGION:
Global FUNCTION/PSL:
Pipeline & Process Services OWNER:
B&C HMS Coordinator APPROVED BY: Steve Arrington
REVISION BY: Malcolm MacMillan
REV. DATE: 01.SEPT.2011
REV. NO: 1.0
PAGE: 1 of 5
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
I 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
II 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
III 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
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 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 Toolbox Talk Checklist FO-UK-HAL-PPS-401 to acknowledge that they been involved the risk assessment review of the job.
RISK ASSESSMENT
Title:
PIPELINE – RIG-UP EQUIPMENT HALLIBURTON MANAGEMENT SYSTEM
DOCUMENT NUMBER:
RA-GL -HAL-PPS-407 REGION:
Global FUNCTION/PSL:
Pipeline & Process Services
OWNER: B&C HMS Coordinator
APPROVED BY: Steve Arrington
REVISION BY: Malcolm MacMillan
REV. DATE: 01.SEPT.2011
REV. NO: 1.0
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
P R O B A B I L I T Y
R P C
A C C E P T A B L E TASK HAZARD
HAZARD EFFECT
ENVIRONMENTAL ASPECT & IMPACT
TARGETS: P – PEOPLE E – EQUIPMENT ENV – ENVIRONMENTAL DT – DOWNTIME M – MATERIALS
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:
PIPELINE – RIG-UP EQUIPMENT HALLIBURTON MANAGEMENT SYSTEM
DOCUMENT NUMBER:
RA-GL -HAL-PPS-407 REGION:
Global FUNCTION/PSL:
Pipeline & Process Services
OWNER: B&C HMS Coordinator
APPROVED BY: Steve Arrington
REVISION BY: Malcolm MacMillan
REV. DATE: 01.SEPT.2011
REV. NO: 1.0
PAGE: 3 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
P R O B A B I L I T Y
R P C
A C C E P T A B L E TASK HAZARD
HAZARD EFFECT
ENVIRONMENTAL ASPECT & IMPACT
TARGETS: P – PEOPLE E – EQUIPMENT ENV – ENVIRONMENTAL DT – DOWNTIME M – MATERIALS
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:
PIPELINE – RIG-UP EQUIPMENT HALLIBURTON MANAGEMENT SYSTEM
DOCUMENT NUMBER:
RA-GL -HAL-PPS-407 REGION:
Global FUNCTION/PSL:
Pipeline & Process Services
OWNER: B&C HMS Coordinator
APPROVED BY: Steve Arrington
REVISION BY: Malcolm MacMillan
REV. DATE: 01.SEPT.2011
REV. NO: 1.0
PAGE: 4 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
P R O B A B I L I T Y
R P C
A C C E P T A B L E TASK HAZARD
HAZARD EFFECT
ENVIRONMENTAL ASPECT & IMPACT
TARGETS: P – PEOPLE E – EQUIPMENT ENV – ENVIRONMENTAL DT – DOWNTIME M – MATERIALS
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 – RIG-DOWN EQUIPMENT & BACKLOADHALLIBURTON MANAGEMENT SYSTEM
DOCUMENT NUMBER:
RA-GL-HAL-PPS-408 REGION:
Global FUNCTION/PSL:
Pipeline & Process Services OWNER:
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
RISK ANALYSIS MATRIX
Potential Consequences Probability Rating
Hazard Severity Category
Descriptive Word
Personal Illness/ Injury
Equipment Loss(s)
Environmental (Any incident that…)
A Frequent
BReasonably
Probable
C Occasional
D Remote
EExtremely
Improbable
F Impossible
I 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
II 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
III 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
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 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 Toolbox Talk Checklist FO-UK-HAL-PPS-401 to acknowledge that they been involved the risk assessment review of the job.
RISK ASSESSMENT
Title:
PIPELINE – RIG-DOWN EQUIPMENT & BACKLOADHALLIBURTON MANAGEMENT SYSTEM
DOCUMENT NUMBER:
RA-GL-HAL-PPS-408 REGION:
Global FUNCTION/PSL:
Pipeline & Process Services OWNER:
B&C HMS Coordinator APPROVED BY: Steve Arrington
REVISION BY: Malcolm MacMillan
REV. DATE: 01.SEPT.2011
REV. NO: 1.0
PAGE: 2 of 3
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
P R O B A B I L I T Y
R P C
A C C E P T A B L E TASK HAZARD
HAZARD EFFECT
ENVIRONMENTAL ASPECT & IMPACT
TARGETS: P – PEOPLE E – EQUIPMENT ENV – ENVIRONMENTAL DT – DOWNTIME M – MATERIALS
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:
PIPELINE – RIG-DOWN EQUIPMENT & BACKLOADHALLIBURTON MANAGEMENT SYSTEM
DOCUMENT NUMBER:
RA-GL-HAL-PPS-408 REGION:
Global FUNCTION/PSL:
Pipeline & Process Services OWNER:
B&C HMS Coordinator APPROVED BY: Steve Arrington
REVISION BY: Malcolm MacMillan
REV. DATE: 01.SEPT.2011
REV. NO: 1.0
PAGE: 3 of 3
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
P R O B A B I L I T Y
R P C
A C C E P T A B L E TASK HAZARD
HAZARD EFFECT
ENVIRONMENTAL ASPECT & IMPACT
TARGETS: P – PEOPLE E – EQUIPMENT ENV – ENVIRONMENTAL DT – DOWNTIME M – MATERIALS
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
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 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:
RA-UK-HAL-PPS-456 REGION:
Europe West Africa FUNCTION/PSL:
Pipeline & Process Services OWNER:
Douglas Wood APPROVED BY:
Alan Clunie REVISION BY:
ID Obott REV. DATE: 1st June 2012
REV. NO: 01
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
I 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
II 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
III 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
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
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 Toolbox Talk Checklist FO-UK-HAL-PPS-401 to acknowledge that they been involved the risk assessment review of the job.
RISK ASSESSMENT Title:
PIPELINE SPU – (SPHU Pipeline Hydrotest)HALLIBURTON MANAGEMENT SYSTEM
DOCUMENT NUMBER:
RA-UK-HAL-PPS-456 REGION:
Europe West Africa FUNCTION/PSL:
Pipeline & Process Services OWNER:
Douglas Wood APPROVED BY:
Alan Clunie REVISION BY:
ID Obott REV. DATE: 1st June 2012
REV. NO: 01
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
P R O B A B I L I T Y
R P C
A C C E P T A B L E
TASK HAZARD
HAZARD EFFECT
ENVIRONMENTAL ASPECT & IMPACT
TARGETS: P – PEOPLE E – EQUIPMENT ENV – ENVIRONMENTAL DT – DOWNTIME M – MATERIALS
RISK ASSESSMENT REVIEW CARRIED OUT BY: A Clunie, D Wood, T Connolly, E Emea, J Lee, M Holmes, I Obott. DATE: 01/06/12
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
RISK ASSESSMENT Title:
PIPELINE SPU – (SPHU Pipeline Hydrotest)HALLIBURTON MANAGEMENT SYSTEM
DOCUMENT NUMBER:
RA-UK-HAL-PPS-456 REGION:
Europe West Africa FUNCTION/PSL:
Pipeline & Process Services OWNER:
Douglas Wood APPROVED BY:
Alan Clunie REVISION BY:
ID Obott REV. DATE: 1st June 2012
REV. NO: 01
PAGE: 3 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
P R O B A B I L I T Y
R P C
A C C E P T A B L E
TASK HAZARD
HAZARD EFFECT
ENVIRONMENTAL ASPECT & IMPACT
TARGETS: P – PEOPLE E – EQUIPMENT ENV – ENVIRONMENTAL DT – DOWNTIME M – MATERIALS
RISK ASSESSMENT REVIEW CARRIED OUT BY: A Clunie, D Wood, T Connolly, E Emea, J Lee, M Holmes, I Obott. DATE: 01/06/12
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
RISK ASSESSMENT Title:
PIPELINE SPU – (SPHU Pipeline Hydrotest)HALLIBURTON MANAGEMENT SYSTEM
DOCUMENT NUMBER:
RA-UK-HAL-PPS-456 REGION:
Europe West Africa FUNCTION/PSL:
Pipeline & Process Services OWNER:
Douglas Wood APPROVED BY:
Alan Clunie REVISION BY:
ID Obott REV. DATE: 1st June 2012
REV. NO: 01
PAGE: 4 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
P R O B A B I L I T Y
R P C
A C C E P T A B L E
TASK HAZARD
HAZARD EFFECT
ENVIRONMENTAL ASPECT & IMPACT
TARGETS: P – PEOPLE E – EQUIPMENT ENV – ENVIRONMENTAL DT – DOWNTIME M – MATERIALS
RISK ASSESSMENT REVIEW CARRIED OUT BY: A Clunie, D Wood, T Connolly, E Emea, J Lee, M Holmes, I Obott. DATE: 01/06/12
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 ASSESSMENTTitle:
PIPELINE – WORKING AT HEIGHTHALLIBURTON MANAGEMENT SYSTEM
DOCUMENT NUMBER:
RA-GL-HAL-PPS-445 REGION:
Global FUNCTION/PSL:
Pipeline & Process Services OWNER:
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
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
I 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
II 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
III 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
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 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 Toolbox Talk Checklist FO-UK-HAL-PPS-401 to acknowledge that they been involved the risk assessment review of the job.
RISK ASSESSMENT
Title:
PIPELINE – WORKING AT HEIGHTHALLIBURTON MANAGEMENT SYSTEM
DOCUMENT NUMBER:
RA-GL-HAL-PPS-445 REGION:
Global FUNCTION/PSL:
Pipeline & Process Services OWNER:
B&C HMS Coordinator APPROVED BY: Steve Arrington
REVISION BY: Malcolm MacMillan
REV. DATE: 01.SEPT.2011
REV. NO: 1.0
PAGE: 2 of 3
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
P R O B A B I L I T Y
R P C
A C C E P T A B L E TASK HAZARD
HAZARD EFFECT
ENVIRONMENTAL ASPECT & IMPACT
TARGETS: P – PEOPLE E – EQUIPMENT ENV – ENVIRONMENTAL DT – DOWNTIME M – MATERIALS
Climbing to height
Falls from height Dropped objects
Personal injury Damage to plant and
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
Personal injury Damage to plant and
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 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 Flooding)HALLIBURTON MANAGEMENT SYSTEM
DOCUMENT NUMBER:
RA-UK-HAL-PPS-455 REGION:
Europe West Africa FUNCTION/PSL:
Pipeline & Process Services OWNER:
Douglas Wood APPROVED BY:
Alan Clunie REVISION BY:
ID Obott REV. DATE: 1st June 2012
REV. NO: 01
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
I 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
II 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
III 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
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
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 Toolbox Talk Checklist FO-UK-HAL-PPS-401 to acknowledge that they been involved the risk assessment review of the job.
RISK ASSESSMENT Title:
PIPELINE SPU – (SPHU Pipeline Flooding)HALLIBURTON MANAGEMENT SYSTEM
DOCUMENT NUMBER:
RA-UK-HAL-PPS-455 REGION:
Europe West Africa FUNCTION/PSL:
Pipeline & Process Services OWNER:
Douglas Wood APPROVED BY:
Alan Clunie REVISION BY:
ID Obott REV. DATE: 1st June 2012
REV. NO: 01
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
P R O B A B I L I T Y
R P C
A C C E P T A B L E
TASK HAZARD
HAZARD EFFECT
ENVIRONMENTAL ASPECT & IMPACT
TARGETS: P – PEOPLE E – EQUIPMENT ENV – ENVIRONMENTAL DT – DOWNTIME M – MATERIALS
RISK ASSESSMENT REVIEW CARRIED OUT BY: A Clunie, D Wood, T Connolly, E Emea, J Lee, M Holmes, I Obott. DATE: 01/06/12
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
RISK ASSESSMENT Title:
PIPELINE SPU – (SPHU Pipeline Flooding)HALLIBURTON MANAGEMENT SYSTEM
DOCUMENT NUMBER:
RA-UK-HAL-PPS-455 REGION:
Europe West Africa FUNCTION/PSL:
Pipeline & Process Services OWNER:
Douglas Wood APPROVED BY:
Alan Clunie REVISION BY:
ID Obott REV. DATE: 1st June 2012
REV. NO: 01
PAGE: 3 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
P R O B A B I L I T Y
R P C
A C C E P T A B L E
TASK HAZARD
HAZARD EFFECT
ENVIRONMENTAL ASPECT & IMPACT
TARGETS: P – PEOPLE E – EQUIPMENT ENV – ENVIRONMENTAL DT – DOWNTIME M – MATERIALS
RISK ASSESSMENT REVIEW CARRIED OUT BY: A Clunie, D Wood, T Connolly, E Emea, J Lee, M Holmes, I Obott. DATE: 01/06/12
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.
RISK ASSESSMENT Title:
PIPELINE SPU – (SPHU Pipeline Flooding)HALLIBURTON MANAGEMENT SYSTEM
DOCUMENT NUMBER:
RA-UK-HAL-PPS-455 REGION:
Europe West Africa FUNCTION/PSL:
Pipeline & Process Services OWNER:
Douglas Wood APPROVED BY:
Alan Clunie REVISION BY:
ID Obott REV. DATE: 1st June 2012
REV. NO: 01
PAGE: 4 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
P R O B A B I L I T Y
R P C
A C C E P T A B L E
TASK HAZARD
HAZARD EFFECT
ENVIRONMENTAL ASPECT & IMPACT
TARGETS: P – PEOPLE E – EQUIPMENT ENV – ENVIRONMENTAL DT – DOWNTIME M – MATERIALS
RISK ASSESSMENT REVIEW CARRIED OUT BY: A Clunie, D Wood, T Connolly, E Emea, J Lee, M Holmes, I Obott. DATE: 01/06/12
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 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 Pre-mobilisation & Pre-Deployment)HALLIBURTON MANAGEMENT SYSTEM
DOCUMENT NUMBER:
RA-UK-HAL-PPS-453 REGION:
Europe West Africa FUNCTION/PSL:
Pipeline & Process Services OWNER:
Douglas Wood APPROVED BY:
Alan Clunie REVISION BY:
ID Obott REV. DATE: 1st June 2012
REV. NO: 01
PAGE: 1 of 6
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
I 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
II 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
III 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
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
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 Toolbox Talk Checklist FO-UK-HAL-PPS-401 to acknowledge that they been involved the risk assessment review of the job.
RISK ASSESSMENT Title:
PIPELINE SPU – (SPHU Pre-mobilisation & SPHU Pre-Deployment)HALLIBURTON MANAGEMENT SYSTEM
DOCUMENT NUMBER:
RA-UK-HAL-PPS-453 REGION:
Europe West Africa FUNCTION/PSL:
Pipeline & Process Services OWNER:
Douglas Wood APPROVED BY:
Alan Clunie REVISION BY:
ID Obott REV. DATE: 1st June 2012
REV. NO: 01
PAGE: 2 of 6
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
P R O B A B I L I T Y
R P C
A C C E P T A B L E
TASK HAZARD
HAZARD EFFECT
ENVIRONMENTAL ASPECT & IMPACT
TARGETS: P – PEOPLE E – EQUIPMENT ENV – ENVIRONMENTAL DT – DOWNTIME M – MATERIALS
RISK ASSESSMENT REVIEW CARRIED OUT BY: A Clunie, D Wood, T Connolly, E Emea, J Lee, M Holmes, I Obott. DATE: 01/06/12
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.
RISK ASSESSMENT Title:
PIPELINE SPU – (SPHU Pre-mobilisation & SPHU Pre-Deployment)HALLIBURTON MANAGEMENT SYSTEM
DOCUMENT NUMBER:
RA-UK-HAL-PPS-453 REGION:
Europe West Africa FUNCTION/PSL:
Pipeline & Process Services OWNER:
Douglas Wood APPROVED BY:
Alan Clunie REVISION BY:
ID Obott REV. DATE: 1st June 2012
REV. NO: 01
PAGE: 3 of 6
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
P R O B A B I L I T Y
R P C
A C C E P T A B L E
TASK HAZARD
HAZARD EFFECT
ENVIRONMENTAL ASPECT & IMPACT
TARGETS: P – PEOPLE E – EQUIPMENT ENV – ENVIRONMENTAL DT – DOWNTIME M – MATERIALS
RISK ASSESSMENT REVIEW CARRIED OUT BY: A Clunie, D Wood, T Connolly, E Emea, J Lee, M Holmes, I Obott. DATE: 01/06/12
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.
RISK ASSESSMENT Title:
PIPELINE SPU – (SPHU Pre-mobilisation & SPHU Pre-Deployment)HALLIBURTON MANAGEMENT SYSTEM
DOCUMENT NUMBER:
RA-UK-HAL-PPS-453 REGION:
Europe West Africa FUNCTION/PSL:
Pipeline & Process Services OWNER:
Douglas Wood APPROVED BY:
Alan Clunie REVISION BY:
ID Obott REV. DATE: 1st June 2012
REV. NO: 01
PAGE: 4 of 6
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
P R O B A B I L I T Y
R P C
A C C E P T A B L E
TASK HAZARD
HAZARD EFFECT
ENVIRONMENTAL ASPECT & IMPACT
TARGETS: P – PEOPLE E – EQUIPMENT ENV – ENVIRONMENTAL DT – DOWNTIME M – MATERIALS
RISK ASSESSMENT REVIEW CARRIED OUT BY: A Clunie, D Wood, T Connolly, E Emea, J Lee, M Holmes, I Obott. DATE: 01/06/12
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.
RISK ASSESSMENT Title:
PIPELINE SPU – (SPHU Pre-mobilisation & SPHU Pre-Deployment)HALLIBURTON MANAGEMENT SYSTEM
DOCUMENT NUMBER:
RA-UK-HAL-PPS-453 REGION:
Europe West Africa FUNCTION/PSL:
Pipeline & Process Services OWNER:
Douglas Wood APPROVED BY:
Alan Clunie REVISION BY:
ID Obott REV. DATE: 1st June 2012
REV. NO: 01
PAGE: 5 of 6
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
P R O B A B I L I T Y
R P C
A C C E P T A B L E
TASK HAZARD
HAZARD EFFECT
ENVIRONMENTAL ASPECT & IMPACT
TARGETS: P – PEOPLE E – EQUIPMENT ENV – ENVIRONMENTAL DT – DOWNTIME M – MATERIALS
RISK ASSESSMENT REVIEW CARRIED OUT BY: A Clunie, D Wood, T Connolly, E Emea, J Lee, M Holmes, I Obott. DATE: 01/06/12
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
RISK ASSESSMENT Title:
PIPELINE SPU – (SPHU Pre-mobilisation & SPHU Pre-Deployment)HALLIBURTON MANAGEMENT SYSTEM
DOCUMENT NUMBER:
RA-UK-HAL-PPS-453 REGION:
Europe West Africa FUNCTION/PSL:
Pipeline & Process Services OWNER:
Douglas Wood APPROVED BY:
Alan Clunie REVISION BY:
ID Obott REV. DATE: 1st June 2012
REV. NO: 01
PAGE: 6 of 6
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
P R O B A B I L I T Y
R P C
A C C E P T A B L E
TASK HAZARD
HAZARD EFFECT
ENVIRONMENTAL ASPECT & IMPACT
TARGETS: P – PEOPLE E – EQUIPMENT ENV – ENVIRONMENTAL DT – DOWNTIME M – MATERIALS
RISK ASSESSMENT REVIEW CARRIED OUT BY: A Clunie, D Wood, T Connolly, E Emea, J Lee, M Holmes, I Obott. DATE: 01/06/12
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 – WORKING AT HEIGHTHALLIBURTON MANAGEMENT SYSTEM
DOCUMENT NUMBER:
RA-GL-HAL-PPS-445 REGION:
Global FUNCTION/PSL:
Pipeline & Process Services OWNER:
B&C HMS Coordinator APPROVED BY: Steve Arrington
REVISION BY: Malcolm MacMillan
REV. DATE: 01.SEPT.2011
REV. NO: 1.0
PAGE: 3 of 3
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
P R O B A B I L I T Y
R P C
A C C E P T A B L E TASK HAZARD
HAZARD EFFECT
ENVIRONMENTAL ASPECT & IMPACT
TARGETS: P – PEOPLE E – EQUIPMENT ENV – ENVIRONMENTAL DT – DOWNTIME M – MATERIALS
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
SNEPCO-BMIP-BNW and Saipem Consortium – led by SCNL.
Document No.:
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 91 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.
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
Halliburton Management System Document Number:
FO-GL-HAL-PPS-402 Region: Global
Function/PSL: Pipeline and Process Services
Owner: Global PE HMS Coord
Approved By: Steve Arrington
Job Revision By: Amy Edwards
Rev Date: 22/12/08
Rev No: 1
Page: 1 of 4
Once printed this form is uncontrolled, refer to HMS for controlled copy
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
Title: Site Pre-Job Briefing Checklist
Halliburton Management System Document Number:
FO-GL-HAL-PPS-402 Region: Global
Function/PSL: Pipeline and Process Services
Owner: Global PE HMS Coord
Approved By: Steve Arrington
Job Revision By: Amy Edwards
Rev Date: 22/12/08
Rev No: 1
Page: 2 of 4
Once printed this form is uncontrolled, refer to HMS for controlled copy
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
Title: Site Pre-Job Briefing Checklist
Halliburton Management System Document Number:
FO-GL-HAL-PPS-402 Region: Global
Function/PSL: Pipeline and Process Services
Owner: Global PE HMS Coord
Approved By: Steve Arrington
Job Revision By: Amy Edwards
Rev Date: 22/12/08
Rev No: 1
Page: 3 of 4
Once printed this form is uncontrolled, refer to HMS for controlled copy
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
Title: Site Pre-Job Briefing Checklist
Halliburton Management System Document Number:
FO-GL-HAL-PPS-402 Region: Global
Function/PSL: Pipeline and Process Services
Owner: Global PE HMS Coord
Approved By: Steve Arrington
Job Revision By: Amy Edwards
Rev Date: 22/12/08
Rev No: 1
Page: 4 of 4
Once printed this form is uncontrolled, refer to HMS for controlled copy
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
Page 1 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
Halliburton Management System Document Number:
FO-GL-HAL-PPS-401 Region: Global
Function/PSL: Pipeline and Process Services
Owner: Global PE HMS Coord
Approved By: Steve Arrington
Job Revision By: Amy Edwards
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
Halliburton Management System Document Number:
FO-GL-HAL-PPS-401 Region: Global
Function/PSL: Pipeline and Process Services
Owner: Global PE HMS Coord
Approved By: Steve Arrington
Job Revision By: Amy Edwards
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
Halliburton Management System Document Number:
FO-GL-HAL-PPS-604 Region: Global
Function/PSL: Pipeline and Process Services
Owner: Global PE HMS Coord
Approved By: Steve Arrington
Job Revision By: Amy Edwards
Rev Date: 22/12/08
Rev No: 1
Page: 1 of 1
Once printed this form is uncontrolled, refer to HMS for controlled copy
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
Halliburton Management System Document Number:
FO-GL-HAL-PPS-115 Region: Global
Function/PSL: Pipeline and Process Services
Owner: PPS HMS Coordinator
Approved By: Steve Arrington
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:
Once printed this form is uncontrolled, refer to HMS for controlled copy
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
HALLIBURTON MANAGEMENT SYSTEM DOCUMENT NUMBER
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
-
Once printed this form is uncontrolled, refer to HMS for controlled copy
Global PE HMS Coordi
Print Name: Print Name:
Sign: Sign:
For: Date:
Date:
FO-UK-HAL-PPS-428 Rev 5 20th August 09
ONCE PRINTED THIS FORM IS UNCONTROLLED; REFER TO HMS FOR CONTROLLED COPY
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
Pipeline & Process Services
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
HALLIBURTON MANAGEMENT SYSTEM DOCUMENT NUMBER
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:
ONCE PRINTED THIS FORM IS UNCONTROLLED; REFER TO HMS FOR CONTROLLED COPY
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
ONCE PRINTED THIS FORM IS UNCONTROLLED; REFER TO HMS FOR CONTROLLED COPY
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:
Temperature Instrument 2:
Temperature Instrument 3:
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
Halliburton Management System Document Number:
FO-GL-HAL-PPS-501
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 3
Once printed this form is uncontrolled, refer to HMS for controlled copy
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……………….
Initial……………….
Initial……………….
Initial……………….
Initial……………….
Initial……………….
Initial……………….
Initial……………….
Initial……………….
Initial……………….
Initial……………….
Initial……………….
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
Title: Back-load Checksheet
Halliburton Management System Document Number:
FO-GL-HAL-PPS-501
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: 2 of 3
Once printed this form is uncontrolled, refer to HMS for controlled copy
BACKLOAD CHECKLIST - CONTINUATION Serial No
Contents / Description
Length
Width
Height
Weight
(KG)
Backload checklist
complied w ith
Initial……………….
Initial……………….
Initial……………….
Initial……………….
Initial……………….
Initial……………….
Initial……………….
Initial……………….
Initial……………….
Initial……………….
Initial……………….
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
Title: Back-load Checksheet
Halliburton Management System Document Number:
FO-GL-HAL-PPS-501
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: 3 of 3
Once printed this form is uncontrolled, refer to HMS for controlled copy
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
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
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
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
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