Standard Procedures for Underwater Engineering Operations

8/10/2019 Standard Procedures for Underwater Engineering Operations

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Shell Exploration & Production

STANDARD PROCEDURESFOR UNDERWATER

ENGINEERING OPERATIONS





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Re-issue 04/05 (i)

STANDARD PROCEDURES FOR

UNDERWATER ENGINEERING OPERATIONS

CONTENTS

AUTHORITY FOR ISSUE

AUTHORITY FOR AMENDMENT

AMENDMENT RECORD

LIST OF ABBREVIATIONS

PREFACE

AMENDMENT HISTORY

SECTION 1 STANDARD OPERATING PARAMETERS

Chapter 1 Operational Workscopes

Chapter 2 Location/Positioning

Chapter 3 Equipment

Chapter 4 Inspection Operations

Chapter 5 Information Control Centre

SECTION 2 GUIDE TO THE STANDARD PROCEDURES FOR UNDERWATER ENGINEERING

OPERATIONSChapter 1 Introduction

Chapter 2 Standard Procedures

Chapter 3 Method of Use

Chapter 4 Task Coding System and Component Task Sheets

Chapter 5 Procedure & Component Numbering System

Chapter 6 Anomaly Reporting and Criteria

Chapter 7 Reporting

SECTION 3 INSPECTION PROCEDURES (Excluding Pipelines and Risers)

I 01 003 Debris Survey and Recovery

I 01 007 General Video SurveyI 06 001 Seabed Profile and Scour Survey

I 06 003 Linear Profile Scour Survey

I 10 001 Dimensional Damage Survey to Steel Structures

I 15 001 Weld Inspection

I 15 002 Wall Thickness & Ultrasonic Inspection - General

I 15 003 Flooded Member Detection

I 20 001 Concrete Surface and Damage Inspection

I 20 002 General Concrete Surface Inspection - Subsea and Topside

I 30 001 Seawater Inlet Inspection

I 32 001 Boat Landing and Barge Bumper Survey



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I 43 001 Caisson Inspection

I 49 057 Talon Joint Inspection

I 60 004 Cathodic Protection Monitoring

I 97 001 Inspection of Abandoned / Suspended Wellhead

I 97 002 Inspection of Subsea Tree (Production and Water Injection)

SECTION 4 CONSTRUCTION PROCEDURES

R 01 011 Dredging

R 26 001 Installation and Removal of Clamped Blanking Flange

R 48 001 Installation and Removal of Blind Flange

R 48 002 Installation and Removal of Inlet Blanking Plug (ROV

SECTION 5 PIPELINE AND RISER PROCEDURES

I 41 001 Riser and J-Tube Inspection

I 90 001 Valve Assembly Spool Piece (VASP) Inspection

I 90 002 Pipeline Damage Inspection

I 91 001 Igloo Inspection - Fulmar Tee Skid

I 91 002 Subsea Intervention Valve (SSIV) Inspection - Northern Business Units

I 91 003 Igloo Inspection - WELGAS Number 1 and 2

I 91 004 Igloo Inspection - 20 Inch Fulmar 'A' to St Fergus Gas Pipeline

I 91 005 Igloo Inspection - Subsea Umbilical Splitter Box Brent Alpha

Under Review I 91 006 Subsea Intervention Valve (SSIV) Inspection - ONEgas Business Unit

I 91 007 Igloo / Manifold Inspection – General

I 91 008 Igloo Inspection - Brent Spar Manifold - ROV

I 91 009 Igloo Inspection – Osprey to Dunlin A Flowline Bundle Carrier Pipe

I 93 001 Pipeline Protection Cover InspectionI 98 001 Concrete Protection Covers and PBSJ Inspection

NON-STANDARD TASKS

Under Review R 90 003 Pipeline Span Stabilisation

Under Review R 90 053 Installation of Protection Mattresses

APPENDIX 1 REFERENCES





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AMENDMENT RECORD

The signature for each amendment indicates that the amendment was correctly incorporated in accordance withthe Amendment Instruction Sheet.

AMENDMENTNUMBER

PERSON INCORPORATING AMENDMENT INTO MANUALDATE

AMENDED

NAME SIGNATURE DESIGNATION



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LIST OF ABBREVIATIONS

ACFM Alternating Current Field Measurement

ACPD Alternating Current Potential Drop

AS Arc Strike

BA Breathing Apparatus

BCS Burmah Castrol Strip

BDC Bottom Dead Centre

BFU Brent Field Unit

BS British Standards

CGF Conductor Guide Frame

CNS Central North Sea

COABIS Component Oriented Anomaly Based Inspection System

CP Cathodic Protection

CTS Component Task Sheet

CVI Close Visual Inspection

DMC Data Management Controller

DOWS Draft Operational Work Scope

DPR Daily Progress Report

DSV DSV/MSV operating on behalf of UEIP

DV Digital Video

DVD Digital Video Disk

DVI Detailed Visual Inspection

ECI Eddy Current Inspection

EMA Electro Magnetic Array

FMD Flooded Member Detection

FOWS Final Operational Work Scope

GBS Gravity Based Structure

GRP Glass Reinforced Plastic

GVI General Visual Inspection

H2S Hydrogen Sulphide

HAT Highest Astronomical Tide

HAZ Heat Affected Zone

HAZID Hazard Identification

HDM Horizontal Diagonal Member



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HIRA Hazard Identification & Risk Assessment

HM Horizontal Member

HMI Head Mining Installation (OIM Dutch Sector)

IBIS Inspection Based Information System (Pipelines Database)IEC International Electrotechnical Commission

IMCA International Marine Contractors Association

IMR Inspection, Maintenance and Repair

ISO International Organization for Standardization

JPG (JPEG) Joint Photographic Experts Group (Digital Image Format)

JRA Job Risk Assessment

LAM Linear Angular Measurement gauge

LAT Lowest Astronomical Tide

LSA Low Scale Activity

m Metres

mm Millimetres

mV Milli Volts

MGR Marine Growth Removal

MGS Marine Growth Survey

MPG (MPEG) Moving Picture Experts Group (Digital Video Format)

MPI Magnetic Particle Inspection

NFU Northern Field Unit

NDT Non Destructive Testing

NNS Northern North Sea

NUI Normally Unattended Installation

OCM Offshore Construction Manager (Contractor)

OIM Offshore Installation Manager

OM Offshore Manager (Contractor)

OOE Offshore Operations Engineer (Shell Representative)

OWS Operational Work Scope

P&ID Piping & Instrumentation Diagram

PBSJ Pressure Balanced Safety Joints

PEC Pulsed Eddy Current (Wall Thickness Reading System)

PLBM Production Linear Block Manifold

PLEM Pipeline End Manifold



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PM Parent Metal

PON Petroleum Offshore Notification

PSS Platform Services Supervisor

PVC Polyvinyl Chloride

RPS Radiation Protection Supervisor

RC Reinforcement Cap

ROV Remotely Operated Vehicle

ROVSV ROV Support Vessel

SOD Subsea Operations Department

SOE Subsea Operations Engineer

SOW Scope of Work

SROU Surface Read Out Unit

SSIV Sub Sea Intervention Valve

STLB Submerged Turret Loading Buoy

S-VHS Super VHS

SWL Safety Working Load

TA Technical Authority

TDC Top Dead Centre

TRA Task Risk Assessment

UC Undercut

UMC Underwater Manifold Centre

UMDB Underwater Maintenance Data Bank

UT Ultrasonic Thickness (Test)

VASP Valve Assembly Spool Piece

VDM Vertical Diagonal Member

VM Vertical Member

WILBM Water Injection Linear Block Manifold

WRF Work Request Form

WT Wall Thickness

WROV Workclass ROV



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PREFACE

This manual defines the personnel, equipment specifications, procedures, guidance on the detailed planningand execution of procedures involved in the underwater inspection, maintenance and repair of offshore

structures, risers, pipelines and igloos within Shell Exploration & Production Europe (EPE).

The manual is intended to provide information to project, structural and pipeline engineers, and will also be usedto instruct contractors of the requirements for underwater engineering operations. It can be used with or withoutthe Shell adopted computer-based data management systems, COABIS (Component Oriented Anomaly BasedInspection System) and IBIS (Inspection Based Information System), however the numbering and task codingsystems to be used are those based on the COABIS system.

Equipment and techniques for underwater inspection work are continually being developed or changed andtherefore, from time to time, Sections of the manual may be found to be no longer appropriate or in need ofamendment or addition. Where this occurs, comments are to be forwarded to the Custodian.

The manual is divided into five sections providing information on the following;

Section 1 Standard Operating Parameters

This section states the methods to be adopted with respect to:

Chapter 1. The production and use of Operational Workscopes

Chapter 2. Location, Datum and Positioning methods to adopt

Chapter 3. General Construction and Inspection equipment specification, legislation and methodsof use

Chapter 4. Types of inspection carried out, and specifies the distinctions between General,Detailed and Close visual inspections (GVI, DVI & CVI)

Chapter 5. Contractor obligations with respect to providing suitable facilities and involvementoffshore, with respect to data gathering offshore

Section 2 Guide to the Standard Procedures for Underwater Engineering Operations

This section states:

Chapter 1. The reasons why Standard Procedures are adopted by Shell EPE

Chapter 2. Information on - Standard Procedures; production of new Standard Procedures;production of Non-Standard Procedures and Standard Procedures in COABIS

Chapter 3. The method of use of Standard Procedures, and the requirements for production of a

Non-Standard Procedure

Chapter 4. The full list of Shell EPE Tasks codes based on the COABIS task coding system

Chapter 5. How Standard Procedure numbers are obtained, and the full list of Shell underwatercomponent type code numbering

Chapter 6. The method of reporting anomalies, and gives the full list of Shell EPE anomalycriteria

Chapter 7. For all Shell EPE offshore operations conducted - how reports and data gathered areto be submitted; the format of the Job Completion Report to be submitted; the methodof numbering, labelling and format of all types of data gathered; and the format of Job

Closeout Notes



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Section 3 Inspection Procedures (excluding Pipelines and Risers)

This section contains Standard Procedures specific to the inspection of offshore structures bothsteel and concrete, and their appurtenances, excluding Risers, J-Tubes, Pipelines and mostSubsea Facilities.

Section 4 Construction Procedures

This section contains Standard Procedures specific to construction tasks, which are not subject tochanges due to local variations.

Section 5 Pipeline and Riser Procedures

This section contains Standard Procedures specific to the inspection of offshore Risers, J-Tubes,Pipelines and most Subsea Facilities



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Am 05 03/12 (xv)

AMENDMENT HISTORY

Amendment No/Date.

Subject DS Job No

Re-issue 04/05 General Review. 171734

Am 01 05/05 Amended Prelims; Section 2, Contents and Chapter 6; Section 3,Procedure I-43-001; Section 5 Procedures I-90-001, I-91-007 and addedProcedure I-91-002.

173008

Am 02 08/05 Amend Prelims and add Procedure I-97-001 to Section 3. 174989

Am 03 04/06 Amend Prelims and Procedures I 43 001, I 90 001 and I 41 001. AddProcedures I 90 002, I 91 001, I 91 003, I 91 004 to Section 5.

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Am 04 04/08Procedures I 93 001, I 91 005, I 91 008, I 91 009 and I 98 001incorporated into Section 5.

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Am 05 03/12Major changes throughout all of Section 2, Chapter 6 Anomaly Reporting

and Criteria.

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SECTION 1

STANDARD OPERATING PARAMETERS

CONTENTS

CHAPTER 1 OPERATIONAL WORKSCOPES

CHAPTER 2 LOCATION / POSITIONING

CHAPTER 3 EQUIPMENT

CHAPTER 4 INSPECTION OPERATIONS

CHAPTER 5 INFORMATION CONTROL CENTRE

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CHAPTER 1

OPERATIONAL WORKSCOPES

1 INTRODUCTION

Written instructions (termed Operational Workscopes) are required for all field operations undertakenby the Underwater Operations Department. The instructions are written, approved and distributed witha view to achieving the following aims:

(1) The Underwater Operations Work Resource and the Field Unit Facility involved always work toprecise and unambiguous work instructions with all foreseeable requirements defined.

(2) Prior to implementation written instructions are available for review by all parties concerned.

(3) Hazards and control measures are systematically reviewed and refined to precisely targetHealth Safety & Environment instructions to the job.

The recognised categories of instructions and their authors are:

(1) Operational Workscopes authored within the Underwater Operations group, in Consultation withthe Diving Contractor.

(2) Operational Workscopes authored by the Diving Contractor or other Engineering Contractor inconsultation with the Underwater Operations group.

(3) Fast track Operational Workscopes authored by the Underwater Operations group andendorsed by the Diving Contractor and vice versa.

(4) IBIS (Inspection Based Information System) Workscopes that allocate specific underwaterOperations Department Standard Procedures.

(5) Field instructions authored by the Shell Offshore Operations Engineer.

The policy specified in this Chapter covers routine and fast track Operational Workscopes. Theflowchart (see Figure 2) contained at the back of this section, further emphasis the process.

Field generated work procedures are employed only when absolutely necessary for protection oftechnical integrity or to authorise routine jobs of opportunity that are covered by UnderwaterEngineering Operations Standard Procedures, one example being simple cargo lifts. Proceduresgenerated offshore require to be reviewed by the Underwater Operations Focal Point or their deputyprior to implementation.

2 GENERAL INFORMATION AND POLICIES

2.1 Obligation to Read and Comply

Field personnel must familiarise themselves with the instructions and seek clarification, as necessary,prior to starting work.

A TRA will always be carried out offshore prior to commencement of the work. This activity is theoffshore acceptance of the operational workscope.

2.2 Obligation to Report Errors

The Operational Workscope is a vehicle to allow persons within multiple organisations with varied

experience, expectations, viewpoints and locations to agree on a relatively precise sequence of workinstructions. A disciplined approach to work requires that agreed procedures be faithfully executed.

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On occasion new information becomes available, previously unrecognised problems arise, or commonsense begs for a change or deviation of the procedure.

Circumstances will often dictate carrying on with the original instructions. Nevertheless, any and allpersons have an obligation to raise concerns regarding work instructions with their supervisor. 'I was just following the procedure' is an unacceptable excuse for silently proceeding with a work instruction

the person on the job knows to be wrong.

2.3 Management of Changes

Field deviations from the published Operational Workscope are to be documented in writing andprocessed in accordance with the Contractors policy. The appropriate level of supervisory agreementfor the change is always to be obtained in advance. Where additional work is requested by the Shelloffshore operations Engineer a formal request shall be submitted to the Contractor on the vessel (see Additional Work Request Form) and the appropriate level of local change control initiated.

Four levels of change are recognised:

Minor Change Minor change in workscope. The Jobsite Task Risk Assessment (JS-TRA) is not

affected by the change. Approved by the Dive Supervisor.

Local ReviewChange

The existing JS-TRA no longer applies. A new JS-TRA is conducted. Any new hazardsarising from the change are standard hazards routinely addressed in the safety section ofthe workscope. The change does not require another location or facility to change theirplanned activities. The Contractor Operations Superintendent can approve the changefor the Contractor. The Shell Offshore Operations Engineer approves the change oncehe is satisfied it has been handled in accordance with the Contractors procedures andgood practice.

Onshore ReviewChange

The existing JS-TRA no longer applies. A new JS-TRA is conducted. An additionalhazard arising from the change is one known to have particularly hazardous potential(e.g. oxyarc burning), or supporting actions are required from persons not onboard thevessel, or an unanticipated dive is required. The Contractor Operations Superintendent

suggests a change and advises his onshore management of the proposed change. TheShell Offshore Operations Engineer is advised of the proposed change and is satisfied ithas been handled in accordance with the Contractors procedures and good practice. Hemay need to liaise with the Field Unit Facility to support the change. He advises theUnderwater Operations Department of the circumstances.

FundamentalChange

A totally different execution concept is required to accomplish the task. The worksite isfound to be unsafe and it cannot be readily remedied. A new revision of the OperationalWorkscope is required.

It is a matter of judgement as to what category a change falls into. Examples are outlined below forguidance.

Change Appropriate Supervisory Action

Diver finds spanner size isincorrect

Minor Change. Dive Supervisor arranges to have the correctspanner deployed and notes it in the working copy of theWorkscope.

A stud bolt to be removed underthe workscope is found to befrozen tight.

• Cut using hydraulic nut splitter Local review change. The Superintendent and Shell OffshoreOperations Engineer are notified. A JS-TRA is conducted toassess occurrence and control of all potential hazards arisingfrom use of the hydraulic nut splitter. The change is approved bythe Superintendent and the discussion minuted.

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The Shell Offshore Operations Engineer approves that change,satisfied that the Contractors own procedures and good practicehave been observed in addressing the change.

The work can proceed. Dive Supervisor arranges to have thecorrect nut splitter deployed and notes it in the working copy of

the Workscope. Change control document included in the finalreport.

• Cut using abrasive disk Local review change. The Superintendent and Shell OffshoreOperations Engineer are notified. A JS-TRA is conducted toassess occurrence and control of all potential hazards arisingfrom use of the cutting tool. The change is approved by theSuperintendent and the discussion minuted.

The Shell Offshore Operations Engineer approves that change,satisfied that the Contractors own procedures and good practicehave been observed in addressing the change. The work canproceed. Dive Supervisor arranges to have the correct abrasivedisk deployed and notes it in the working copy of the Workscope.

Change control document included in the final report.• Cut using Oxy-arc burning Onshore Review Change. Oxy-arc burning is known to have

significant hazardous potential.

Dive Supervisor finds work accessrequires 35m of diver tether.

Local Review Change. Use of an umbilical longer than 30m ismentioned in the Workscope Diving hazards list. TheSuperintendent and Shell Offshore Operations Engineer arenotified. A JS-TRA is conducted to assess occurrence andcontrol of all potential hazards arising from use of a longer tether.The change is approved by the Superintendent and thediscussion minuted. The Shell Offshore Operations Engineerapproves that change, satisfied that the Contractors ownprocedures and good practice have been observed in addressing

the change. The work can proceed. A ROV job cannot proceed due todebris that must be removed bydivers

Local Review Change. The Superintendent and Shell OffshoreOperations Engineer are notified of the problem. The situation isdiscussed onboard and a plan to utilise divers to remove thedebris is agreed. A JS-TRA is conducted and the risks have beenmitigated to ALARP. The need for this dive was not anticipated inthe Workscope, not even as a contingency. The UnderwaterOperations Focal Point onshore is advised of the divingrequirement.

A ROV job adjacent to a seawaterinlet cannot be completed by theROV. The inlet cannot be idled.

Local Review Change. The Underwater Operations Focal Pointonshore is notified the work cannot be safely completed asplanned. A new or revised Workscope is required.

2.4 Document Contro l

Copies of the latest version of all Operational Workscopes or other job instructions are held in theDepartment job files, even if fieldwork is never undertaken. Job file copies of Draft OperationalWorkscopes are discarded upon completion of fieldwork.

All Operational Workscope transmittals are made through the Underwater Operations Department.Whenever a Workscope document (OOWS, DOWS or FOWS) is sent to an addressee outside theunderwater Operations Department, a document transmittal is prepared by the Shell onshore database controller. Document transmittals are logged on a computerised database to allow easy review ofthe status of a given Operational Workscope. Preparation and loading of document transmittals iscarried out by the data base controller.

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All procedures, drawings etc shall be supplied in electronic format. ‘Livelink’ shall be used as theonline document database providing electronic storage and access for documents and procedures.

2.5 Timely Completion of Operational Workscopes

Final Operational Workscopes are to be approved, published and ready for transmittal offshore no less

than two weeks prior to job execution as scheduled in the Four-Week-Look ahead. If this deadlinecannot be met utilising routine mail circulation of approval copies, consideration should be made tohand carry or to use ‘Livelink’ to electronically transmit workscopes in order to expeditiously secure therequired approvals and ensure the workscope is distributed.

3 OPERATIONAL WORKSCOPE SEQUENCE OF PREPARATION

3.1 Initiation of Work (Work Registration Form)

Active Operational Workscope preparation begins on a job once a Sponsor submits a WorkRegistration Form.

The WRF must be fully completed by the job sponsor and should include all necessary budget

approvals. The work registration is reviewed by the underwater Operations Focal Point, who willassign a Job Leader (i.e. one of the Underwater Operations Engineers) to the work and decide ifcircumstances dictate use of a Fast track Operational Workscope. Any conditions of acceptance arenoted on the form and the endorsed copy is returned to the Sponsor.

A COABIS ‘Cost Code’ (Job Number, See Section 7 below) is raised by the COABIS DatabaseController. The Job Leader is responsible for ensuring written instructions are authored, reviewed andcirculated in accordance with the department policy. Operational Workscopes are generally preparedby or under the supervision of the Job Leader.

3.2 Sponsor Scope of Work (SSOW)

Once the requirement for work has been identified the Job Leader confers with the Sponsor and

provides guidance to aid the Sponsor in preparing a Sponsor Scope of Work (SSOW). The scope isstructured to utilise Standard Procedures or previous similar jobs insofar as possible. Detail is addeduntil the Job Leader is satisfied that he has sufficient understanding of the sponsor's requirements tomake his own Outline or Fast track Workscope.

Information items that must be supplied by Sponsors are:

(1) The objective of the job and operational constraints, i.e. Summary of tasks, method statementetc.

(2) Operating Facility actions for establishing a safe worksite. Typical subjects are isolations ofpressurised piping, electrical equipment, hydraulically actuated equipment, seawater inlets, and

any other remotely controlled facilities,

(3) Information needed to comply with government/asset regulations - Hydrotest pressures,environment issues (i.e. PON), data sheets for chemicals supplied by the Sponsor etc.

(4) Legible A3 size copies of relevant drawings i.e. P&IDs, system and equipment layouts anddetails.

(5) Details of Sponsor supplied equipment, materials, and services.

(6) Asset scheduling, aspirations/constraints.

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3.3 Outline Operational Workscope (OOWS) and Kick Off Meeting

From the information received, if appropriate, the Job Leader will prepare an Outline OperationalWorkscope (OOWS), which contains sufficient information for the Draft Operational Workscope(DOWS), which may (dependant on workload) be produced by the Diving Contractor.

The OOWS will include as a minimum:

(1) The SSOW (including attachments WRF etc. and any other supporting information),

(2) Identification and discussion of diving/ROV hazards and execution constraints (per consultationwith the Underwater Operations Focal Point),

(3) If applicable the allocation of applicable Standard Procedures, or copy of a previous similar job.

(4) Method statement of the job execution concept agreed with the sponsor.

(5) Designs or concept sketches of any installation equipment,

(6) List of illustrations required.

Alternatively a Kick off meeting may be held in lieu of a formal OOWS

Kick of f Meeting

Once the WRF and all the relevant information has been gathered, the Job Leader will hold a kick offmeeting with all interested parties – Sponsor, Dive contractor etc. The purpose of the meeting is todiscuss all aspects of the job, clarifying the workscope, identifying constraints, interfaces, isolations,identifying all necessary information and identifying the relevant action parties.

A method statement and summary of tasks will be a fundamental outcome of the Kick off meeting.

A date for the issue of the DOWS shall also be agreed. This meeting shall be minuted and copies ofthe minutes are to be posted in live link by the job leader

3.4 Draft Operation Workscope (DOWS)

The Diving Contractor prepares the DOWS (Rev. A1) in accordance with Para 4.0 of this Chapter andwithin the agreed time frame. The Job Leader will monitor the timely production of the DOWS andprompt the Diving Contractor as necessary to meet the required schedule. Subsequent revisions ofthe DOWS, will be numbered A2, A3, accordingly. The Job Leader reviews the DOWS prior to it beingsubmitted for official distribution, it is the principal task of the Job Leader to ensure that the DOWS ismature enough to be distributed for review.

Word processing assembly of the Workscope always starts using the current Workscope Template asa foundation.

Once the DOWS is deemed ready for issue (see paragraph above) the Diving Contractor will endorsethe DOWS cover sheet in the relevant approval box prior to submitting it for distribution and review.Consideration can be made to reviewing using ‘Livelink’, and or distributing electronically but alltransmittals must be recorded in the transmittal database. Distribution is defined on the cover sheetand Shell Expro distributions are handled by the Underwater Operations Department.

The commented copies are all routed to the Job Leader for collation of comments. The Job Leader isto resolve conflicting comments before returning the DOWS to the Contractor for revision.

The Job Leader will determine detail/breakdown of the COABIS CTS sheets. This breakdown is to be

agreed will all relevant parties, and any suggested changes discussed with the Underwater OperationsJob Leader. Agreed changes will be implemented by the Job Leader.

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3.5 Hazard Identifi cation & Risk Assessment (HIRA)

A HIRA is a legal requirement. It can be performed at any point that a procedure is deemed to be in arobust state, i.e. at A2, A3 or C1 stage, where no significant changes to the workscope areanticipated. Recommendations from the HIRA may entail changes to the DOWS or FOWS.

This onshore safety meeting is conducted to capture all safety aspects of the work, to evaluate risksand make recommendations on how to mitigate those risks. The results of the HIRA are to be madeavailable for offshore reference. The HIRA is to be chaired by the Diving Contractor, with relevantparties from the Contractor, Shell and any relevant Sub-Contractors to attend. Attendees shouldinclude HSE representatives, Project Engineer, Job Leader, other technical authorities, offshorerepresentatives, diving or ROV personnel, as required.

3.6 Final Operational Workscope (FOWS)

The Dive Contractor reviews and applies the changes requested and forwards one approval copy ofthe FOWS to the underwater Operations Department for circulation (Rev. C1). The Departmentrecords receipt of the FOWS and sends it to the Job Leader. The Job Leader reviews and approvesthe FOWS and is responsible for its final approval cycle.

To expedite processing the FOWS cover sheet can be signed with minor comments and typographicalerrors flagged. Revisions to concept are discouraged and must be rigorously justified. The FOWScover sheet should not be signed if the reviewer believes a concept revision is required or if he judgesa comment or typographical error to be other than 'minor'. Re-submittals should have later revisioncodes (e.g. C2) if copies other than the signature copy are in existence.

The Job Leader returns the original FOWS with signed off cover sheet to the Diving Contractor for finalupdate and publishing. Copies are distributed per an agreed distribution list:

• Currently three copies to onshore Shell Database Controller, and up to 16 copies to theDSV/ROVSV.

3.7 Offshore Receipt

Offshore recipients on the DSV/ROVSV who will execute the job, review the FOWS and conduct aTask Risk Assessment (TRA). In the event an unacceptable flaw is found in the FOWS, work is not toproceed until it is revised either using a change control process, or a Fast track OperationalWorkscope amendment developed.

In no event are offshore personnel to undertake the work, unless they are confident it is safe andreasonable to execute. Also no work is to start unless an appropriately signed version ‘C’ of the FOWSis available or a field instruction (backed up by an onsite TRA) has been carried out. The latestrevision status of the FOWS is indicated on the ‘Latest Look ahead Schedule’, issued by UnderwaterOperations Cost/Planning Engineer.

4 FORMAT AND CONTENT OF OPERATIONAL WORKSCOPES

4.1 Physical Document

The document is to be of A4 size dimensions. Drawings will typically be reduced to size A4 with, ifrequired, some A3. These would require folded and bound into the document. No drawings larger than A3 shall be used in the workscopes. The document is to be comb bound to permit easy photocopying.The outside covers are to be durable plastic.

With respect to larger workscopes, consideration should be made by the Engineer responsible forproduction of the FOWS, in consultation with the Job Leader and other parties, to bind drawings,appendices and any other relevant documents in a separate volume.

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4.2 Format

The format is to comply with the current Word-for-Windows Workscope Template.

4.3 Content

The workscope shall contain clear step-by-step instructions detailing the work to be carried out. It shalldetail the objective of the work identifying the platform/asset preparation/isolation work that has to becarried out prior to and during the execution of the work. The workscope shall contain all thenecessary drawings, sketches and, where appropriate, storyboards. The workscope shall highlight allsafety concerns associated with the work identifying any risks have been mitigated.

5 OPERATIONAL WORKSCOPES

5.1 Introduction

There are generally two types of operational workscopes, remedial/construction workscopes andInspection workscopes.

Inspection workscopes differ from remedial or construction workscopes because of their dependenceupon standard inspection procedures, the use of ROV techniques and of their relationship withCOABIS. To ensure consistency of inspection instructions and results, Inspection OperationalWorkscopes utilise COABIS CTS sheets as the foundation for the work instructions.

Remedial/construction workscopes are normally based upon previous similar intervention jobs and willalways be a detailed step-by-step sequence giving clear and unambiguous instructions for theexecution of the work.

5.2 Format for Operational Workscopes

The Operational Workscope is authored starting with the same Word-for-Windows WorkscopeTemplate as any other Workscope.

(1) Introduction General overview of the worksite, brief summary of the objectives ofthe workscope, a schedule and sequence of the work and a summaryof tasks. A field layout is also to be included in this section.

(2) Safety andEnvironmental HSE

This section will start with a safety summary, which will briefly identifythe particular hazards associated with carrying out the work. It shallidentify whether an onshore HIRA has been conducted and refer tothe appropriate document. The remaining section will identify eachknown hazard. Discuss how it arises and how it is to be controlled,with a view to the whole job.

(3) SpecificCommunications

Offshore/Onshore, List of contacts

(4) Operational Procedure This section shall fully detail the work to be carried out. It shall be astep-by-step sequence of events detailing all activities and equipmentrequired, complete with all safety and hold points identified. Thissection shall include all preparation, isolation, installation andcommissioning activities. For complex jobs this section may be furthersubdivided into discrete sections. All sections shall have a summaryat the beginning describing the objectives of each section.

Where appropriate include a decision tree specifically for faultanalysis and investigation.

(5) Composite EquipmentList

Highlighting specific/specialist equipment required.

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(6) Drawings, Sketches &Photographs

General drawings, P&IDs and photographs that apply to the job as awhole. Drawings are typically obtained from the Structure/facilityUMDB, unless none exist, where suitable alternative drawings are tobe employed. They should identify any safety issues, such as caissonlocations and depths, chain anchor catenaries. For intervention tasksP&IDs and relevant system schematics must be included.

(7) Attachments & Appendices

Contains Work Status Report (Listing of CTS and estimated times); asappropriate, CTS Sheets highlighting specific requirements by CTS; Appendices such as COSHH sheets; Specialist equipment manuals;Checklist matrix of required work at the location (Optional, usuallyused for FMD member listings).

6 APPROVALS

The draft and final documents are circulated for comment and approval and distributed in the samemanner as other Operational Workscopes (Paragraphs 3.3 to 3.5).

The Fast track Operational Workscope is a work instruction and responsibility for undertaking thesetasks lie with the diving contractor. Diving contractor approval must be secured.

7 CREATION OF ‘COST CODES’ (JOB NUMBERS)

7.1 Introduction

Once a WRF (Work Registration Form) has been established, a ‘Cost Code’ is assigned to the work.This is generated by COABIS in numerical order. Creating a Cost Code outside of COABIS may resultin duplication of assigned job numbers.

7.2 Cost Code Creation

COABIS creates a Cost Code, based on the Installation; Year; Work Type; Sponsoring Unit; and

Sequential number.

Installations, Subsea Facilities and Pipelines shall be referenced by a Code, which for pipelines andsome associated facilities cross reference to the Inspection Based Information System (IBIS) codes forpipelines. These codes are inbuilt in to the COABIS system, but where COABIS is not used the codeswill be given within the relevant workscope. Examples of these codes are as follows:

Structure Code BA - Brent Alpha`

Facility Code EGRT - Egret Subsea Facility

Pipeline Code N0205 - 8 inch Gas Export Anasuria to Fulmar

The Sponsor Unit is selected from the following list, where the initial letter is incorporated in the CostCode, prior to the final three numbers of the Cost Code.

B Brent (Including Risers)

N Northern (Including Risers)

C Central (Including Risers)

E ONEgas East

W ONEgas West

Z Integrated Systems (Pipelines)

P Projects Subsea

I Insurance

T Third Party

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The Work Type is selected from the following list, where the number shown is incorporated in theCost Code as the third last digit.

(1) Inspection

(2) Construction

(3) Repairs(4) Topside (Lifts, Support)

(5) Vessel Overheads

(6) De-Commissioning

(7) Production Wellheads

(8) Trials

From the above a Cost Code is generated in the form shown below:-

AA/2004/C302

Installation / Year / Sponsoring Unit - Work Type – Sequential Number

Auk Alpha / 2004 / Central (C) – Repair (3) – 02 (2nd

Job Planned for Auk A in 2004)

In addition to the above, a description of the works, the Sponsor and an Account Number is enteredinto Coabis. The COABIS entry form is shown below:

Figure 1 COABIS Entry Form

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INITIATE WRF(SPONSOR)

APPROVEWRF

CIRCULATEWRF

COABIS JOB No. ACCOUNT No.

ALLOCATEJOB LEADER

CREATE JOBFILE ANDLIVELINK

JOB LEADER CONTRACTOR JOB FILE

JOB LEADERKICK OFFMEETING

DEVELOPPROCEDEURE

ISSUE DRAFTOWS

CIRCULATEFOR REVIEW

SPONSOR PEER REVIEWENGINEER

CONTRACTOR

JOB LEADERCOLLATES COMMENTS

ISSUE FOWS FORSIGNATURE

SPONSOR PEER REVIEWENGINEER

CONTRACTOR

FOWSPROCEDURE SIGNED

PUBLISH

OUTLINE SCOPEOF WORK

SPONSORSCOPE OF WORK

Figure 2 Workscope Development Flowchart



0153-001

SECTION 1

CHAPTER 2

LOCATION / POSITIONING

CONTENTS

Para Page

1 INTRODUCTION 3

2 PROCEDURE 3

2.1 Datum Points 3

2.2 Structural Numbering System 3

2.3 Distance Measurement 3

2.4 Structural Clock Notation System 3

2.5 Weld Clock Notation 3

2.6

Structural Compass Heading and Depth Notation System 4

3 SEABED SURVEY 4

FIGURES

No Page

1 Shell EPE Offshore Coordinate Reference Systems 5

2 Node Saddle Clock Notation 6

3 Conductor Notation 7

4 Continuous Element Notation 8

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CHAPTER 2

LOCATION / POSITIONING

1 INTRODUCTION

A systematic approach is to be carried out to define the location of defects or anomalies. The objectiveof such an approach is to allow consistent relocation of these features in subsequent years.

2 PROCEDURE

The definition of the location of anomalies requires the use of a number of concepts. These are DatumPoints, the Structural Numbering System, Distance Measurement and Clock Notation. These conceptsare outlined in Paras 2.1 to 2.6.

2.1 Datum Points

The position of any item of interest must be measured from a datum point. A datum point can be any

readily available, identifiable and repeatable static reference point.

2.2 Structural Numbering System

Each structure has a systematic numerical identification system that allows particular points orelements of the structure to be described. This numbering system is to be used when describing thelocation of the datum point.

2.3 Distance Measurement

The distances are to be measured in metric units and an indication of the accuracy of themeasurements must be given.

2.4 Structural Clock Notation System

The clock notation system is used to describe the location of a feature around a cylindrical element.For the purpose of the system, cylindrical elements are divided into four categories.

(1) Horizontal and diagonal elements. These include horizontal, horizontal diagonal and verticaldiagonal members, riser stubs and pile guide supports. See Figures 2 and 3.

(2) Vertical elements (primary). These elements form an integral part of the installation and includelegs, vertical members, conductors and guides and caissons. See Figures 2 and 3.

(3) Vertical elements (secondary). These elements are associated with larger structural

components and would, for example, be pile sleeves and grout pipes. See Figures 2 and 3.

(4) Continuous elements. These elements go through both horizontal and vertical phases andwould include risers and J tubes. See Figure 4. The convention, as it applies to each of thesecategories, is described as follows:

(a) Horizontal and diagonal elements. 12 o'clock is at the top of the member and the clock isviewed from the mid-point of the brace towards the node. See Figure 2.

(b) Vertical elements (primary and secondary). 12 o'clock is taken at platform north and theclock is always viewed in plan. See Figure. 2.

2.5 Weld Clock Notation

Node saddle welds are always to be viewed from the brace to the node with the imaginary clock facingthe viewer.

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The 12 o'clock position is to conform to prevailing structural clock notation system. The 12 o'clockposition and clock orientation shall conform to the structural clock notation system for all butt welds.See Figure 3.

2.6 Structural Compass Heading and Depth Notation System

This location method should be used when a Remotely Operated Vehicle (ROV) is being used tosurvey a large vertical cylindrical element of a structure. Any findings should be reported against thevehicle's depth and it’s heading when viewing the anomaly straight on.

3 SEABED SURVEY

The CONTRACTOR shall carry out all offshore survey and positioning WORK using the coordinatereference system and datum shift parameters from WGS84 supplied by the COMPANY, at the time ofthe work.

For guidance see Figure 1 Shell EPE Offshore Co-ordinate Reference Systems.

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Figure 1 Shell EPE Offshore Coordinate Reference Systems

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Figure 2 Node Saddle Clock Notation

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Figure 3 Conductor Notation

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12

3

6

9

12

6

39

12

6

39

12

6

39

12

6

3

12

6

3

SECTION B - B

SECTION A - A

SECTION C - C

A D

16

14

13

15

1

2

3

4X

VIEW ON ARROW X

12

3

6

9

VIEW ON

ARROW Z

Z

12

6

39

VIEW ON

ARROW Y

B

B

A

A

C

C

SUPPORT

SUPPORT

9

9

Figure 4 Continuous Element Notation



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SECTION 1

CHAPTER 3

EQUIPMENT

CONTENTS

Para Page

1 SPECIFICATIONS 3

1.1 General 3

1.2 Hydraulics 3

1.3 Electrical 3

1.4 High Pressure Water Jetting Equipment 3

1.5 Low Pressure Dry Air Grit Entrained Cleaning Equipment 3

1.6 Lifting Equipment 4

1.7 Video System 4

1.7.1

General 4

1.7.2 Video Lighting 4

1.7.3 Video Standards 4

1.7.4 Onboard Video Suite 4

1.7.5 Topside Video 5

1.8 Digital Images/Stil ls 5

1.8.1 Underwater Images 5

1.8.2 Topside Images 6

1.8.3 Format 6

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CHAPTER 3

EQUIPMENT

1 SPECIFICATIONS

1.1 General

All items of equipment are to be supplied together with a complete set of operating instructions andtechnical literature.

The equipment is to be suitably protected for the environment in which it is to be operated.

The depth rating of the equipment is to be adequate to allow it to operate at all depths specified in thework scope.

All external controls are to be accessible and easily manipulated by the operator and have clearidentification and markings. Suitable measures are to be taken to protect and prevent the loss of

equipment when at/or transferring to or from the worksite. The equipment is to be maintained andoperated in accordance with the manufacturer's instructions.

Where appropriate, lifting pad eyes and attachments are to be correctly tested and certified, includingNon Destructive Testing (NDT) certificates for welded components.

All supplied equipment is to be compliant with any conditions required by UK legislation, and whererequired is also to be compliant with the ‘Provisions and Use of Work Equipment Regulations 1998’ (PUWER).

When working outside of the UK sector, equipment is to comply with the local government legislation.References below are only made to the relevant UK legislation.

1.2 Hydraulics

All equipment for diver operation is to be fitted with 'dead man' type triggers.

Triggers are to be surrounded by guards designed to prevent accidental operation.

Cutting discs or brushes are to be suitably guarded.

1.3 Electrical

All underwater electrical equipment is to comply with the latest revision of the International MarineContractors Association (IMCA) Diving Division, ‘Code of Practice for the Safe Use of Electricity

Underwater’.

1.4 High Pressure Water Jetting Equipment

All high-pressure water jetting equipment is to comply with the latest revision of the IMCA DivingDivision ‘Code of Practice for the Use of High Pressure Water Jetting Equipment by Divers’.

All operators are to be instructed in the use of the equipment.

1.5 Low Pressure Dry Air Grit Entrained Cleaning Equipment

Two-way communication, Topside Operator/Diving Supervisor is to be maintained during systemoperation.

All operators are to be instructed in the use of the equipment.

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Expendable grit utilised must comply with SI 2002 No. 2677, ‘The Control Of Substances HazardousTo Health’ (COSHH).

1.6 Lifting Equipment

All lifting equipment is to be compliant with ‘The Lifting Operations and Lifting Equipment Regulations

1998’ (LOLER).

A LOLER Lift Plan is required to be completed for all lifting operations.

1.7 Video System

1.7.1 General

All video recorders shall be of the Super-VHS format for direct recording from diver or ROV, and shalluse tapes of three-hour duration. S-VHS tapes are to be used for all underwater recordings. Oncompletion, one copy shall be made again on S-VHS. Additional copies may be requested, some ofwhich may be required on Standard-VHS format tapes.

In every case the video recording suite should be capable of recording and playing back 400 lineresolutions as a minimum. VCRs are to be set up to avoid synchronisation faults such as picturehooking.

1.7.2 Video Lighting

Video lighting is to conform to the following:

(1) To be designed and arranged to give optimum video.

(2) 'Spot lighting' on diver helmet video e.g. SSS Mk II lights are not acceptable.

(3) Should be diffused to give even lighting across the picture and not cause burn-out orshadowing, e.g. OE 1132 lights, or better, are acceptable.

(4) Not to cause unacceptable colour cast.

(5) Must give good colour rendition and separation.

1.7.3 Video Standards

The video system will be assessed using the Shell Video Assessment Test Kit and Procedures. Thefollowing video standards are applicable for live video:

(1) Diver Observation ROV camera e.g. Tiger. SIT 550 lines resolution, 9 clear steps on the grey

scale Colour 500 lines resolution, and clear colour separation.

(2) ROV general purpose/pilot camera. SIT 550 lines resolution, 9 clear steps on the grey scale.Colour 500 lines resolution, clear colour separation and good colour rendition.

(3) ROV Inspection Camera/Diver Helmet mounted camera. SIT 550 lines resolution, 9 clear stepson the grey scale. Colour 500 lines resolution, clear colour separation.

1.7.4 Onboard Video Suite

The onboard video suite will include but not be limited to: -

(1) Cameras

(2) Video Recorders (S-VHS format)

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(3) Video Overlay Units

(4) COABIS Video Overlay system

(5) Timers

(6) Microphones

(7) Monitors (Super - VHS Resolution)

(8) Lighting

All units are to be compatible within the system suite to CCIR Standard (PAL Format for colour).

Recorded video to be 400 lines resolution with 9 clear steps on the grey scale, clear colour separationand good colour rendition.

1.7.5 Topside Video

A digital video camera may be required for topside inspections, and occasionally for video of topsideconstruction tasks.

The required specification for a topside video camera is given in the contract document.

1.8 Digital Images/Stil ls

1.8.1 Underwater Images

Underwater Digital Images will be required in the following cases:

(1) As a matter of course, of all anomalies where such an image suitably conveys details of the

anomaly.

(2) Where specifically requested in the Workscope, Standard Procedure or by the Shell OffshoreRepresentative.

(3) During construction operations, where specified in the Workscope, requested by the ShellOffshore Representative, and/or to enhance the reporting of findings / operations conducted.

Where possible the image should be captured directly from the diver or ROV camera picture direct, soas not to lose picture quality. Where an item arises that was not initially captured, images can beobtained from relevant video footage, or if practicable, a return visit should be made to the item ofinterest whilst the vessel is still on location to obtain direct digital stills.

1.8.1.1 Image Requirements

Most video inspections should be run using COABIS, with built in video overlay. For this reason, andwith the additional date/time overlay required for all video inspections, most of the required informationshould automatically be available on the video overlay, providing sufficient details of the subject inquestion. The following information, as a minimum, is required on a Digital Image: -

(1) Date/Time (Standard Overlay)

(2) Component Number (Standard COABIS Overlay), or Component Description

(3) Cost Code / CTS (Additional Input)

(4) Brief Description (Additional Input)

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Items (3) and (4) should be on the same line, so as not to obscure the component.

Where possible a scale should be employed, i.e. when taken from a divers video camera.

Additional information that may be required, as dictated by the subject, would be Eastings andNorthings, which again would automatically be superimposed from the ROV video overlay.

1.8.1.2 Stand Off/General View

Where specified in the workscope, as a result of an anomaly, or on instructions from the ShellOffshore Representative, Stand Off/General View Digital Images will be taken.

The images are to clearly show the overall worksite, if possible, from two opposing sides, i.e., nodallocations 12 and 6 o'clock or 3 and 9 o'clock.

If a series of images are to be taken they are to proceed in a logically agreed continuous sequence.

1.8.1.3 Weld Node / Close Up Images

Inspections may require images to be taken to highlight defects or repairs, i.e. remedial grinding. Inthese instances the image will be restricted to the area of interest. Full weld mosaics are not required.For such images, in addition to the above data, the following is also to be included on image:

(1) The Datum Mark will be the start position - 'O' mm in all instances.

(2) Scale at least 150mm long, with 5mm and 10mm increments clearly visible. Scale to bepositioned between 25mm and 50mm from the weld / item of interest.

(3) Distances from datum to be marked in 100mm increments, i.e. 0, 100, 200, 300, 400mm etc.,covering the area of interest. The scale used (2) should suitably span these increments to givethe exact position from datum. For welds this numbering is to run in a clockwise directionaround the member or chord as site conditions dictate. For other items of interest the numberingis to view from left to right.

(4) 'C1' anomalies or defect grinding areas are to be highlighted using colour coded magneticarrows, or suitably marked using image editing software.

(5) Where mosaics are required, suitable overlap between consecutive images is required, so thatthe full area of interest is covered, with unambiguous results.

1.8.2 Topside Images

A Digital Camera will be required to take topside Digital Images in the following cases:

(1) For topside inspections as requested in the Workscope, Standard Procedure and where criticalanomalies exist.

(2) During construction operations, where specified in the Workscope, requested by the ShellOffshore Representative, and/or to enhance the reporting of findings / operations conducted, i.e.images of recovered chokes.

The required specification for a topside camera is given in the contract document.

1.8.3 Format

All digital still images should be supplied in .JPG format.

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CHAPTER 4

INSPECTION OPERATIONS

1 INSPECTION

Inspection shall include but not be limited to:

(1) Video recording and Digital Still Images

(2) Identification and cleaning

(3) Scour, debris surveys and debris removal

(4) NDT techniques, (visual, MPI, ultrasonics, ACFM, FMD, PEC, etc.)

(5) Surveys:

(a) Marine growth

(b) Dimensional

(c) Corrosion

2 SURVEILLANCE OF INSPECTION

The Contractor shall ensure the Inspection Diver's helmet is fitted with CCTV at all times during allunderwater activities and inspection related works. Such CCTV coverage is to be capable of clearlyshowing positions of equipment as necessary, and work locations (including close-up views whereanomalies may be noted). All anomalies shall be recorded by diver description.

Such recording will be made direct by the diver and all diver conversation will be repeated, for clarity,by the Dive Supervisor, or Inspection Controller.

3 VISUAL INSPECTION SPECIFICATIONS

3.1 General Visual Inspection - GVI

This type of inspection is generally carried out by ROV.

The purpose of the inspection is to establish the overall impression of the condition of the componentand its attachments without any cleaning and to detect any major departures from the original orpreviously known condition. Any anomalies found during this type of inspection are likely to be of fairly

large scale such as dents, holes, buckling, missing members, debris, scour, mud build up, etc.

3.2 Detailed Visual Inspection - DVI

This type of inspection is generally carried out by ROV or divers.

The purpose of the inspection is to establish the condition of the component and its attachments anddetect defects that would otherwise be obscured by marine growth. A limited amount of cleaning willbe required to carry out this inspection. Soft marine growth should be removed by either water jetting,scrapers and/or wire brushes, the standard of cleaning will be sufficient to enable details of thecomponent to be seen. It will not normally be necessary to remove hard marine growth unless itobscures detail. Care is to be taken during the cleaning to ensure any surface coatings are notdamaged.

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Any anomalies found during this type of inspection are likely to be large cracks in concrete surface,gross cracks in welds, cracks in conductor guides, clamp bolts missing/loose, corrosion, etc.

3.3 Close Visual Inspection - CVI

Divers generally carry out this type of inspection. However, it may be carried out by ROV. For ROV

CVI the vehicle should be parked. Either zoom or manipulator mounted video camera and lightpackage is to be used to scan the area at extreme close range (typically 20 - 100mm stand-off).Scanning speed over surface is to be 0.5 to 1 metre per minute.

The purpose of the inspection is to establish a detailed inspection of areas of specific interest, typicallywelded joints and concrete joints. A higher standard of cleaning is required for this type of inspection,for welded joints all marine growth is to be removed and the area to be grit cleaned to SA 2.5. Forconcrete surfaces it will be necessary to remove all hard and soft marine growth, worm cast stains canbe left in place unless they obscure detail.

The standard of cleaning will be sufficient to enable details of the component to be seen. Care is to betaken during the cleaning of concrete surface/joints to ensure any bitumen/epoxy coating is notdamaged.

For diver inspection the area to be inspected is to be marked up in increments to enable anydefects/blemishes to be accurately located, sized and plotted with reference to a known datum point.

For ROV inspection, the area to be inspected is to be clearly identified using SIT and/or colour CCD,with the ROV at sufficient stand off for the area to be shown in relation to identifiable features. Thisprecludes the requirement for the area to be marked up in increments. However, any defects notedare to be marked up using a 'Propelling Wax Crayon' at a distance of 75 to 150mm either side of thedefect. A single line or 'X' is sufficient, again this should be shown in the stand off video sufficiently toidentify its position with regard to a known feature.

Any anomalies found during this type of inspection are likely to be weld cracks/defects, concretecracks/blemishes.

Anomalies found by ROV may result in diver intervention to accurately size the defect. Alternatively,the ROV should use a rod, marked in suitably sized increments, i.e. 10mm, held in the vehiclesmanipulator. Dependant on the item to be inspected, the scale should be in the form of two rodsmounted at 90 degrees to each other, to give horizontal and vertical dimensions, without need torotate the manipulator



0153-001

SECTION 1

CHAPTER 5

INFORMATION CONTROL CENTRE

CONTENTS

Para Page

1 OPERATIONAL OBLIGATIONS 3

1.1 Facilities 3

1.1.1 Information Control Centre 3

1.1.2 Dive Contro l Data Recorders Workstation 4

1.1.3 ROV Data Recorders Workstation 4

1.2 Data Recording 5

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CHAPTER 5

INFORMATION CONTROL CENTRE

1 OPERATIONAL OBLIGATIONS

The Contractor is responsible for providing suitable facilities for the gathering of inspection data andrecording of activities conducted during maintenance and repair operations. The Contractor isresponsible for various tasks during these IMR programmes; in addition to the completion of theseIMR works.

The QAQC Coordinator shall act as the focal point for liaison with the Diving Superintendent/ROVParty Chief for all information relating to the planning, performance, recording and reporting of thework.

The following details these obligations:

1.1 Facilities

The following facilities are to be provided to allow data gathering, compilation of data gathered andcompletion of reports:

1.1.1 Information Control Centre

An office is required for the use of the Shell QAQC Coordinator, and/or the Contractors IMRCo-ordinator. The office is to be equipped with the following:

• Monitors to allow views all works carried out by either diver or ROV from any workstation. Thisshould be linked into the video suite, listed below, to allow recording of any of these views.

• It will have full communications to all workstations and an uninterrupted power supply regulatorfor working with computer systems. Communications links shall include suitable KU Bandtelephone external linkage for both phone and fax, and full IT linkage enabling utilisation of e-mail and the internet, with a dedicated ‘Yac-Fax’ (or similar) account.

• 2 x COABIS computers complete with 17” flat screen monitors and DVD+RW drives. Thefollowing software is required:

• Microsoft Office 2000, or compatible.

• Microsoft Project.

• AutoCAD LT 97 or higher and a drawing viewer – e.g. Voloview Express.

• Adobe Acrobat.

• Paint Shop Pro V.8 (or Photoshop V5).

• 1 x Laser printer (networked). Minimum specification equivalent to HP LaserJet 5M, suppliedwith spare toner cartridges.

• 1 x A3 colour printer (networked), supplied with spare toner/ink cartridges.

• 1 x A3 colour scanner (networked).

•

An A3/A4 photocopy machine complete with reducing/enlarging multi-feed and sorting facilitiesfor the use of the QAQC/Coordinators, supplied with spare toner cartridges and suitable paper.

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• A video suite for reviewing/copying of tapes, comprising of two Panasonic AG7350 S-VHS tapedecks (or similar) and one YC colour monitor (minimum 16 inch screen size). This suite shouldallow copying of video from a topside digital Camcorder, to S-VHS.

• The office will have sufficient space to allow preparation of workscopes and fast trackworkscopes for issue, and for the production of multiple reports.

• Suitable shelving, with bad weather fixings, will be required with sufficient clearance for A4 ringbinder sized manuals.

• Suitable cupboards or A4 shelving (+2m in length) to allow storage of the full compliment ofCOMPANY platform Underwater Maintenance Database Manuals (UMDB’s).

• Two x 3 drawer filing cabinets.

• 1 x White board.

1.1.2 Dive Control Data Recorders Workstation

(1) An NDT/work control station providing working facilities for the Data Recorder, with suitabledesk space to allow review of workscopes and for writing/marking up of data records. Thisstation shall have full communications link with divers and Dive Supervisor, as well as monitorsfor receiving video input from divers and ROV. Facilities for recording video inputs shall beprovided (Super-VHS format), complete with microphone.

(2) The master video recorder will be equipped with a video overlay card, to allow control by theCOABIS system, as well as a separate video overlay unit for manual use.

(3) A networked COABIS installed computer dedicated for the Data Recorder’s use, will beavailable at the Data Recorders workstation, without recourse for them to move position whilstoperating the video suite. The computer will have a video grab facility, to allow direct real time

video grabs and grabs from videotape. The computer will have its own e-mail account. Thecomputer will be loaded with the following minimum software;


• AutoCAD LT 97 or higher and a drawing viewer – e.g. Voloview Express.

• Adobe Acrobat.


(4) Filing cabinets, shelves, etc. to hold all work scopes and dive procedures, plus all other workrelated information including the UMDB Manuals supplied by Shell EPE.

(5) A suitable area shall be available for the set up, charging and maintenance of inspectionequipment, such as CP and WT meters.

(6) Control of the subsea MPI unit should be possible from the Dive station or Data Recordersworkstation.

1.1.3 ROV Data Recorders Workstation

Facility should be available at each ROV station, to allow recording of Data. To facilitate this, thefollowing is required as a minimum:

(1) Suitable desk space for the Data Recorder to allow review of workscopes, and forwriting/marking up of data records. This station shall have full communications link to the DiveSupervisor and Bridge.

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(2) A monitor for reviewing the ROV video picture. Facility to record to S-VHS video, any of theROV camera pictures, including all relevant overlay, i.e. date, time, depth and heading. Whereseabed surveys are required, easting and northing overlay from a continuous feed, of the ROV’sposition is to be recorded. CP overlay is also required. Facilities for recording video inputs shallbe provided (Super-VHS format), complete with microphone.

(3) The master video recorder will be equipped with a video overlay card, to allow control by theCOABIS system, as well as a separate video overlay unit for manual use.

(4) A networked COABIS installed computer dedicated for the Data Recorders use, will be availableat the Data Recorders workstation, without recourse for them to move position whilst operatingthe video suite. The computer will have a video grab facility, to allow direct real time video grabsand grabs from videotape. The computer will have its own e-mail account. The computer will beloaded with the following minimum software;


• A drawing viewer – e.g. Voloview Express.

• Adobe Acrobat.


1.2 Data Recording

A Data Recorder will be required to be at the Dive Control and ROV workstations when inspection andconstruction work is ongoing, that requires the recording of operations both in the form of video andor/written accounts.



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SECTION 2

GUIDE TO THE STANDARD PROCEDURES

FOR UNDERWATER ENGINEERING OPERATIONS

CONTENTS

CHAPTER 1 INTRODUCTION

CHAPTER 2 STANDARD PROCEDURES

CHAPTER 3 METHOD OF USE

CHAPTER 4 TASK CODING SYSTEM AND COMPONENT TASK SHEETS

CHAPTER 5 PROCEDURE & COMPONENT NUMBERING SYSTEM

CHAPTER 6 ANOMALY REPORTING & CRITERIA

CHAPTER 7 REPORTING

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SECTION 2

CHAPTER 1

INTRODUCTION

CONTENTS

Para Page

1 INTRODUCTION 3

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CHAPTER 1

INTRODUCTION

1 INTRODUCTION

The main aims of producing Standard Procedures for Underwater Engineering Operations are asfollows:

(1) To reduce the number of procedures that have been produced in the past on similar work.

(2) To assist the Engineer in the preparation of the Scope of Work.

(3) To standardise the format and collate the Standard Procedures into a single volume to facilitateeasy reference.

(4) To specify to the contractor the method and the precise standards to which the work is to beperformed.

(5) To specify personnel qualification necessary to carry out the specified works.

(6) To carry out all works in a safe and most efficient manner.

(7) To standardise procedures for ‘ad hoc’ jobs to maintain quality and safety.

The adoption of Standard Procedures for Underwater Engineering Operations, in combination with aprocedure numbering and task coding system will significantly enhance the system for both theEngineer and Database Operator.

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SECTION 2

CHAPTER 2

STANDARD PROCEDURES

CONTENTS

Para Page

1 STANDARD PROCEDURES 3

2 NEW STANDARD PROCEDURES 3

3 NON-STANDARD PROCEDURES 3

4 STANDARD PROCEDURES IN COABIS 3

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CHAPTER 2

STANDARD PROCEDURES

1 STANDARD PROCEDURES

Standard Procedures are written to free the Engineer from the task of writing the requirements of thework, e.g. take colour video, carry out Magnetic Particle Inspection (MPI) examination, etc.For the Contractor the Standard Procedures will specify that he carry out the work to a prescribedstandard.

The procedures included within Sections 3, 4 and 5 of this manual, have set tasks to be carried outdue to the repetitive nature of the procedure. Optional set tasks are also listed. The method in which tocarry out both these set and optional tasks are detailed within the relevant Standard Procedure.

The majority of the Standard Procedures are for inspection work, due to the repetitive nature of theinspection requirements.

Due to their nature, only a few repair and construction procedures are repetitive and can be coveredby a Standard Procedure included within this manual.

2 NEW STANDARD PROCEDURES

Where a new standard procedure is to be developed it shall conform to the following format:

(1) Work Method. This section briefly outlines the scope of the Procedure and whether the workcontained therein is to be accomplished by diver, ROV or a combination of both.

(2) Task Options. This section provides a list of Task Options required for the particular Procedure.

(3) Operating Procedure and Specification. This section details the method of accomplishing thework and the particular requirements that the work must be carried out to. It also gives theminimum qualifications for the personnel who are to carry out the works.

Included in this part, where applicable, are references to contractor/manufacturer procedures foroperation of specialist equipment, e.g. FMD, ACFM & PEC, etc. Where indicated these procedures areto be applied to the task in hand.

3 NON-STANDARD PROCEDURES

Other forms of repair and construction procedures are always ‘one off’. Their development cannot becovered within this manual, however previous workscopes created for various types of interventionsare saved within Shell EPE archives both electronically and in hard copy format, in deep storage.

Electronically, the most recent of these are stored within the Shell EPE Livelink database back to1997. These can be recalled and changed appropriately.

4 STANDARD PROCEDURES IN COABIS

The Standard Procedures are built into the Component Orientated Anomaly Based Inspection System(COABIS), with the associated designated set and optional tasks. For Inspection Tasks, set times areassigned to each task, which vary based on the component being operated on, and method ofinspection, i.e. diver or ROV. These times are set based on historical data. This allows for a quickmethod of estimating the time required to inspect a particular riser, caisson, wellhead, etc.Times however can be altered as required, based on other variables, such as access restrictions.

For Construction Tasks, times cannot be so easily assigned, and will require altering to suit.

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Where non-standard procedures are conducted, COABIS allows for any number of tasks from the totaltask listing can be allocated as appropriate.

The list of the tasks and their associated COABIS task codes are given in Chapter 4.



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SECTION 2

CHAPTER 3

METHOD OF USE

CONTENTS

Para Page

1 METHOD OF USE 3

2 WORK UTILISING A STANDARD PROCEDURE 3

3 NON STANDARD WORK 3

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CHAPTER 3

METHOD OF USE

1 METHOD OF USE

When the requirement for work on a particular component, group of components or structures arises,the sponsoring engineer will first check through Sections 3 to 5 in order to establish if there is asuitable procedure within the current list of standards that will satisfy the requirements of the work.

If a suitable procedure is located, proceed as in Para 2, or if the work is non-standard, proceed as inPara 3.

2 WORK UTILISING A STANDARD PROCEDURE

When a Standard Procedure is located that satisfies all or most of the requirements of the work it willeffectively reduce the contents of the Scope of Work to a listing of Job Number; Job Title; Componentsto be inspected; relevant Standard Procedure number; and any specific options to carry out under the

Standard Procedure.

If there is some additional work or some changes these will be identified in the relevant operationalworkscope.

The preparation and distribution of an Operational Work Scope (OWS) is covered in Section 1,Chapter 1.

3 NON STANDARD WORK

If there is no Standard Procedure available, the sponsoring engineer will be required to complete amuch more detailed Scope of Work to enable a suitable procedure to be produced (See Section 1,Chapter 1).

The sponsor's Scope of Work shall provide the following information:

(1) Detailed description of the work to be carried out.

(2) General description of the worksite.

(3) Review of the existing worksite and the historical context for the work.

(4) Reasons for modifying the existing situation.

(5) What it is that is to be installed, removed or inspected.

(6) Details of all sponsors supplied equipment.

(7) Any other generally informative comments.

This Scope of Work will be handed over to the Subsea Operations Job Leader, the focal point for thepreparation of the OWS. The preparation and distribution of OWS is covered in Section 1, Chapter 1.

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SECTION 2

CHAPTER 4

TASK CODING SYSTEM AND COMPONENT TASK SHEETS

CONTENTS

Para Page

1 INTRODUCTION 3

2 TASK CODE SYSTEM 3

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CHAPTER 4

TASK CODING SYSTEM AND COMPONENT TASK SHEETS

1 INTRODUCTION

When preparing an operational workscope (see Section 1, Chapter 1) a workscope will be subdividedinto one or several logical sections. These sections are called workpacks or CTS’s (Component TaskSheets). CTS’s ultimately form part of the final report (See Section 2, Chapter 7). There are no hardand fast rules regarding creation of CTS’s - they should merely be logical divisions of an operationalworkscope, discrete manageable sections which can be executed and reported against, and whichcan be assigned an estimate of duration.

Each CTS consists of a number of tasks. These work tasks enable specific information such asestimated times, actual times and other unique data i.e. CP readings to be recorded against.The CTS’s and tasks assist in planning and estimating similar activities on similar jobs.

The tasks form part of COABIS and the Task Code system logically groups like tasks together under

set categories to facilitate quick reference.

Due to a review of the Standard Procedures and tasks conducted, some Task Codes no longerutilised have been removed from paragraph 2 below. These removed tasks and their associatedhistorical data remain within the COABIS database.

2 TASK CODE SYSTEM

The Task Listing will be made up of 2-3 Alpha character code as follows:

Task Code Descript ion

CH - Check

CH-BLT Bolt Check (Visual and by Hand)

CH-LKS Check for Leaks

CH-VLV Valve Position Check

CH-FXW Check Armawrap (Flexi-Wrap)

CL - Cleaning

CL-DRG Dredge Pump

CL-GRT LP Dry Grit Clean

CL-INS Clean for Inspection

CL-MGR Marine Growth Removal

CN - Construction

CN-COM Commissioning Observation

CN-DPR Deck Preparation

CN-EQP Deploy Equipment

CN-FLG Align/Pull in Spools

CN-FLS Flushing Operations

CN-FLT Tension & Wrap Flanges

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CN – Construct ion (Continued)

CN-FXW Remove/Apply Flexi-Wrap

CN-GRB Build Grout Bag Support

CN-GRD Remedial Grinding

CN-GRT Grouting Operation

CN-HVL Heavy Lift

CN-IAN Install Anode

CN-IGC Install/Recover GRP Covers

CN-INC Install/Recover Clamp

CN-IPC Install Pile Cap

CN-JUM Connect/Disconnect Jumpers

CN-LRG Large Construction TaskCN-MAT Lay/Recover Mattresses

CN-MUD Mud Removal

CN-PIG Pigging Operations

CN-PRT Pressure Test

CN-RBP Remove/Replace Blanking Plate

CN-RGR Remove Grill/Replace Grill

CN-RIG Rig/Derig Worksite

CN-RPL Open or Close Roof Panel

CN-STD Standard Construction Task

CN-TCH Trenching Operation

CN-TEN Tension Studs

CN-TOP Topside Assistance

CN-VLC Valve Operation

CP – Cathodic Potential Measurement

CP-CON Contact Measurements

CP-CONC Concrete Proximity ReadingsCP-GSC G-Scan CP Survey

CP-PRX Proximity Measurements

CP-ZON Zonal CP Survey

CU - Close-Up Inspect ion (Weld)

CU-CVI Close Visual Inspection

CU-DVI Detailed Visual Inspection

CU-MPI Magnetic Particle Inspection

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DB - Debris

DB-CHK Visual Debris Check

DB-REM Debris Removal

DM - Dimensional Survey

DM-SCR Scour Survey

DM STD Standard Dimensional Task

IN - Other Inspection Tasks

IN-CMT Comments and Details

IN-ECI Eddy-Current Inspection

IN-ERS Talon ERS Survey

IN-FMD Flooded Member Detection

IN-GSC G-Scan Direct Current Readings

IN-OTH Other Inspection Task

IN-RAD Radiography

IN-SSC Swain Sea-Clip DC Measurement

IN-UT Ultrasonic A-Scan Inspection

IN-UTA Ultrasonic A Scan

LI - CU Linked Technique Tasks (Weld)

LI-CVI Close Visual Inspection

LI-DVI Detailed Visual Inspection

LI-MPI Magnetic Particle Inspection

MG - Marine Growth

MG-GEN Marine Growth Survey

PH - Photography

PH-DIG Digital Image

PH-TOP Topside Digital Still Images

PI - Pipeline

PI-203 Bare Metal Incident

PI-500 Anode

PI-CP CP on Damage


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PI – Pipeline (Continued)

PI-CSE Confirmation of Span End

PI-CSS Confirmation of Span Start

PI-GEN General Pipeline Task

PI-SPN Pipeline Span Rectification

VD - Video

VD-DIV Diver Video

VD-ROV General ROV Video

VI - Visual Inspection

VI-AW Anode Wastage Measurement

VI-AWD Detailed Anode CheckVI-CVI Close Visual Inspection

VI-DVI Detailed Visual Inspection

VI-GVI General Visual Inspection

VI-PNT Coating Assessment

VI-ROV ROV Worksite Check

VI-SPZ Splash Zone Inspection

VI-TOP Topside Inspection

WT - Wall Thickness

WT-DIG Measurement U/T Thickness

WT-PEC Pulsed Eddy Current



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SECTION 2

CHAPTER 5

PROCEDURE & COMPONENT NUMBERING SYSTEM

CONTENTS

Para Page

1 INTRODUCTION 3

2 NUMBERING SYSTEM 3

2.1 Type of Work 3

2.2 Component Code 4

2.3 Sequential Number of the Procedure 9

3 STANDARD PROCEDURES 9

4

REGISTER OF PROCEDURE NUMBERS 9

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CHAPTER 5

PROCEDURE & COMPONENT NUMBERING SYSTEM

1 INTRODUCTION

The intention behind the Procedure Numbering System is threefold and is explained as follows:

(1) To convey a certain amount of information relating to the nature of the work (Tasks).

(2) To identify the type of component the work is being applied to.

(3) To group procedures related to work on similar components together in a logical manner.

2 NUMBERING SYSTEM

The numbering system conveys three items of information relating to the procedure.These items arecategorised as follows:

(1) Type of Work

(2) Component Code

(3) Sequential number of the procedure within its Component Code.

A typical example of a procedure number is given below illustrating the above three items ofinformation.

TYPE OF WORK (SINGLECHARACTER)

COMPONENT CODE (2-DIGIT) SEQUENTIAL OF THEPROCEDURE (3-DIGIT)

I 15 057

The number of characters and digits will not exceed six in total.

An explanation of each of the above three categories follows:

2.1 Type of Work

There are five possible codes within this category as follows:

(1) I - Inspection

This includes work not only performed by diver, but survey work carried out by ROV and topsidevisual inspection carried out from the diving/ROV support vessel.

(2) C - Construction

This covers all work installing equipment underwater.

(3) R - Repair

Includes change out of faulty equipment.

(4) M - Maintenance and general underwater operations

This includes routine submarine hose change-outs, opening and closing subsea valves, generalunderwater maintenance and operations.

(5) X - Miscellaneous

Non Specific.

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2.2 Component Code

The codes within this category are primarily, with some exceptions, based upon the UMDB systemwhere each component on a structure is given a unique number.

This unique numbering system is as per the Engineering Reference Document, Tag Numbering

System Code of Practice (Shell Document Number EA/116), Appendix 8, 9 and 10.

The Main Structure Component Codes (General) are as follows:

Non Specific Components 00 - 09

Structural Steel Jacket 10 - 19

Structural Concrete 20 - 29

Structural General 30 - 39

Pipework Systems 40 - 49

Valves 50 - 59

Cathodic Protection System 60 - 69

Anchoring System 70 - 79

Universal Joint 80 - 89

Spare 90 - 99

These main sections are further sub divided as follows:

(1) Non Specific Components (00 - 09)

00 - Work created offshore and for COABIS operators use (Defunct)

01 - General Arrangements (Non specific components)

02 - Frame / Elevation / View (External)

03 - Row / Elevation (Internal)

04 - Level / Plan (from above)

05 - Level / Plan (from below)

06 - Seabed

07 - Ancillary Systems GS’s

08 - Trials and testing of new underwater equipment and products

09 - Spare

(2) Structural Steel Jacket (10-19)

10 - General - Scour Survey

11 - Section of Leg

12 - Horizontal Member

13 - Diagonal Member

14 - Vertical Member

15 - Node/Intersection

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16 - Skirt Pile Guide

17 - Spare

18 - Spare

19 – Spare

(3) Structural Concrete (20 - 29)

20 - General - Scour Survey

21 - Shaft

22 - Cell Domes; Caisson Roof and Star Cell (Upper)

23 - Cell/Caisson Wall and Raft

24 - Spare

25 - Construction Joint

26 - Infill, Temporary Opening and Penetration

27 - Embedments

28 - Spare

29 - Spare

(4) Structural General (30 - 39)

30 - Structural (General)

31 - Steel Hull

32 - Boat Fender, Landing and Riser Protector

33 - Platform, Walkway and Support

34 - Ladders and Grab Rungs

35 - Conductor Guide Frame

36 - Baseframe, Mudmats/Support Structures (Secondary Steelwork)

37 - Baseframe (Seabed)

38 - Compartment/Float Tank

39 - General Attachments (Mooring Eyes, Pipeline, Anchor Lugs, Padeyes- Central Shaft).

(5) Pipework Systems (40 - 49)

40 - General

41 - Riser

42 - J-Tube

43 - Pump Casing, Caisson Drain, Cutting Chute

44 - Hose and Flotation Collars

45 - Manifold

46 - Clamp/Guide Assemblies

47 - Coupling

48 - Flange and Site Weld

49 - Conductors and Talon Connectors.

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(6) Valves (50 - 59)

50 - Valves

51 - Oil Valve

52 - Gas Valve

53 - Water Valve

54 - Air Valve

55 - Transducers

56 - Spare

57 - Spare

58 - Spare

59 – Spare

(7) Cathodic Protection System (60 - 69)

60 - General

61 - Anode - Section of Leg

62 - Anode - Horizontal Member

63 - Anode - Diagonal Member

64 - Anode - Pipework System

65 - Anode - Vertical Member

66 - Anode - Skirt Pile Sleeve

67 - Anode - Steel Hull

68 - Anode - Tank, Float, Compartment

69 - Anode - Platform, Baseframe, Base (Seabed) and Conductor Guide Frame

(8) Anchoring System (70 - 79)

70 - General (Guides and Stoppers)

71 - Anchor

72 - Anchor Block

73 - Chain Cable (with Shackle)

74 - Wire Cable

75 - Chain/Cable Anchorage

76 - Anchor Coupling

77 - Transponder

78 - Spare

79 - Spare

(9) Universal Joint (80 - 89)

80 - Universal Joint

81 - Universal Joint Assembly

82 - Universal Joint Seatings

83 - Spare

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84 - Spare

85 - Spare

86 - Spare

87 - Spare

88 - Spare89 - Spare

The Subsea Facil ity Component Codes (General) are as fo llows:

Wellheads/Trees 200 – 209

Towheads 210 – 219

Structures and Steelwork 220 – 229

Manifolds 230 – 239

Pipework 240 – 249

Valves 250 – 259

Cathodic Protection System 260 – 269

Control Systems 270 – 279

(10) Wellheads / Trees (200 - 209)

200 - Wellheads/Trees

201 - Guidebases

202 - Guideposts

203 - spare

204 - spare205 - spare

206 - spare

207 - spare

208 - spare

209 - spare

(11) Towheads (210 - 219)

210 - Towheads

211 - spare

212 - spare

213 - spare

214 - spare

215 - spare

216 - spare

217 - spare

218 - spare

219 – spare

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(12) Structures and Steelwork (220 - 229)

220 - Structure and Steelwork

221 - Access Panels

222 - Piles

223 - Secondary Steelwork

224 - Trawlboard Deflectors

225 - Cocoon Protective Structures

226 - spare

227 - spare

228 - spare

229 - spare

(13) Manifolds (230 - 239)

230 - Manifolds

231 - Manifold - Linear Block

232 - Manifold - Recoverable Valve Module

233 - Manifold - Chemical

234 - spare

235 - spare

236 - spare

237 - spare

238 - spare

239 - spare

(14) Pipework (240 - 249)

240 - Pipework

241 - Oil Flowline Jumper

242 - Gas Flowline Jumper

243 - Water Injection Flowline Jumper

244 - Spool Pieces

245 - Control and Umbilical Connections

246 - Clamps/Guides

247 - Flowmeter Spools

248 - Flanges

249 - spare

(15) Valves (250 - 259)

250 - Valves

251 - Oil Valves

252 - Gas Valves

253 - Water Injection Valves

254 - Air Valves

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255 - Hydraulic Valves

256 - Methanol Valves

257 - Chemical Injection Valves

258 - Pressure Monitor Valves

259 - Test Valves (16) Cathodic Protection System (260 - 269)

260 - Cathodic Protection System

261 - Anodes - Guidebase

262 - Anodes - Tree

263 - Anodes - Towhead

264 - Anodes - Junction Box

265 - Anodes - Manifold

266 - Anodes - Other267 – Anodes - Pipework

268 - spare

269 – Corrosion Monitoring

(17) Control Systems (270 - 279)

270 - Control Systems

271 - Panels

272 - Control Modules

273 - Umbilicals / Weaklinks

274 - Control System Jumpers

275 - Junction Boxes

276 - Accumulators

277 - Acoustic Module

278 - Transducers / Transponders

279 - Spare

2.3 Sequential Number of the Procedure

Each procedure will be given a sequential number commencing from 001 within the aforementionedComponent Code Group

3 STANDARD PROCEDURES

Standard Procedures will be coded in the same manner as specified in Para 2.

4 REGISTER OF PROCEDURE NUMBERS

The register of the Procedure Codes will be maintained by Shell. Therefore any new procedures thatare created will be correctly categorised and given their unique number by Shell.



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SECTION 2

CHAPTER 6

ANOMALY REPORTING & CRITERIA

CONTENTS

Para Page

1 REPORTING - MSV/DSV ACTIVITIES 3

2

SUBSEA INSPECTION ANOMALY REPORTING 3

2.1 Anomaly Reporting Requirements 3

2.1.1 Levels of Reporting 3

2.1.2

Critical Anomaly Reporting (General) 3

2.1.3 Critical Anomaly Reporting (Leaks) 4

2.1.4 Steel Sub-Structures 5

2.1.5

Concrete Sub-Structures (Brent Bravo, Charlie and Delta) 5 2.1.6 Risers 5

2.1.7 Buoyant Structures (FPSO’s) 6

2.1.8 Existing Anomalies 6

2.2

Anomaly Reporting and Limits – Steel and Concrete Structures 6

2.2.1 Index of Terms 6

2.2.2 Anode Wastage 7

2.2.3

Burial 7

2.2.4 Caissons 7

2.2.5 Cathodic Protection 7

2.2.6

Chain 8

2.2.7 Coating Damage 8

2.2.8 Concrete Condition 8

2.2.9

Corrosion 8 2.2.10

Debris 8

2.2.11 Flooded Members 9

2.2.12 Lack of Integrity 9

2.2.13

Leaks 9

2.2.14 Marine Growth 9

2.2.15 Physical Damage 9

2.2.16 Relative Movement 10

2.2.17

Scour 10

2.2.18 Talon Connector 11

2.2.19 Variance from Specification 11

2.2.20 Wall Thickness 11

2.2.21 Weld Defect 11

2.3

Anomaly Reporting and Limits – Risers, J-Tubes, Pipelines and Umbilicals 12 2.3.1

Index of Terms 12

2.3.2 Anode Wastage 12

2.3.3 Burial 12

2.3.4

Cathodic Protection 12

2.3.5 Coating Damage 13

2.3.6 Corrosion 13

2.3.7 Debris 13

2.3.8

Lack of Integrity 13

2.3.9 Leaks 13

2.3.10 Marine Growth 14

2.3.11

Physical Damage 14

2.3.12 Relative Movement 14

2.3.13

Scour (Pipeline) 14

2.3.14

Scour (Igloos) 15



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2.3.15 Scour (Wellheads) 15

2.3.16

Wall Thickness 15

2.4 Critical (C1) Anomaly Process 16

2.5 Leak Sample Notification and Delivery Ashore 17

FIGURES

No Page

1 Example Sample Analysis Request (SAR) Form 17

2

Blank Sample Analysis Request (SAR) Form 18



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CHAPTER 6

ANOMALY REPORTING & CRITERIA

1 REPORTING - MSV/DSV ACTIVITIES

Consistency, accuracy and completeness of anomaly records is extremely important, to providesufficient information to the relevant engineers, to minimise the amount of re-inspection/ambiguities.

2 SUBSEA INSPECTION ANOMALY REPORTING

2.1 Anomaly Reporting Requirements

2.1.1 Levels of Reporting

Two categories of anomaly are specified with differing reporting requirements.

(1) Category One (C1). Critical; requiring immediate reporting. Not greater than 24hrs from initial

identification.

(2) Category Two (C2). Not Critical; typically issued 14 days after completion of the work.

The anomaly reporting and limits to assign to appropriate category, are highlighted in greater detail inparagraph 2.2 (Anomaly Reporting and Limits – Steel and Concrete Structures) and paragraph 2.3(Anomaly Reporting and Limits – Risers, J-Tubes, Pipelines and Umbilicals).

The operational vessel’s offshore Daily Progress Report (DPR), is to reflect all anomalies identifiedduring the previous 24hr period and their criticality. Where COABIS is utilised, full details of allanomalies raised are included within the DPR automatically for the previous 24hr period. For DPRclarity, due to the potentially high numbers of anomalies raised, only critical (C1) anomaly reports areto be left in the DPR, with non-critical (C2) anomalies removed and replaced by a statement on how

many C2 anomalies were raised for that previous 24hr period.

All anomalies are to be included in the final and interim Job Reports issued. The individual anomaliesshould be updated to reflect any additional information gathered, or remedial action undertaken priorto the Job Report being issued.

Examples of critical immediately reportable anomalies for steel jackets, concrete and buoyant

structures are listed in brief in the paragraphs 2.1.4, 2.1.5, 2.1.6, 2.1.7 and more fully in sections 2.2

and 2.3 below.

2.1.2 Critical Anomaly Reporting (General)

Items falling within the critical category are of two basic types.

(1) Those representing a serious risk to integrity of the installation.

(2) Those where immediate response will generate a significant cost effective action.

Critical anomalies will be reported via the DPR as above. In addition, or where COABIS is not utilised,the individual C1 anomalies will be sent ashore for review within 24 hours. This report is to be sentonce all suitable details have been gathered. These details should include sketches, digital images,video clips (if possible place in Livelink), etc, to suitably establish the nature and extent of theanomaly. Should further investigations be carried out, the subsequent findings are to be updated intothe relevant C1 anomaly and redistributed accordingly.

Prior to sending of the DPR or above C1 anomaly report, the anomaly text and accompanying dataare to be checked for correctness.



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The order in which the C1 anomaly is initially reported, via either the DPR or Anomaly Report, is notfixed and will be dependent on when the anomaly is found and data gathered.

For all C1 anomalies, or where immediate action or further guidance is deemed to be required, theShell Offshore Operations Engineer (OOE), should immediately contact the relevant Shell SubseaOperations Engineer (Job Team Leader), or Duty Engineer (for the sector in which operations pertain),

dependant on availability.

During working hours, the Job Team Leader is to be contacted, who will inform the Shell SponsoringEngineer, who will report to the Technical Authority, if not the same person.

If the Job Team Leader is unavailable, or outside of working hours, the Duty Engineer is to beinformed, who will contact the Job Team Leader; Shell Sponsoring Engineer and/or Technical

Authority, dependant on availability, severity of the findings and actions required.

The Duty Engineer should only give advice, based on suitable knowledge of the systems worked on,or after consultation/referral with the relevant Job Leader, Sponsoring Engineer or Technical Authority(TA) as specified in the workscope. No repair work should be undertaken without suitable instructionwithin this line of communication.

The DPR distribution list will include the operational workscope Job Leader and Sponsor, OffshoreInstallation Manager (OIM), Operations Supervisor (OS) and the Subsea Maintenance & Interventiondepartment Data Management Controller (UIE-T-PS) as a minimum for the workscopes andinstallations covered in the relevant 24hr period. As such notification of any C1 anomaly will besupplied to the controlling installation via the DPR for the previous 24hr period.

Copies of the C1 anomaly report and any associated data are to be e-mailed directly to the ShellSubsea Maintenance & Intervention department Data Management Controller, Inspection departmentteam, workscope Job Leader, workscope Sponsoring Engineer, relevant Installation OIM and OS. Therelevant e-mail addresses are included in the workscope. All C1 anomalies are subsequently heldwithin the COABIS database.

Should a C1 anomaly be downgraded offshore (to C2) since its appearance in the DPR, then the ShellData Management Controller must be notified of its new level of criticality. Should the criticality of a C1anomaly be downgraded offshore after submission of a C1 report ashore, then all parties previouslyinformed of the report must be notified of its new level of criticality.

The above reporting route is documented in Section 2, Chapter 7, Figure 1 – Flow Chart for WorkExecution Reporting.

The specific C1 anomaly process, report distribution and follow up process is charted in section 2.4

below.

2.1.3 Critical Anomaly Reporting (Leaks)

In line with the above, the following is required specifically for leak reporting:

Where a leak is found, a concerted effort is to be made to identify the exact location of the leak.Identify any associated damage, or other cause. If it is not possible to identify the location of the leakthen a statement is to be made in the COABIS report, both anomaly and main, explaining the reasonwhy identification was not possible. This is so that an assessment of the best method of any follow upactions, including inspection by diver can be made. The assumed leak type is to be stated, oil, gas,hydraulic, methanol or other.

The rate of leak is to be estimated and suitably described, with sufficient anomaly video footage takento allow onshore assessment of the rate and location. Take digital still images if appropriate.The anomaly is to state the location of the leak, rate and facility operational status. Provide a suitably

annotated drawing to complement the report and any video/images taken. Description of rate is to berestricted to number of bubbles and rate (i.e. x bubbles per/sec, champagne type, constant,intermittent, etc...). No volume estimate is to be made, unless some measuring device has been used.



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Any leaks identified during the inspection are to be reported to the controlling installation, oncesufficient data has been gathered. For UK installations this is to enable the installation to raise asuitable PON1 notification to the appropriate government agency within 6 hours of being informed ofthe leak. For none UK installations this is again to allow appropriate reporting by the installation to therelevant national authority.

This notification should initially be relayed verbally to the installation, with the Critical C1 anomalyreport subsequently issued as per 2.1.2 above, with full and accurate details of the anomaly to avoidany miscommunication of the leak details. The Critical C1 anomaly report is to be accompanied bysketches, photos and video as e-mail restrictions allow.

This leak data gathering and reporting process is charted in section 2.4 below.

Should sampling equipment be available, unless otherwise stated in a workscope or Master Anomaly,leak samples are to be taken as follows:

Where a new gas leak is identified.

For an existing gas leak where no sample has previously been taken.

For fluids where there is doubt as to the composition of the leak substance, i.e. hydraulic,methanol or other.

No crude oil samples are to be taken unless otherwise requested in a workscope.

Method of sample delivery ashore including notification is covered under section 2.5 below.

2.1.4 Steel Sub-Structures

(1) Missing, torn, buckled, dented, and flooded members.

(2) Cathodic protection.

(3) Weld defects, cracks /linear defects.

(4) Caisson defects.

(5) Talon Joints

(6) Scour

2.1.5 Concrete Sub-Structures (Brent Bravo, Charlie and Delta)

(1) Spalling of concrete exposing internal steel reinforcement through impact or other reasons.

(2) Crack-like opening of construction joints.

(3) Scour.

(4) Tubular steel conductor guide frames anomalies as Steel Sub-Structures.

2.1.6 Risers

(1) Significant physical damage, missing/loose clamps, relative movement and leaks.

(2) Cathodic protection.

(3) Corrosion.

(4) Scour.







0153-001

2-6-8 Am 05 03/12

2.2.6 Chain

(1) Components. Anchor chains/Chain Stoppers.

(2) Anomaly. Loss of link diameter 0-20% (C2). Loss of link diameter 20%, cracking(C1).

Loss of link stud, Kenter Link plug, rock/debris contacting chain (C2).(3) Action Dimension, protect from further wear, video.

(4) Checks. PD, DB, CW, KS, other assignable causes.

2.2.7 Coating Damage

(1) Components. All.

(2) Anomaly. Any significant coating damage to a component (C1/C2 as deemednecessary). Bare metal exposure with significant pitting corrosion C1.

(3) Action. Determine nature i.e. abrasion, coating breakdown (blistering), exposure ofprimer or exposure of bare metal. Where required condition of exposedbare metal i.e pitting, corrosion. Record position from selected datum; takedimensions (l x w x d); video and digital images.

(4) Checks. DB, CR, CP, assignable causes.

2.2.8 Concrete Condition

(1) Components. All on gravity platform.

(2) Anomaly. Concrete spalling (C2) Concrete spalling about embedment plates (C1).

Cracks 1mm (C2) >1mm (C1). Other blemishes categorised in accordancewith OTH 84 206 & OTH 87 261 (C2).

(3) Action. Record extent of anomaly. Reference defect to known datum/attachment.Measure area and depth of loss of cover. Record orientation, length, width

and depth of cracks and mark up limits for future monitoring. Video anddigital images. Extend inspection outside any set area to fully define defect.

(4) Checks. DB, PD.

2.2.9 Corrosion

(1) Components. All except sacrificial anodes and debris.

(2) Anomaly. Pitting 2mm deep (C2).

(3) Action. Dimension, note density of coverage, surface profile, pit gauge readings onpitting, WT readings covering area using a 25mm grid, minimum area to beinspected 100mm sq. Video and digital images.

(4) Checks. AW, DB, CP, WT.

2.2.10 Debris


(2) Anomaly. Hazardous to divers, in contact with risers/structure, causing damage,abrasion etc., blocking inlets, video remaining debris, (C2).

(3) Action. Determine type, quantity and position, check for damage and take CP’s.Remove if a diver/ROV hazard. Video on completion of removal, checkingfor any associated damage.

(4) Checks. PD, CR, CP.



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Am 05 03/12 2-6-9

2.2.11 Flooded Members

(1) Component. Tubular members.

(2) Anomaly. Members not designated, as being flooded and therefore not reflectingdesign intent, or not having previously been identified as being flooded.

(C1).(3) Action. Check flooding in associated members. GVI member, with particular

attention to the end welds, for any evidence of gross defect, or otherpossible cause. Any further inspection requirements, i.e. weld ACFM/MPI,to be requested by Sponsoring Engineer, based on C1 anomaly raised.

(4) Checks. PD, LI, (WD).

2.2.12 Lack of Integrity


(2) Anomaly. Any on caisson (C1). Missing/severed members, missing clamps (C1).Missing/loose bolts/clamps, misalignment (C2). Missing/damaged

anode/anode segment, continuity cable, not associated with AW (C2).(3) Action. Quantify and determine nature, i.e. missing/loose. Determine position from

selected datum, take CP’s, video, digital images.

For missing bolts, check size, replace if possible.

(4) Checks. PD.

2.2.13 Leaks

(1) Components. Any.

(2) Anomaly. Any Leaks (C1).

(3) Action. As per section 2.1.3 above.

(4) Checks. PD, LI.

2.2.14 Marine Growth

(1) Components. Steel members, Caissons and Appurtenances.

(2) Anomaly. NNS & CNS - Hard growth >50mm (C2)ONEgas West – Hard Growth >50mm for below –6m,

>125mm for –6m and above (C2).ONEgas East – Hard Growth >50mm (C2)

Exception – AME-2 300mm (C2).

Soft marine growth >150mm (In the case of anemones, when notfeeding/extended), and/or long filamentous growth, seaweed or kelp >1m

(C2).

(3) Action. Note type of marine growth, percent cover and approximate extent (depthrange), or other as specified in workscope.

(4) Checks. None.

2.2.15 Physical Damage


(2) Anomaly. Any significant impact damage to a component (C1/C2 as deemednecessary).

(3) Action. Determine nature i.e. abrasion/deformation/fracture. Determine position

from selected datum; take dimensions (l x w x d); video and digital images.






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2.2.18 Talon Connector

(1) Components. Relevant conductors.

(2) Anomaly. Any indication of rotational movement 25mm (C1)

Any indication of rotational movement 12mm (C2)

Any indication of cracks or damage to box (C1)

Any misalignment, e.g. - visible opening of the interface of the talon joint (C1)

Average readings of 4; 15-29.9 micro ohms (C2) 30 micro ohms (C1)

Any indication of rotational movement 12mm and 15-29.9 micro ohms (C1)

(3) Action. (C1) rotational movement - measure rotation.

Complete actions as per workscope & standard procedure I-49-057.

(4) Checks. RM, CR.

2.2.19 Variance from Specification

(1) Component. Any.

(2) Anomaly. Any (C2).

(3) Action. Sketch accurately, measure dimensions and distance from specified datum,video, (update UMDB/COABIS onshore).

(4) Checks. LI.

2.2.20 Wall Thickness

(1) Component. Structural members.

(2) Anomaly. 20% loss (C2).

(3) Action. Map area of low WT.

(4) Checks. CR, PD, FM.

2.2.21 Weld Defect

(1) Components. All welds.

(2) Anomaly. Crack/linear indication (C1). Other defects (C2).

(3) Action. Crack/linear indication. Confirm length and depth of crack/linear indicationusing ACFM. On completion measure distance to start of defect from datumpoint, video and digital image.

Grinding up to 5% of nominal WT (or 2mm maximum) to remove surface

defects is permitted without approval. Grinding to a greater depth shall beapproved by the Structural TA.

(4) Checks. CR, PD and previous grinding.





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2.3.5 Coating Damage


(2) Anomaly. Any significant coating damage to a component (C1/C2 as deemednecessary). Bare metal exposure with significant pitting corrosion C1.

(3) Action. For risers, spools etc - Determine nature i.e. abrasion, coating breakdown(blistering), exposure of primer or exposure of bare metal. Where requiredcondition of exposed bare metal i.e pitting, corrosion. Record position fromselected datum; take dimensions (l x w x d); video and digital images.

For concrete coated pipelines - Determine nature i.e. crack, spalling etc.exposure of rebars, underlying corrosion coating, pipe parent metal. Recordposition from selected feature datum; take dimensions (l x w x d); video anddigital images. Note bitumen filled field joints are not to be reported asdamaged unless parent pipe metal is exposed and field joint cladding is notto be reported as coating damage, although where the cladding is a ROVhazard it is to be reported under debris.


2.3.6 Corrosion

(1) Components. All riser, J-tube, pipelines, other pipework.

(2) Anomaly. Pitting 1mm deep (C1).

(3) Action. Dimension, note density of coverage, surface profile, pit gauge readings onpitting, WT readings covering area using a 25mm grid, minimum area to beinspected 100mm sq. Video and digital images.

(4) Checks. AW, DB, CP, WT.

2.3.7 Debris

(1) Components. All.(2) Anomaly. Hazardous to divers, in contact with risers/structure, causing damage,

abrasion etc. (C2).

(3) Action. Determine type and quantity, determine position, remove as a minimum allmetallic debris in contact with steelwork/anodes. Remove if a diver/ROVhazard. Video on completion of removal, checking for any associateddamage.

(4) Checks. PD, CR, CP.

2.3.8 Lack of Integrity


(2) Anomaly. Missing clamps (C1). Missing loose bolts/loose clamps, misaligned (C1).Missing/damaged anode/anode segment (C2).

(3) Action. Determine nature i.e. missing/loose. Determine position from selecteddatum, tighten and/or replace bolts, check size, video, digital images.

(4) Checks. Any.

2.3.9 Leaks

(1) Components. Any.

(2) Anomaly. Any leaks (C1) apart from leaks flexible end connection from vent ports.

Leaks from flexible end connection vent ports, are considered ‘Not

Anomalous’, unless rate is significant indicating non-designed leakage.



0153-001

2-6-14 Am 05 03/12

(3) Action. As per section 2.1.3 above.

Where leak seen from a flexible end connection vent port, positively confirmthis to be the case; clean as required. Make comment in Job CompletionReport, not in anomaly report, unless rate is significant indicating non-designed leakage.

Take suitable video and digital still images (if appropriate).

(4) Checks. PD, LI.

2.3.10 Marine Growth

(1) Components. Risers and J-Tubes.

(2) Anomaly. NNS & CNS - Hard growth >50mm (C2)ONEgas West – Hard Growth >50mm for below –6m,

>125mm for –6m and above (C2).ONEgas East – Hard Growth >50mm (C2)

Exception – AME-2 300mm (C2).

Soft marine growth >150mm (In the case of anemones, when not feeding /

extended), and/or long filamentous growth, seaweed or kelp >1m (C2).

(3) Action. Note type of marine growth, percent cover and approximate extent (depthrange), or other as specified in workscope.

Take suitable video and digital still images (if appropriate).

(4) Checks. None.

2.3.11 Physical Damage


(2) Anomaly. Any significant impact damage to a component (C1/C2 as deemed necessary).

(3) Action. Determine nature i.e. abrasion/deformation/fracture. Determine positionfrom selected datum; take dimensions (l x w x d); video and digital images.


2.3.12 Relative Movement

(1) Components Risers, J-Tubes, clamps and riser elbow/pipelines; Guides.

(2) Anomaly. (a) Apart from Guides (see below), Any Movement (C1).

(b) Not anomalous where there is a designed gap between Riser/J-Tubeand the guide, unless there is associated significant PD or WT loss

20% (C2).

(3) Action. Determine range of movement relative to a fixed datum, check bolts, take

CP’s & video. Take Digital images where associated PD, WT visible. Wheredivers available, measure depth & area of any associated wear.

(4) Checks. PD, LI, CP, WT.

2.3.13 Scour (Pipeline)

(1) Components. Risers, J-Tubes and Pipelines.

(2) Anomaly. 10m of suspension from elbow/tie-in flange, or any subsequent 10msuspension (C1).

(3) Action. Check for possible associated damage. Measure length of suspension(position fix), obtain maximum and average suspension heights (Seeprocedure I-60-003). If suspension at elbow/flange, obtain height ofsuspension and depth of seabed, relative to a known datum.



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Am 05 03/12 2-6-15

(4) Checks. PD, RM.

2.3.14 Scour (Igloos)

(1) Components. Igloo Structure.

(2) Anomaly. Gaps 150mm in height, occurring within or encroaching within 1500mm of

any corner (C2).

Gaps 300mm in height, occurring within or encroaching within 1500mm ofany corner (C1).

Gaps of area (height x depth) 0.75sq.m, not extending within 1500mm ofany corner (C2).

Gaps of area (height x depth) 1.0sq.m, not extending within 1500mm ofany corner (C1).

(3) Action. Check for possible associated damage. Give lengths, heights and locationof scour on a suitable drawing. Take video and digital images.

Block with grout bags, if the vessel has immediate remediation capability.

(4) Checks. PD, RM.

2.3.15 Scour (Wellheads)

(1) Components. Wellheads.

(2) Anomaly. Scour 1.0m from mean seabed level (C2).

Any lack of support to flowline at touchdown from as-built (C2).

(3) Action. Give depth and distance out from conductor of scour bowl relative to mean

seabed. Supply suitable profile drawings on two 90 planes, video anddigital images.

Check for possible associated damage, i.e. jumper connections due toincreased strain. Check any spools/jumpers for lack of support. Obtainunsupported height and length out from tie-in flange or base of gooseneck.

Block with grout bags, if the vessel has immediate remediation capability.

(4) Checks. PD, LI, RM.

2.3.16 Wall Thickness

(1) Components. Risers, J-Tubes, pipework & appurtenances.

(2) Anomaly. 10-20% loss of nominal (C2). 20% loss (C1).

Any lack of support to flowline at touchdown from as-built (C2).

(3) Action. Map area of low WT.(4) Checks. CR, PD.



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2-6-16 Am 05 03/12

2.4 Critical (C1) Anomaly Process

STEP C1 (CRITICAL ANOMALY PROCESS CONTRACTOR VESSEL QA/QCVESSEL SHELL

REP

ONSHORE

DATAMANAGEMENT

CONTROLLER

(UIE/T/PS)

JOB LEADER JOB SPONSORINSTALLATION

OIM/OS

INSPECTIONDEPARTMENT

(UIE/T/PS)

OTHERS

(See Action)ACTIONS

1C1 Anomaly found during Offshore

Operations. Anomaly raised in COABISReport to Shell QA/QC.

Shell QA/QC to inform Vessel Shell Rep

2

Carry out investigation and gather datato obtain full details of anomaly,

as per 0153-001, Section 2, Chapter 6and as agreed with Shell QA/QC

Clean as necessary.Obtain video clips, still images, and create sketches/drawings to fully

illustrate anomaly details.

3 C1 Anomaly is leak of fluid / gas

Vessel Shell Rep to inform controlling installation OIM/OS of leakas soon as possible, providing sufficient information for installationto issue a PON1 to DECC (required within 6hrs of notification), i.e.

Leak type and rate.

4

C1 Anomaly included in

Vessel Daily Progress Report (DPR).(Note step 4 and 5 order may swap)

Anomalies are automatically generated within the DPR produced byCOABIS.

Any anomaly is to be checked for accuracy by the QA/QC prior toDPR production/distribution.

5

C1 Anomaly Reporting Onshorewithin 24 hours of identification (Step 1).

(Note step 4 and 5 order may swap)

Vessel QA/QC e-mails C1 anomaly onshore to the following:Data management Controller (UIE/T/PS), Job Lead, Job Sponsor,

U/W Inspection Department (UIE/T/PS).Vessel QA to place any video clips in designated Livelink 'Vessel

Data Transfer' area

6

Data Management Controller distributes toagreed additional personnel

not included in step 5.

To include Principal Well Integrity Engineer (PWIE - TA1) of any wellissues.

Any additional personel to be confirmed by Job Lead/Sponsor, or,responsibility of Job Lead/Sponsor to distribute as required.No request is to be made of the Vessel QA/QC to distribute.

7

Job Lead confirms C1 to sponsor, and/orasset focal point and formulates action

plan

Job Lead/Sponsor to discuss with others as necessary, who mayinclude:

Subsea Assett Focal Points (UIE/T/PS), Asset Focal Point, PWIE,relevant TA, others...

8

For any additional information gathered,or follow-up actions carried out, COABIS

anomaly to be updated.

Update anomaly with actions carried out and resulting outcome.

9Repeat steps 5 and 6if required by step 8.

Distribute anomaly as required.

10 Anomaly Review

COABIS Anomaly review to be overseen by relevant UIE/T/PSInspection dept. personnel. Review to include relevant personnel,

which may include the Job Lead, Job Sponsor, Subsea Asset FocalPoints (UIE/T/PS), Asset Focal Point, PWIE, relevant TA, others...

COABIS anomaly either Closed, or Master Anomaly created.

Key

Required action to be carried out by.

Persons required to be included in the process step





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2-6-18 Am 05 03/12

Figure 2 Blank Sample Analysis Request (SAR) Form



0153-001

SECTION 2

CHAPTER 7

REPORTING

CONTENTS

Para Page

1 REPORTING - MSV/DSV ACTIVITIES 3

1.1 Reporting Requirements 3

2 JOB COMPLETION REPORT 4

2.1 Report Structure 4

2.1.1 Introduction 4

2.1.2 Section 1 - Introduction 4

2.1.3 Section 2 - Job Completion Summary 4

2.1.4

Section 3 - Anomaly Summary 5 2.1.5 Section 4 - Daily Summary 5

2.1.6 Section 5 - Video Logs 6

2.1.7 Section 6 - Digital Image Logs 6

2.1.8 Section 7 - Anomaly Details 6

2.1.9 Section 8 - Drawings 6

2.1.10 Section 9 - Appendix (or Results) 7

3 ELECTRONIC FILE NUMBERING 7

3.1 Introduction 7

3.2 Numbering System 8

4 VIDEO RECORDINGS 8

4.1 Introduction 8

4.2

Recordings 8 4.2.1 Standard Overlay Page 1 9

4.2.2 Standard Overlay Page 2 9

4.3 Overlays 9

4.3.1 Diver 9

4.3.2 ROV 9

4.4 Labelling and Numbering 9

5 DIGITAL IMAGE REPORT 10

5.1 Digital Images 10

6 JOB CLOSEOUT NOTE 11

FIGURES

1 Flow Chart for Work Execution Reporting 12

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0153-001

CHAPTER 7

REPORTING

1 REPORTING - MSV/DSV ACTIVITIES

Consistency, accuracy and completeness of inspection and intervention records is extremelyimportant as the information provided will become part of the Subsea Operations DepartmentsComponent Oriented Anomaly Based Inspection System (COABIS).

All irregular findings or critical anomalies are to be immediately reported. This may be either via theShell Subsea Operations Engineer (Job Team Leader) or Shell Duty Engineer (for the sector in whichoperations pertain), who will inform the relevant Shell Sponsoring Engineer/Technical Authority. Thespecific reporting route will depend on the severity of the anomaly in question.

The correct method of reporting is given in Section 2, Chapter 6 - Anomaly Reporting & Criteria, andas shown below in Figure 1 - Flow Chart for Work Execution Reporting.

1.1 Reporting Requirements

Reports are to include all work carried out by the vessel. Additional reports may be requested to coverspecific activities such as special projects, top side construction etc. Such reports will be defined at thetime they are requested.

The report shall be submitted to the Onshore Data Management Controller and Sponsors, - NorthernBusiness Units, - Southern Business Unit, as appropriate.

Interim Report Will be compiled on all ongoing works which, due to operational requirements, havea break in the work programme exceeding 14 days, or as otherwise agreed.

Final Report Will be compiled for all completed works, works, which are deemed complete by

sponsor and at year end irrespective of work completion.

Reports are to be compiled, with one signed copy submitted to the Shell Onshore Data ManagementController within 14 days.

The format to be adopted is as detailed in point 2. Where COABIS is utilised the report is automaticallycompiled in this format.

All referencing and reporting shall follow the COABIS format, comprising Cost Code(Procedure/Workscope number - See Section 1, Chapter 1, Point 7.2), Component Task (See Section2, Chapter 4, Point 2) and Component Numbering System (See Section 2, Chapter 5, Point 2.2).

Special attention shall be paid to the final presentation of the report, its accuracy, completeness of allreferences within the Component Task Sheet (CTS) system and all relevant details such as jobsummaries, diagrams, videos, digital images, ‘As-built’ data, Procedure Changes and Sub-contractorsreports.

These details are to be checked by the Shell QAQC/Coordinator, prior to distribution to the ShellOffshore Operations Engineer (OOE), Contractors Offshore Construction Manager / Offshore Managerwho will further check the report to confirm its completeness.

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0153-001

2 JOB COMPLETION REPORT

2.1 Report Structure

The Job Report is to adopt the format as specified in the sections below. This report format is to beused for all IMR and Project works carried out. Any of the sections listed below which are not required,may be omitted from the Job Report.

The report is to be bound, front and back by gold card for Final reports, and by blue card for Interimreports. These covers are supplied by the Shell Onshore Data Management Controller.

Interim reports are required for workscopes/procedures which have not been completed, but wherefurther work will be carried out. If no further work is to be carried out by the vessel that last worked onthe procedure, then an Interim report is required from the vessel. If a vessel is to return to carry outfurther works on a procedure, then the requirement for an Interim report on completion of the earlierworks will depend on the time interval between the two interventions. This decision will be made bythe Shell Offshore Representative, or as advised by the Job Leader.

Where COABIS is utilised the Job Report is automatically generated by the COABIS System. Wherethis is the case, all information, with the exception of the Introduction Section, is entered into COABISbefore the Report is generated.

Where other electronic files are referenced in the Job Report, these files must be issued along with theJob Report. See Point 3 – Electronic File Numbering.

2.1.1 Introduction

The report is sectioned as follows:

SECTION 1 Title Page, Contents and Introduction

SECTION 2 Job Completion Summary, by CTS number

SECTION 3 Anomaly Summary, and listing by CTS number

SECTION 4 Daily Summary, details in full by CTS number

SECTION 5 Video Logs

SECTION 6 Digital Image Logs, Digital images - colour prints

SECTION 7 Anomaly Details

SECTION 8 Drawings

SECTION 9 Appendix and/or Results

2.1.2 Section 1 - Introduction

This should be a brief description of the work carried out. State whether the report is an Interim (bluecover) or Final (gold cover) and give the start and end dates of the work. It shall also list the following:Name of Installation, Name of Contractor(s), Name of Vessel(s), Job Title and Job Number.

2.1.3 Section 2 - Job Completion Summary

This Section gives a précis job completion summary of all Workpacks (CTS’s) raised under the JobNumber (Cost Code), including a brief description of any outstanding work and reason for non-completion, including any remedial work. Any CTS not started requires to be listed, with a statementas to why.

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0153-001

2.1.4 Section 3 - Anomaly Summary

This section gives a complete summary listing of all anomalies, by anomaly number.

Each entry is to include CTS, Anomaly number, Criticality, Anomaly Type, Component Number, VideoReference and précis description of the anomaly, i.e. 'Excessive debris & Anode wastage', 'Crack like

indication'.

2.1.5 Section 4 - Daily Summary

This is a daily diary of events carried out during the workscope operations. The summary is listed inorder of CTS and date.

References should be made to any relevant documentation raised during the operation, i.e. Change toProcedure documents, Pressure Test results raised, etc. Hard copies of any such document, includingsignatures, are to be included in the Appendix section of the report.

2.1.5.1 Inspection Workscopes

For inspection workscopes, the daily summaries shall consist of a brief summary of the work carriedout each day. A summary status of any readings taken may also be included and any other pertinentfacts that may illustrate any problems encountered or achievements during the operations. Anyoutstanding tasks requested should be listed. A typical entry is as follows:

DVI of the –20m CGF guides 35-107, 35-110 and 35-120 were completed by diver. From this survey,physical damage was identified at guide 35-107, with all other guides free from defect. For furtherdetails of the anomaly, see the referenced anomaly report.

Reference Video Tape BA/VSL2004-01 Anomaly Report BA/VSL2004-03Drawing BA/VSL2004C101-01-01Digital Image Log BA/VSL2004-01, Digital Images 01, 02 & 03.

The required Wall thickness (WT) readings were outstanding and will be carried out at a later date.

The ROV completed the GVI of the –20m CGF. No physical defects were identified. Scaffold debriswas found during the survey, with no associated damage.

Reference Anomaly Reports BA/VSL2004-05, 06 & 07

CP readings ranged between –950mV and –1002mV. Full details are contained within the Resultssection of this report.

Marine growth levels were within specification. Full details are contained within the Results section of

this report.

Reference Video Tape BA/VSL2004-02Results CP & Marine Growth Listings

Detailed results should not be entered in the summary. These should be presented, if necessary, inSection 9 (Results) and/or Section 8 (Drawings).

2.1.5.2 Construct ion Workscopes

For construction workscopes, a detailed summary is required explaining clearly actions taken,problems encountered, remedial actions, reasons for any deviations from procedure, any relevanttimings and platform assistance. The information should be succinct, with repetitive activities, i.e. bolt

tensioning, described only once unless carried out in a different manner, apart from references to thelikes of final tensioning pressures, and serial numbers, which may or may not differ.

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0153-001

2.1.10 Section 9 - Appendix (or Results)

This section is to include all data referenced within the Daily Summary, not included within theprevious sections of the report.

The title of this section can be amended as required or, additional sections created, pertinent to the

documents to be contained within the report, i.e. Appendix – Pressure Test Charts, Results – PEC.

2.1.10.1 Inspection Workscopes

The section should contain referenced Change Instructions and any results that have been requestedin the Scope of Work, or that are required as per any Standard Procedure used. The type of results tobe included are as follows:-

• Marine Growth Survey Data - results listing;

• Cathodic Protection - results listing or Standard form (See I-60-004);

• ACFM - Listing of ACFM files and any graphical representations (See I-15-001);

• MPI (See I-15-001);

• PEC results (print out of PEC 2D graphics);

• Other miscellaneous.

Alternatively, some results may be included in any drawings produced for Section 8.

Where the above results are contained on an electronic file, i.e. MG, CP, PEC & ACFM, these are filesare to be submitted along with the report. Where possible a system of numbering is to be adoptedwhereby the files are automatically associated with the Job Number and CTS. The numbering system

to be adopted for these different files is reported under point 3 – Electronic File Numbering.

2.1.10.2 Construct ion Workscopes

The section should contain hard copies (signed where applicable) of any relevant documentationraised during the operation, i.e. Change to Procedure documents, Pressure Test results raised, etc.

If Shell EPE so requires, specialist sub-contractors may submit reports in addition to the computeriseddata. Any such reports will be summarised and referenced in the relevant summary and included inSection 9.

3 ELECTRONIC FILE NUMBERING

3.1 Introduction

Where electronic files accompany a Job Report, each file requires a unique identifier.

The numbering system adopted should reflect a combination of the following attributes:

File Type, Platform/Facility, Vessel, Year, Job Number, CTS, then an incremental numbering system.

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0153-001

3.2 Numbering System

The following lists the numbering system that is to be adopted for each individual type of file:

• Job Report: AA2005C101

(Platform/Year/Last 4 Digits of Job Number) This is the same as the job number.

• Drawing Number: DWG-AAVSL2005C101-02-01

(File Type-Platform/Vessel Code/Year/Last 4 Digits of Job Number-CTS-SequentialNumber)

• Digital Image No.: PH-AAVSL2005C101-03-01-02

(File Type-Platform/Vessel Code/Year/Last 4 Digits of Job Number-CTS-Log No.-Image No.)

• Change Instruction: CI-AAVSL2005C101-01

(File Type-Platform/Vessel Code/Year/Last 4 Digits of Job Number-Sequential Number)

• Closeout Report: COR-AAVSL2005C101

(File Type-Platform/Vessel Code/Year/Last 4 Digits of Job Number)

• Miscellaneous Files: MISC-AAVSL2005C101-01 (Other documents not covered above)

(File Type-Platform/Vessel Code/Year/Last 4 Digits of Job Number- Sequential Number)

• Cathodic Protection Results CP-AAVSL2005C101-01

(File Type-Platform/Vessel Code/Year/Last 4 Digits of Job Number-CTS)

• Marine Growth Results MG-AAVSL2005C101-01

(File Type-Platform/Vessel Code/Year/Last 4 Digits of Job Number-CTS)

Other inspection software files, such as PEC generate their own file numbering system, which isunique.

4 VIDEO RECORDINGS

4.1 Introduction

Video recordings are to be made on Super-VHS colour cassette for the original master tape. One copyis to be supplied on S-VHS. Additional copies or, compilation tapes may be required on either S-VHSor VHS, as requested, on an ad-hoc basis.

4.2 Recordings

Video standards are to comply with those stated in Section 1, Chapter 3 (Equipment), Point 1.6, andas stated in the contractual agreement.

The narrative is to be recorded on channel one only, leaving second channel clear for dubbingpurposes.

The first 45 seconds of the tape is to be left blank. Immediately after, the description of the contents ofthe videotape is to be verbally recorded, whilst simultaneously displayed in the form as given for page1 shown below.

Prior to operations being recorded against each new CTS, the description of the contents of theensuing section of video tape is to be verbally recorded, whilst simultaneously displayed in the form asgiven for page 2 shown below.

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4.2.1 Standard Overlay Page 1

Shell Expro - Vessel (name)

Contractor:

Tape No:

Job No:

Title:

Time and date to be superimposed on the video without obscuring the subject matter.

4.2.2 Standard Overlay Page 2

CTS Number:

Component No:

Task Description:

Depth Range:

Time and date to be superimposed on the video without obscuring the subject matter.

4.3 Overlays

Video overlays are required for all recordings, to be superimposed without obscuring the subjectmatter. The content varies dependant on the spread type used for the recording, Diver or ROV.

4.3.1 Diver

As a minimum, Time and Date are to be recorded as well as a brief description of task being carriedout, and component where suitable, i.e. for inspection tasks.

4.3.2 ROV

As a minimum, Time, Date, Bathymetric Depth and Heading are required. In addition for inspection,the component being inspected is required, or for construction purposes a brief description of the task.

For seabed survey work, or as specified in the workscope, the ROV’s position is required to bepermanently displayed in the format Eastings and Northings, supplied as a live feed from Survey Data.

4.4 Labelling and Numbering

Shell specific Video Labels can be obtained from the Shell Onshore Data Management Controller. A Microsoft Excel form (Shell Video Label.xls) is available for the filling in of these labels.

Where these labels are not supplied, the Contractors own labels may be utilised. These should clearlynote the Tape Number; Location; Job Number; Relevant CTS’s; Vessel; Tape Start and End Dates;Description of Tasks covered; Contractor Name; Relevant Spreads used (ROV, SAT).

Each tape, including copy, is to be supplied along with its own Video Log.

The Shell Video Tape numbering system is based on the facility being worked at, Media Prefix (Vesselor Platform) which is year specific and then a sequential number starting from 01 for each MediaPrefix, as follows: BA/VSL2005-01.

With this numbering system it should be noted that if a vessel has worked for Shell on more than oneoccasion in the same year, then there is a possibility for duplication of video numbering if the vessel isto work at the same facility on those occasions. This numbering system is automatically generated byCOABIS, where such duplications should not occur.

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Where COABIS is not used to control video operations, the Contractors own numbering system canbe used, but this should allow no replication of tape numbers.

5 DIGITAL IMAGE REPORT

Colour negative photographs are no longer to be used.

Digital Images are required of any anomalies (see Section 2, Chapter 6, Points 2.2 and 2.3),where the image(s) can provide suitable illustration of the defect. Images may also be required whichshow aspects of a particular job and subject, relevant to a workscope. Images should be taken as amatter of course by the Data Recorder based on the above, and where specifically requested by theworkscope, or Shell Offshore Representative. Where possible some form of scale should be included.

As stated above for the Job Report, Point 2.1.7, Section 6 - Digital Image Logs, a Digital Image Log isrequired, with hard copies of each digital image to be included with the submitted Job Report.

The Shell standards required for the taking of Digital Images, are specified in Section 1, Chapter 3,Point 1.7.

5.1 Digital Images

Selection and editing (enhancement) of images, from those taken, will be carried out offline, with theimages included within the report restricted to only the most appropriate, based on the above.

All images should be supplied in .JPG format, with the file size to be kept to a minimum, withoutaffecting the quality of the image significantly.

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6 JOB CLOSEOUT NOTE

For all work completed by the Contractor, the Shell Offshore Operations Engineer, after consultationwith all parties involved (Superintendent, Dive/ROV Supervisors, Project Engineers, Riggers, etc.)will complete a Job Closeout Note. The note will take the following format.

SUBSEA OPERATIONS DEPARTMENT JOB CLOSEOUT NOTE

Job Number:

Job Title:

Execution Date:

Weather Conditions: Vessel:

Contributors:

Safety: (How it was or could be made safer)

•

Execution Concept: (Practicality, appropriateness, suggested alternatives for the future)

•

Operational Workscope: (Clarity completeness, accuracy, timeliness, suggestions for improvements)

•

Equipment: (Applicability, performance, condition, suggested modifications)

•

Work times: (In Water Times not Vessel)

• Planned : hrs

• Actual : hrs

• Special Circumstances :

Technical Publications: (Corrections/suggestions to UMDBs or Standard Procedures)

•

Other Comments:

•

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2-7-12 Re-issue 04/05

This will be submitted along with the Job Completion Report, and any other data, in both hard copyand electronic format, complete with referenced attachments, such as Change to Procedures andTRA’s. This will then be distributed to the Project Subsea Operations Engineer (Job Leader).

Where COABIS is used, the electronic file will be saved within the COABIS database.

EXECUTE WORK

TO

OPERATIONAL WORKSCOPE

RECORD

DATA

PRODUCE

VIDEO TAPES,

DIGITAL VIDEO, AND

VIDEO GRABS

DAILY

PROGRESS

REPORT (DPR)

DATA

CRITICAL

(C1)

ANOMALY

REPORT

PRODUCE

DRAWINGS

COLLATE CHANGE

TO PROCEDURES,

SUB-CONTRACTOR

REPORTS, ETC.

PRODUCE HARD

COPY OF

FINAL/INTERIM

REPORTOFFSHORE

SUBSEA

OPERATIONS

ONSHORE

SUBSEA

OPERATIONSDATA

MANAGEMENT

CONTROLLER

(EPE-T-PS)

SUBSEA

OPERATIONS

ENGINEER

(JOB LEADER)

FOR REVIEW

DATA

MANAGEMENT

CONTROLLER

(EPE-T-PS)

MASTER

REPORT TO

SPONSOR

COPY

REPORT TO

JOB FILES

COPY

REPORT TO

CONTRACTOR

MASTER VIDEO TO

EXTERNAL

ARCHIVES

COPY OF VIDEO

TO LOCAL

ARCHIVES

(2 YEARS)

COPY

REPORTS

TO

FILES

TECHNICAL

AUTHORITY

(If not Job Sponsor)

DATA

MANAGEMENT

CONTROLLER

(EPE-T-PS)

SUBSEA

OPERATIONSENGINEER

(JOB LEADER)

JOB

SPONSOR

DUTY

ENGINEER

Figure 1 Flow Chart for Work Execution Reporting



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SECTION 3

INSPECTION PROCEDURES

(EXCLUDING PIPELINES AND RISERS – SEE SECTION 5)

CONTENTS

STANDARD INSPECTION TASKS

I 01 003 DEBRIS SURVEY AND RECOVERY

I 01 007 GENERAL VIDEO SURVEY

I 06 001 SEABED PROFILE AND SCOUR SURVEY

I 06 003 LINEAR PROFILE SCOUR SURVEY

I 10 001 DIMENSIONAL DAMAGE SURVEY TO STEEL STRUCTURES

I 15 001 WELD INSPECTION

I 15 002 WALL THICKNESS & ULTRASONIC INSPECTION - GENERAL

I 15 003 FLOODED MEMBER DETECTION

I 20 001 CONCRETE SURFACE AND DAMAGE INSPECTION

I 20 002 GENERAL CONCRETE SURFACE INSPECTION - SUBSEA AND TOPSIDE

I 30 001 SEAWATER INLET INSPECTIONI 32 001 BOAT LANDING AND BARGE BUMPER SURVEY

I 43 001 CAISSON INSPECTION

I 49 057 TALON JOINT INSPECTION

I 60 004 CATHODIC PROTECTION MONITORING

I 97 001 INSPECTION OF ABANDONED / SUSPENDED WELLHEAD

I 97 002 INSPECTION OF SUBSEA TREE (Production and Water Injection)

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PROCEDURE I 01 003

DEBRIS SURVEY AND RECOVERY

CONTENTS

Para Page

1 INTRODUCTION 3

2 TASKS 3

2.1 Standard Tasks 3

2.2 Optional Tasks 3

3 OPERATING PROCEDURE AND SPECIFICATION 3

3.1 Inspection Qualifications 3

3.2 Structural Debris Survey (VD-ROV / DB-CHK) 3

4 OPTIONS 5

4.1

Pre-Diver Intervention Survey (VI-ROV) 5

4.2

Debris Recovery/Removal (DB-REM) 5

4.3 Mud/Drill Cuttings Survey (DM-STD) 5

5 REPORTING 5

5.1 Final Report 5

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PROCEDURE I 01 003

DEBRIS SURVEY AND RECOVERY

1 INTRODUCTION

The work method is to be applied to a general video survey by an ROV of debris, including mud anddrill cuttings, on or around a structure, pipeline or any other underwater facility, with the possibleeventual removal/recovery of the debris by diver or ROV.

This procedure may be applied as a ‘Pre-Diver Intervention Survey’ by ROV, to assess whether theworksite is clear from hazardous debris above and in the vicinity of the divers worksite. See 4.1.

2 TASKS

2.1 Standard Tasks

The following Listed tasks are always to be invoked.

VD-ROV (DIV) - ROV (Diver) Video

DB-CHK - Visual Debris Check

2.2 Optional Tasks

The following work tasks are optional and will either be explicitly called for in the Workscope, or be asdictated by diver safety.

VI-ROV - ROV Worksite Check

DB-REM - Debris Removal

DM-STD - Standard Dimensional Survey (Mud/Drill Cuttings Survey)

Should additional activities be carried out or anomalies noted, suitable work tasks and task codes maybe added to cover works.

Should anomalies be noted, they are to be reported and acted upon as per Section 2, Chapter 6,‘Anomaly Reporting & Criteria’, and as directed by the Shell Offshore Representative.

3 OPERATING PROCEDURE AND SPECIFICATION

3.1 Inspection Qualifications

The inspection is to be carried out by ROV, under the guidance of a CSWIP 3.3u or 3.4u InspectionController. Debris clearance maybe carried out by any grade of diver or ROV Pilot.

Should divers be required to investigate any identified anomaly in greater detail, and then this shouldbe carried out by a CSWIP 3.1u/3.2u diver, under the guidance of a CSWIP 3.4u Inspection Controller.Reference Standard Procedures I-10-001 and I-20-003, ‘Dimensional Damage Surveys to Steel andConcrete Structures’, and I-90-002, ‘Pipeline Damage Inspection’.

3.2 Structural Debris Survey (VD-ROV / DB-CHK)

The ROV will carry out, and fully video record, a general visual inspection of all items of debris on orwithin 3m of a member, i.e. on the seabed, and on or within 3m of a pipeline or subsea facility.




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The purpose of the survey is to record the following information on debris located:

(1) Location.

(2) Description, damage if any.

(3) Size and quantities.

(4) Estimates of mud or drill cutting build up, where applicable.

Particular attention is to be given to large or hazardous items of debris, including notes as to wheredebris has come from i.e. section of caisson fallen from EL-28m. Large or hazardous items of debrisare to be clearly marked on a structural layout drawing or a seabed plan.

No cleaning is required. However, should an area of damage be located which may be attributable toan item of debris and is obscured by marine growth, then all marine growth is to be removed and thearea fully investigated using standard anomaly reporting procedures.

The survey may be conducted using SIT to establish the location of debris, or extent of mud and drill

cuttings. Where items of debris are identified, colour views are required for definition, and to ascertainthe presence of any associated damage.

Camera movement must be slow and deliberate; lighting must be adequate to give good colourrendition. Ensure that lighting and viewing is optimised to avoid flare and flare out. Standoff and focusis to be optimised.

Where possible the camera and lights are to be orientated at right angle to inspection surface to giveoptimum viewing, as viewing at differing angles will cause flare on screen close to subject and fadeout at the far edges of the screen. The areas to be inspected should be covered in a logical order toease subsequent topside interpretation.

The video survey is to be carried out at a speed that is slow enough to allow the observer toadequately observe, comment on and note all items of debris.

All route details should be mentioned i.e. moving from node ref. 15110 down diagonal bracing 13140. At anode No. 61003, large section of tubular debris lying across anode, no damage noted, length 3mby 250mm diameter approximately. Continue along member 13140 towards node ref. 15220.

Components should be identified as they appear in the camera's view, not when they appear in thepilot's view unless coincident. Periodically, reference should also be made to depth and direction.

The camera standoff is to be adequate so as to show the subject without loss of definition. Wherenecessary, the standoff distance should be increased to show an overall view of the debris andsurrounding area.

Other than in exceptional circumstances, the camera is to be held vertical. If the camera is rotated, theextent and direction of the rotation must be frequently mentioned on the video commentary. Anycamera tilt must be described, in terms of degrees up or down, in the commentary.

Reference should be made of all salient points of interest in the video narrative and on the video log.

Additional findings of relevant importance must be noted and sufficient coverage made in order toassess the situation. Consideration should be given to the taking of Digital Still Images, where theimage would clearly show significant, hazardous or anomaly related debris.




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4 OPTIONS

4.1 Pre-Diver Intervention Survey (VI-ROV)

A Task Risk Assessment (TRA) is required to be performed prior to any diver operations. The TRAshould identify those areas required to be inspected by ROV, prior to diver deployment to the worksite.

The areas for inspection should be assessed based on the divers worksite in relation to the structureabove, and areas where other ROV/Diver activities may be conducted at the same time as the specificdiver tasks, in case these operations may cause objects to be dropped in the vicinity of the workingdiver below.

Unless specifically requested in the workscope, these pre-diver intervention surveys are not requiredto be recorded on video. Where items of potentially hazardous debris, or other potential hazards areidentified, then these should be recorded.

4.2 Debris Recovery/Removal (DB-REM)

Unless specified in the workscope, debris will be removed from the component on which it is attached

and placed on the seabed away from the structure. Attempts should be made to lay the debris in setlocations, which are then to be either referenced to known points on the structure, or preferablyposition fixed. The debris should be laid as best as possible, to prevent it from becoming a snagginghazard. Do not relocate debris into the possible footprint areas of Jack-ups.

As per debris anomaly criteria, remove only items of debris that are hazardous to diver or ROV, or withrespect to risers, all contacting metallic debris is to be removed. Debris that is deemed to be causingsignificant physical damage to the component should only be removed after discussion with theOffshore Shell Representative, based on advice from the responsible Structural Engineer.

Debris to be recovered will be specified in the workscope, designated by the Shell OffshoreRepresentative, or as identified in the Task Risk Assessment (TRA) conducted as a result of ROVfindings prior to.

The debris will be recovered to the surface by whatever means is considered safe and suitable.

Having removed the debris, the area of contact, if any, is to be inspected for damage. Any damagenoted is to be fully reported. Depending on type of damage noted further inspection may be required,and if necessary will be detailed by the Shell Offshore Representative, acting on instructions from thesponsoring engineer.

4.3 Mud/Drill Cuttings Survey (DM-STD)

For assessment of build up of mud or drill cuttings, sufficient coverage is to be made in order toassess the overall situation. If specified in the workscope, ROV bathymetric readings are to be taken

to obtain a contoured profile of the extent of mud/drill cuttings. These may be obtained from spotreadings using the ROV’s position, manually recorded against an as-built drawing, or position fix, or ifspecified in the workscope for more accurate detail by continuous survey data of ROV position,altimeter and depth.

Dependant on the type of data gathered, either a representative sketch, or more detailed scaleddrawings shall be produced giving a profile of the build up.

5 REPORTING

5.1 Final Report

The Job Completion Report is to précis the results of the inspection, and any subsequent actions as

per the points of interest listed above. Reference section 2, Chapter 1, Section 3.1.5.




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All anomalies are to be referenced, with a general statement made concerning the types and extent ofanomalies identified. Any C1 anomalies are to be commented on more specifically. Other referencesare to be made to any digital still images and drawings.

Sketches are required, either scanned, AcadLT or other proprietary drawing format, of any majordefects or debris that cannot be suitably documented by anomaly report and digital images alone.

Mud/Drill Cuttings profiles are to be produced based on the type of information obtained, as discussedin 4.3.



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PROCEDURE I 01 007

GENERAL VIDEO SURVEY

CONTENTS

Para Page

1 INTRODUCTION 3

2 TASKS 3





3.2 General Video Survey (VI-GVI / VD-ROV) 4

3.2.1 General 4

3.2.2 Anode Wastage (VI-AW) 5

3.2.3

Steel and Concrete Structures 5

4 OPTIONS 5

4.1 Cathod ic Potential (CP) Monitoring 5

4.2 Above Water Inspect ion 6

5 REPORTING 6

5.1 Final Report 6




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0153-001

PROCEDURE I 01 007

GENERAL VIDEO SURVEY

1 INTRODUCTION

The work is to be applied to a general video survey by an ROV, of most underwater facilities such assteel and concrete structures, buoys, FPSO’s, the UMC, etc.

Note: Subsea Trees, igloos and pipelines have their own procedure, see Section 5.

In exceptional circumstances it may be required for divers to carry out the survey, due to access ortidal conditions. In these cases the methodology to be adopted is the same, as best as practicable.

The purpose of the survey is to visually inspect a large area for possible damage, missingcomponents, lack of component integrity, leaks, debris, anode condition, marine growth coverage andvariation to specification.

During the course of the general survey, Cathodic Potential (CP) data may also be gathered fromcomponents as specified in the workscope.

2 TASKS

2.1 Standard Tasks


VI-GVI - General Visual Inspection

VD-ROV - ROV Video


MG-GEN - Marine Growth Survey

VI-AW - Anode Wastage Measurement

2.2 Optional Tasks

The following work tasks are optional and will be explicitly called for in the Workscope.

CP-PRX - Proximity Measurements

DM-SCR - Scour Survey

VI-TOP - Topside Inspection

PH-TOP - Topside Digital Still Images






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The inspection is to be carried out by ROV, under the guidance of a CSWIP 3.3u or 3.4u InspectionController, or CSWIP 3.1u/3.2u diver, under the guidance of a CSWIP 3.4u Inspection Controller.

3.2 General Video Survey (VI-GVI / VD-ROV)

3.2.1 General

The video survey is to be taken of all components, including anodes, as specified in the ComponentTask Sheet (CTS) or as directed by the Shell Offshore Representative. Continuous video recording isrequired throughout the survey. The purpose of the survey is to check steel members/nodes andconcrete surfaces for any gross damage; variation to specification; debris; lack of integrity; anodewastage; marine growth levels and any leaks.

The inspection is to commence with a SIT view of the general area, to confirm the correct componenthas been identified, with reference to known local components, i.e. Leg B1. The remainder of the

survey should be conducted in both SIT for overall coverage and colour for more detail, to give thebest overall coverage of the component inspected. If visibility allows, the preference is for the moredetailed colour views. Where practicable, i.e. member (excluding legs and piles), guide inspection, thefull width of the component should be in view.

The video survey is to be carried out at a speed that is slow enough to allow the observer toadequately observe, comment on and note the condition of the structure. Camera movement must beslow and deliberate. Lighting must be adequate to give good colour rendition. Ensure that lighting andviewing is optimised to avoid flare and fade out. Standoff light and focus is to be optimised.

Where possible the camera and lights are to be orientated at right angle to inspection surface to giveoptimum viewing, as viewing at differing angles will cause flare on screen close to subject and fade outat the far edges of the screen. The areas to be inspected should be covered in a logical order to ease

subsequent topside interpretation.

All route details should be mentioned i.e. ‘Commencing survey from node 15110, down diagonalbracing 13140, on outboard side of member. Proximity reading adjacent node –920mV. Passing 1

st

anode which is approximately 20% depleted, active and appears secure… Continuing down diagonalbracing, now reached end node 15220. Overall marine growth cover 50% hard, 15mm thick, 10% soft,50mm thick. No debris or anomalies observed. Survey complete.’

Describe marine growth as hard or soft, giving estimated thickness and percentage of cover of each.

No removal of marine growth is required unless specified or unless on anomaly is suspected.However, should cleaning be required it should not take place prior to any CP survey, unlessoperational constraints dictate otherwise, and with the prior consent of the Shell OffshoreRepresentative.

Components should be identified as they appear in the camera's view, not when they appear in thepilot's view unless coincident. Periodically, reference should also be made to depth and direction.

The camera standoff is to be adequate so as to show the subject, without loss of definition. Wherenecessary, the standoff distance should be increased to show a larger area i.e. complete node.

Other than in exceptional circumstances, the camera is to be orientated in the vertical plane. If thecamera is rotated, the extent and direction of the rotation must be frequently mentioned on the videocommentary. Any camera tilt must be described, in terms of orientation, up or down, in thecommentary.

Reference should be made of all salient points of interest in the video narrative. The video lognarrative should only contain references to anomalies, or other salient points, i.e. poor visibility, etc.




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Additional findings of relevant importance must be noted and sufficient coverage made in order toassess the situation.

Digital Still Images (PH-DIG) are to be taken of any anomalies or other areas of interest. These maybe supplemented by suitable drawings to show the location, size and details of the item of interest.

3.2.2 Anode Wastage (VI-AW)

The presence and location of anodes are to be confirmed as per UMDB layout drawings.

Anode attachments are to be inspected for integrity, including any bonding/earth/continuity cables.

Where multiple anodes are present on a member, component, or for bracelet anodes, anode wastageestimation is to be given as an average for all individual anodes on a component. Where multipleanodes are present on a component, anomalies are only to be raised for individual anodes missing or+90% depleted anodes, unless otherwise specified in relevant Master Anomalies.

A guide to estimate percentage wastage on an anode is given below:

0-5% LOSS - ANODE AS NEW, WITH CORNERS WELLDEFINED AND NO PITTING.

6-20% LOSS - ANODE IN GOOD CONDITION,CORNERS ROUNDED, SLIGHT PITTING.

21-50% LOSS - ANODE DETERIORATED, LOSINGSHAPE AND WITH GENERAL PITTING.

>50% LOSS - ANODE IN VERY POOR CONDITION.METAL FROM SUPPORT BRACKETSHOWING. EXTENSIVE PITTING.

ANODE DEPL ETION SCHEMATIC

3.2.3 Steel and Concrete Structures

For the inspection of steel and concrete structures, the recording of data will be gathered from oneconvenient side only for structural members up to and including 30inch (760mm) diameter. Forlarger members recording of data will be gathered from two opposing sides. However, on very largemembers, i.e. structural legs, concrete shafts etc, it may be necessary to view from several sides tofully cover all detail.

4 OPTIONS

4.1 Cathod ic Potential (CP) Monitor ing

During the course of the General Video Survey there may be a requirement to gather CP data.The full extent and location of readings required for specific facility types will be specified in theworkscope, and will be included within the COABIS task listing for each individual component.

The CP probe is to be hard wired into the video overlay such that the CP readings are continuouslydisplayed on the video screen during the ROV survey. CP readings are to be included in the videocommentary.

For steel structure members (component type 11, 12, 13, 14), CP readings are to be taken at bothnode ends and on both sides of the member. On conductor guide frame members (component types




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35, 36), on both steel and concrete structures, CP readings are to be taken both sides of the memberat one location, adjacent a node, ensuring that over the complete CGF, all nodes are covered.Readings are, as best as practicable, to be taken away from anodes.

All readings are to be taken prior to any cleaning that may be specified in the workscope, or requiredas part of an anomaly investigation.

Proximity probes are the preferred method for obtaining the required readings. Contact probes shallnot be used without the prior approval from the Shell Offshore Representative acting on advice fromthe responsible Structural Engineer.

If CP readings on anodes are specifically requested in a procedure, or required as part of an anomalyinvestigation, then disturbance of any oxide layer on the anode is to be avoided.

Calibration data is to be noted and verified before and after each dive. Reference procedure I-60 004 –Cathodic Protection Monitoring.

4.2 Above Water Inspection

Topside inspection may be required to compliment platform based topside inspection.

If requested in the workscope, a topside visual inspection of specified components between LAT andthe under deck of the platform, paying particular attention to the region from LAT to +3m. Only grossdefects (C1 category) are to be reported.

Digital Images may be requested by the workscope, of the following views:

(1) Of all 4 faces from water level to under deck level.

(2) And/or of overall views of the platform from 2 opposing faces.

These should be taken on an opportunity basis only, with no specific vessel move made to obtainthese images, unless specifically requested in the workscope.

5 REPORTING

5.1 Final Report

The Job Completion Report is to précis the results of the inspection, and any subsequent actions asper the points of interest listed above. All anomalies are to be referenced, with a general statementmade concerning the types and extent of anomalies identified. Any C1 anomalies are to becommented on more specifically. Other references are to be made to any digital still images anddrawings.

If not anomalous, reference is to be made to any marine growth results taken, confirming the locationwhere the data can be obtained, i.e. COABIS database.

The maximum and minimum of all CP readings taken are to be reported for a specific section of asurvey, i.e. CTS or specific elevation, or where a section of a survey has been conducted during aspecific dive. Reference should be made confirming the location where the full survey data can beobtained, i.e. COABIS database.

Any other specific inspection tasks requested in the workscope are to be commented upon. If the taskcould not be completed, a statement is required stating reasons.




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PROCEDURE I 06 001

SEABED PROFILE AND SCOUR SURVEY

CONTENTS

Para Page

1 INTRODUCTION 3

2 TASKS 3





3.2 Scour Survey – Steel Structures 3

3.2.1 Survey 3

3.2.2 Datum 4

3.2.3

Scour Bowls 5

3.2.4 Buried Members 5

3.2.5 Jacket Piles 5

3.3 Scour Survey – Concrete Gravity Based Structures (GBS) 6

3.3.1 Northern - (Brent B, Brent C, Brent D, Dunlin A & Cormorant Alpha) 6

3.3.2 ONEgas - (East – F3-FB-1P) 6

4 OPTIONS 6

4.1 ROV Seabed Mapping (DM-STD) 6

4.2 Specialist Seabed Mapping 7

5 REPORTING 8

5.1 Final Report 8

FIGURES

No Page

1 Example of Format for Scour Survey 9




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0153-001

PROCEDURE I 06 001

SEABED PROFILE AND SCOUR SURVEY

1 INTRODUCTION

The work method is to be applied to a general video survey by ROV or Diver of scour, either around asteel or concrete structure and seabed mapping by an ROV or a specialised Imaging Tool. The workwill include a general visual video survey, dimensional measurements and Cathodic Potential (CP)readings where exposed piles are identified.

2 TASKS

2.1 Standard Tasks



2.2 Optional Tasks

DM-STD - Standard Dimensional Survey (Seabed Mapping)





The inspection is to be carried out by ROV, under the guidance of a CSWIP 3.3u or 3.4u InspectionController, or any diver, under the guidance of a CSWIP 3.4u Inspection Controller.

Note: For ONEgas platforms, scour anomaly criteria may vary per jacket based on design criteria.

3.2 Scour Survey – Steel Structures

3.2.1 Survey

The ROV will carry out, and fully video record, a general visual inspection of the seabed around the

base of the structure for concrete platforms and around the piled legs of steel platforms, extents asspecified in the workscope. Continuous video recording in SIT mode for overall coverage and colourfor detailed close up work is to be conducted throughout the survey.

In the event that divers are required to perform the survey, a colour camera is to be used, giving thebest overall views possible.

The purpose of this inspection is to record the following:

(1) Approach views of the seabed to the structure and establishment of distance out to naturalseabed level.

(2) Profile views and measurements of the depth of scour around piled legs - for steel structures.

(3) Measurements of seabed material and or drill cuttings build up.






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• The same may be applied to any other reference point of known depth, when establishing scourto the underside of a vertical diagonal or mudmat.

The standard location for scour/depth readings required for the whole of a structure are as listed,(Reference Figure 1):

(1) Adjacent the leg, or mudmat, at each of the 4 Cardinal clock positions.

(2) 2.5m out from the leg, or mudmat, at each of the 4 Cardinal clock positions.

(3) Midway between each leg on both N-S & E-W framing elevations.

(4) From the leg, and for midpoints between each leg, as shown by Dim ‘x’ in fig.1, identify the pointwhere natural seabed returns. Record distance from platform and seabed depth, at each point.If natural seabed is outside 10m from platform, record seabed depth at 10m out, and report thisfact.

For points (1) to (3), if prevented by clearance under member/mudmat, reading to be taken at nearestpoint outboard. If buried report as per 3.2.4.

Partial coverage of the structure may be specified in the procedure, i.e. Northern, or Western Half,where the above positions still apply for the specified areas. Additional readings may be requested bythe workscope.

3.2.3 Scour Bowls

In addition to the above points, where a scour bowl exists around a leg, the bowl profile is required.Video in SIT and/or colour is required to establish the status around the leg. Actual measurements andestimates as required are to be provided with a sketch (Reference Figure 1).

3.2.4 Buried Members

Where members are buried, an assessment of depth, if possible, shall be given as a positive value. At each point where a reading is taken a comment shall be made with reference to seabedcomposition i.e.:

• Sand

• Silt

• Drilling Mud

• Large Aggregate

• Small Aggregate

• Etc

3.2.5 Jacket Piles

If during the course of the scour survey any jacket pile is observed as being exposed then ifaccessible, CP (Cathodic Potential) readings shall be taken; one reading on the exposed pile and oneon the leg.

This task code (CP-CON) will require to be added to the standard list of tasks, as it is not a standardtask, only carried out when the above condition exists. Should it be necessary to take CP readingscalibration data is to be noted and verified before and after each dive; and for diver readings beforeeach set of readings. Refer to procedure I 60 004 – Cathodic Protection Monitoring.




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3.3 Scour Survey – Concrete Gravity Based Structures (GBS)

3.3.1 Northern - (Brent B, Brent C, Brent D, Dunlin A & Cormorant Alpha)

For concrete platforms, the datum for surveys shall be the design mudline depth, as indicated onbaseline drawings. The method adopted is as for steel structures.

(1) Approach views of the seabed to the structure.

(2) Measurements of the depth of scour, at least every 2m along the survey route.

On a concrete structure base slab, if the steel skirt is visible at any point due to scour it should beinspected for corrosion and if possible a contact CP reading is to be taken. Should it be necessary totake CP readings calibration data is to be noted and verified before and after each dive; and for diverreadings before each set of readings. Refer to procedure I 60 004 – Cathodic Protection Monitoring.

3.3.2 ONEgas - (East – F3-FB-1P)

Platform F3-FB-1P is a Gravity Based Structure (GBS) located in the ONEgas East region. Due to its

presence in a tidal environment, it has specific anti scour protection, which requires unique scour andballast inspections.

The generic scour inspection requirements for this platform will be contained in the specific workscopefor the platform.

4 OPTIONS

4.1 ROV Seabed Mapping (DM-STD)

Seabed mapping is generally required to ascertain the extent of drill mud build up, within and around astructure. It can however be utilised on any area of open seabed, where a contoured profile isrequired.

The ROV will carry out and fully video record, a general visual inspection either:

• Of the seabed within a steel structure, or part thereof.

• On the cell tops of a concrete structure, or part thereof.

• Within any other specified area around a platform.

• On open seabed of a specified area.

The extent of the survey area outside the platform will be 5m, unless otherwise specified in the

workscope. The specific areas of inspection will be as stated in the workscope. Continuous videorecording in SIT mode for overall coverage and colour for detailed close up work is to be conductedthroughout the survey.

There are a number of methods of obtaining the data, both with respect to seabed depth and locationof the readings. Any combination of these (points 1 to 6 below) may be adopted to obtain the finalresults and will be influenced by:

• Availability of a Surveyor.

• Accuracy of survey data and ROV beacon fix, due to platform interference.

• Capabilities of ROV.

• Visibility.




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Discussion on the method for obtaining the required data is to be conducted between all partiesinvolved prior to the survey. These should include the Shell OOE, Shell QAQC/Coordinator, Surveyor,ROV Superintendent, ROV Supervisor and Data Recorder.

Methods that may be adopted to obtain the seabed depth are:

(1) ROV bathometer, with vehicle sitting on seabed at a series of specified positions.

(2) ROV bathometer and altimeter, with ROV passing over a set grid, with a constant string of theresultant data collected with survey positioning data.

Methods that may be adopted to obtain the position of the readings are:

(3) Grid pattern plotted by Surveyor over inspection area, of suitable grid size to be determinedfrom pre-survey discussion, or as specified in the workscope. ROV to position over gridintersections, with fix and depth data to be gathered by Surveyor.

(4) Use of known points within platform, i.e. conductors, nodes, legs, etc.

(5) Use of ROV sonar to position vehicle, relative to known points on platform.

(6) Use of ROV position fix data.

Depth calibration against a component of known depth is to be conducted prior to commencement of asurvey. This should if possible be against a mud brace member of known elevation, level with itsvertical midpoint, which relates to the as-built specified depth of the elevation. Alternatively, the top ofthe member, if the member diameter is known, which is then to be used in any calculations. The timeand data of these calibrations are also to be recorded. These calibrations are to be taken:

• At the start of the survey.

• At the start of any new dive, or vehicle used for the survey.

• Every hour, or otherwise specified by the Surveyor, in tidal locations

Dependant on the type of survey data acquired, a contoured map is to be produced and submittedwith the final report as follows.

• If accurate survey data is obtained, a scaled contoured map is required of the processed data,taking into account any tidal variations.

• Otherwise, a drawing to as accurate a scale as possible.

The Shell Survey provided positioning platform/field layout drawing is to be used as the base drawing

in both cases. The location, time and date of all calibrations are to be included on the drawing.

4.2 Specialist Seabed Mapping

Should a specialist imaging tool be utilised it is to be prepared and deployed in accordance with themanufacturers operating instructions.

Final positioning may require the assistance of the ROV or diver. The imaging tool is fully self-contained, and once set up will be operated by the manufacturers personnel.

The final report of finding will be the subject of a dedicated document and software data packagecompiled and presented by the specialist subcontractor.




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5 REPORTING

5.1 Final Report

The Job Completion Report is to précis the results of the inspection, and any subsequent actions asper the points of interest listed above. Reference section 2, Chapter 1, Section 3.1.5.


Sketches are required, either scanned, AcadLT or other proprietary drawing format, of the results ofthe scour or seabed mapping surveys as stated above. These are to include profile drawings of anyscour bowls, across two planes (12-6 & 3-9 o’clock), (Reference Figure 1).

Buried members shall be indicated as such by cross-hatching on the drawings and an assessment ofdepth, if possible, shall be given as a positive value. At each point where a reading is taken acomment shall be made with reference to seabed composition.

Seabed Mapping profiles are to be produced based on the type of information obtained, as discussedin 4.1 and 4.2.






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PROCEDURE I 06 003

LINEAR PROFILE SCOUR SURVEY

CONTENTS

Para Page

1 INTRODUCTION 3

2 TASKS 3



3.2 Survey 3

4 REPORTING 4

4.1 Final Report 4






0153-001

PROCEDURE I 06 003

LINEAR PROFILE SCOUR SURVEY

1 INTRODUCTION

The work method to be applied will allow for an accurate measurement of the seabed profile across oradjacent to a linear feature such as a pipeline. The work will include detailed dimensionalmeasurements, debris removal and video survey.

It may be required for divers to carry out these inspections due to a number of reasons, i.e. access, ordue to vehicle break down. In these cases, the methodology to be adopted is the same, as best aspracticable.

2 TASKS

VD-ROV - General ROV Video


DM-STD - Standard Dimensional Task

Should anomalies be noted, suitable work tasks and task codes may be added to cover works.




The inspection is to be carried out by ROV, under the guidance of a CSWIP 3.3u or 3.4u InspectionController, or any diver, under the guidance of a CSWIP 3.4u Inspection Controller.

3.2 Survey

Carry out an initial survey by ROV to locate the area to be measured, reporting on any debris or otherobstructions.

On completion of the initial survey remove debris, if any, from the area to be inspected. The debris isto be removed by whatever means is considered suitable and that will allow safe and unrestrictedaccess to the inspection area.

On completion of debris removal establish a horizontal base line, i.e. the top of a pipeline, theunderside of a structural member.

If required, the depth of the baseline is noted and referred back to LAT by noting existing tidalconditions.

The extent of the profile survey is to be noted i.e. between specified pipe joint numbers, where pipespans occur or scour is evident.

Vertical profile measurements are to be taken from the seabed to the horizontal baseline at specificintervals. The specified intervals are to suit local conditions and distance to be inspected, i.e. 1m, 5m,etc.

Carry out a video survey of the area being profiled, which is to clearly show all reference points utilisedin obtaining the profile plot of the baseline, linear feature and seabed.




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4 REPORTING

4.1 Final Report



Drawings are to be supplied of any data gathered.



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PROCEDURE I 10 001

DIMENSIONAL DAMAGE SURVEY TO STEEL STRUCTURES

CONTENTS

Para Page

1 INTRODUCTION 3

2 TASK OPTIONS 3




3.2 Preliminary Works 3

4 OPTIONS 4

4.1 Defect Profiles 4

4.2

Ovality Measurement 5

4.3

Straightness Measurement 5

4.3.1 Straight edge measurement 5

4.3.2 Taut Wire Measurement 5

5 REPORTING 6

5.1 Final Report 6

FIGURES

No Page

1

Example of Format for Defect Profile - Dent (Plan) 7

2

Example of Format for Defect Profile - Dent (Elevation) 8

3 Example of Format for Defect Profile - Dent (Data) 9

4 Example of Format for Ovality Measurement 10

5 Example of Format for Straightness Measurement 11




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0153-001

PROCEDURE I 10 001

DIMENSIONAL DAMAGE SURVEY TO STEEL STRUCTURES

1 INTRODUCTION

The work method is to be applied for the dimensional survey to damage located on steel structures.The work will include debris clearance, profiling, ovality and out of straightness measurements.

NDT methods under Procedure I 15 001, I 15 002, I 15 003 and I 15 004 may also be required to fullyinvestigate and report damage as found.

2 TASK OPTIONS

2.1 Standard Tasks



VD-ROV - ROV Video

PH-DIG - Digital Still Images

Optional Tasks



VD-DIV - Diver Video

CL-INS - Clean for Inspection


VI-DVI - Detailed Visual Inspection

CP-PRX (CON) - Proximity (Contact) CP Readings

Any number or combination of the listed work tasks, or those listed under Procedure I-15 001, I-15002, I 15 003 and I 15 004 may be used or called for on the workscope or during the course of theinspection to fully investigate and report damage as found.




3.2 Preliminary Works

The ROV will carry out, and fully video record, a general visual survey of the area of interest notingarea of damage, item of debris which may have caused the damage or any other cause, marinegrowth coverage and confirm as built configuration for access and rigging for dimensional survey.




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On completion of the general visual survey the diver/ROV is to video all debris in the area as foundprior to removal.

Video and digital still images are to be taken of the damaged area prior to cleaning. The damagedarea is to be suitably identified, with the video and digital still images to clearly show all aspects of thedamage.

NOTE: Any Cathodic Protection (CP) readings requested by the procedure, are to be taken prior toany cleaning.

Deploy cleaning equipment and clean the damaged area to allow inspection. Cleaning of sites forinstalling dimensional survey equipment should also be undertaken at this time.

At this point the damaged area should be marked up as per the requirements of the scope of work andas necessary to carry out the specified dimensional survey/and any NDT works. Prior to carrying outany further work a close visual survey is to be carried out by the diver, recorded on video.

Digital Still Images (PH-DIG) are to be taken of the damaged area on completion of cleaning and diversurvey. The damaged area is to be suitably identified, with the video and digital still images to clearly

show all aspects of the damage.

4 OPTIONS

4.1 Defect Profiles

Defect profiles are to be carried out as specified in the Workscope or as directed by the Shell OffshoreRepresentative, acting on advice from the responsible Structural Engineer. Defect profiles of dents arenormally carried out to measure significant impact damage to members. The profile measurements areto be set out as follows:

(1) Line of maximum bow visually estimated and a taut wire placed parallel to the member axisalong this line, passing over stand off blocks.

(2) A series of wires also on stand off blocks is to be placed 90 degrees to the above on amaximum spacing of 1/6th of the dent width.

(3) A second series of taut wires is to be placed perpendicular to the ones above so as to form agrid over the dent.

NOTE: The perpendicular wires should also be spaced at a maximum of 1/6th of the dentlength.

(4) The grid is to extend across the dent and measurements taken on 'sound' areas.

(5) The grid shall be rectangular and aligned to the member axis.

(6) At sharply indented regions, the spacing of the grid may be reduced for more accurate plotting.

NOTE: A straight edge may be used in place of a taut wire with the agreement of the ShellOffshore Representative.

Measurements are taken from the wire to the member and noted against their grid location. Thelocation of the dent should be referenced to the nearest node or member.

Refer to Figs 1, 2 and 3.




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4.2 Ovality Measurement

Ovality measurements are to be carried out as specified in the workscope, or by the Shell OffshoreRepresentative, acting on advice from the responsible Structural Engineer. Ovality measurements arenormally carried out to determine any distortion, indentation or buckling around a cylindrical element.

The ovality measuring jig (Gauge) is to be constructed so as to provide a solid frame, which can befitted round the element. This frame is to support at least 8 adjustable contact points that can bebrought to bear on the surface of the element in such a way that the tips of the points are not morethan 50mm apart.

When fitting the gauge and adjusting the contact points care is to be taken to ensure that it is at rightangles to the axis of the cylindrical element.

Any local surface irregularities affecting the contact points are to be noted.

The position and orientation of the measuring system relative to the member is to be defined.

The stand off distances from the measuring system to the member at the contact points are to be

tabulated.

Should there be any deviation of straightness of the member, then profile plots are to be drawn. Referto Fig 4.

4.3 Straightness Measurement

Straightness measurements are to be carried out as specified in the workscope, or by the ShellOffshore Representative. Straightness measurements are normally carried out to check the linearity ofa member by measuring from a reference datum line to the structure surface. The measurement maybe carried out by either of the following:

(1) Straight edge (up to 2m).

(2) Taut wire system.

The method used must not involve damage to the structure or its protective coating. An accuracy of0.1% or 1mm, whichever is the least, is required for linear dimensions i.e. 1mm in 1000.

The position and orientation of the measuring system relative to the member is to be defined.

The stand off distances from the measuring system to the member, are to be tabulated and the datumlocations referenced.

Should there be any deviation of straightness of the member, then profile plots are to be drawn.

4.3.1 Straight edge measurement

The areas to which measurements are being noted are cleaned to ensure the straight edge makesgood contact on its support.

Measurements are taken at the 12, 3, 6 and 9 o'clock positions.

The distance from the bottom of the straight edge to the member is to be noted at suitable increments,as agreed with the Shell Offshore Representative, to adequately establish the extent any deflection orcontours.

4.3.2 Taut Wire Measurement

Clamps are installed at each end of the measurement span to hold the taut wire.






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12 O'CLOCK

9 O'CLOCK

DEFECT

SECTION A - A

SHEET 1 OF 3

14112

14113

12142

3 MTRS 250 mm 12 O'CLOCK POSITION

MEMBER 9 O'CLOCK

POSITION

ELEVATION

100 mm

75 mm

MEMBER 9 O'CLOCK

POSITION

14113

A

A

Figure 1 Example of Format for Defect Profile - Dent (Plan)




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A B C D E F G H J K L M

LONGITUDINAL PROFILE

9 O'CLOCK

MEMBER 12124

GRID AT 25mm SPACING

3m TO MEMBER 14112SHEET 2 OF 3

1

2

3

4

5

6

7

8

9

LINE 6

LINE 5

Figure 2 Example of Format for Defect Profile - Dent (Elevation)




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LATERAL PROFILES

LINE A

SHEET 3 OF 3

Figure 3 Example of Format for Defect Profi le - Dent (Data)






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Re-issue 04/05 I 10 001Page 11 of 11

1 4 1 2 3

1 4 1 2 3

1 4 1 2 1

1 2 0 1 6

1 4 1 2 2

M E A S U R E M E N T S A T 0

. 5 M

M A X

. I N T E R V A L S

A A

3 6 9 1 2

9

E L E V A T I O N

C L A M P S

C L A M P

D E V I A T I O N P R O F I L E S

C L O C K P O S I T I O N

P O S I T I O N

T A B L E O F R E A D I N G S

S E C T I O N A -

A

1 2

6

3

C L O C K P O S I T I O N S

O F M E A S U R E M E N T S

Figure 5 Example of Format for Straightness Measurement



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PROCEDURE I 15 001

WELD INSPECTION

CONTENTS

Para Page

1 INTRODUCTION 3

2 TASK OPTIONS 3





3.2 General Visual Inspection (VI-GVI / VD-ROV) 4

3.3 Cathod ic Potential Survey (CP-CON) 4

3.4 Electromagnetic Inspection - ACFM (Alternating Current Field Measurement) 4

3.4.1

Clean for Inspection (CL-INS) 4

3.4.2 Close Up Detailed Visual Inspection (CU-DVI) 5

3.4.3 Scope 5

3.4.4 ACFM Survey and Operat ion (IN-ECI) 6

3.4.5 Reporting of ACFM Results 7

4 OPTIONS 7

4.1 Clean for MPI Inspection (CL-GRT) 7

4.2 Close Visual Inspection (CU-CVI / VD-DIV /VD-ROV) 8

4.3 Magnetic Particle Inspection (CU-MPI) 8

4.4 Indication Grinding – (CN-GRD) Optional 10

4.5 Digi tal Stil l Images (PH-DIG) 11

5 REPORTING 11

5.1

Final Reporting 11

FIGURES

No Page

1 Datum Marking Requirements 12

2 Weld Detailed Inspection Summary Data Sheet 13

3 Electro Magnetic Inspection Data Sheet 14

4 Weld Inspection Magnetic Particle Data Sheet 15




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0153-001

PROCEDURE I 15 001

WELD INSPECTION

1 INTRODUCTION

The work method is to be applied to the inspection of welded steel joints to locate and size for lengthand depth, surface breaking defects. This method may be applied to the inspection of damage to steelmembers, attachments, pipelines and risers.

The work carried out will include, General Visual Inspection, Cathodic Potential Survey, Cleaning,Close and Detailed Visual Inspection (CVI & DVI), Electromagnetic Inspection (ACFM) andVideo/Digital Photography. If explicitly stated in the Workscope, it may also include Magnetic ParticleInspection, Ultrasonic Inspection, Remedial Grinding and Profile Measurements.

Inspection methods under the following procedure are to be employed in conjunction with thisProcedure.

I 15 002 – Wall Thickness and Ultrasonic Inspection – General

2 TASK OPTIONS

2.1 Standard Tasks



VD-ROV - ROV Video

CP-CON - Contact Cathodic Potential Survey

CL-INS - Clean For Inspection

CU-DVI - Close Up Detailed Visual Inspection (Weld Specific for ACFM)

IN-ECI - Eddy Current Inspection (Alternating Current Field Measurement – ACFM)


2.2 Optional Tasks

The following work tasks are optional and will be explicitly called for in the Workscope or will berequired on identification of a C1 anomaly.

CL-GRT - Clean For MPI Inspection (Air Grit Entrainment)

CU-CVI - Close Up Close Visual Inspection (Weld Specific for MPI)

VD-DIV (ROV) - Diver (ROV) Video

CU-MPI - Magnetic Particle Inspection

CN-GRD - Remedial Grinding

PH-DIG - Digital Images




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Following a 'C1' anomaly report further investigative inspection may be required. These works will bespecified in the Workscope, or by the Shell Offshore Representative, acting on advice from theresponsible Structural Engineer.



Inspection to be carried out by CSWIP 3.1u, or 3.2u diver, CSWIP EMD Operator (ACFM Level 1/2)and CSWIP 3.4u Inspection Controller.

An ACFM Level 2 operator will be required onboard during weld inspection operations to assist thelevel 1 as required. An ACFM Level 2 operator will be required to carry out any system re-configurations.

3.2 General Visual Inspection (VI-GVI / VD-ROV)

A general visual inspection will be carried out on the weld and surrounding area, to establish theintegrity of the structure, determine the extent of cleaning required and to check that the area is safefor diver access. Marine growth will not be removed prior to this inspection. Note all debris of ahazardous nature for removal prior to the inspection. The inspection will report any obvious anomalies,e.g. missing or distorted members.

3.3 Cathodic Potent ial Survey (CP-CON)

Contact Cathodic Potential Measurements are to be taken by diver prior to any cleaning being carriedout at the selected inspection site.

CP readings are to be taken at the four cardinal clock positions at the following locations:

(1) At the weld.

(2) 1m along the brace member from the weld.

(3) 2m along the brace member from the weld.

Calibration data is to be noted and verified before and after each dive and before each set of readingsif the contact probe method is used. Proximity readings are the preferred option, but Contact probesmay be used with prior approval of the Shell Offshore Representative, acting on advice from theSponsoring Engineer. Reference procedure I 60 004 – Cathodic Protection Monitoring.

3.4 Electromagnetic Inspection - ACFM (Alternating Current Field Measurement)

3.4.1 Clean for Inspection (CL-INS)

Excessive marine growth, corrosion and other deposits, which would inhibit the smooth probe travelalong the weld toe should be removed. Loose paint coat, or paint coat in excess of 5mm, shall beremoved from the weld cap and from the area within 50mm of each weld toe along the wholecircumference.

Cleaning shall be carried out using hand held wire brush or scrapers, or if required, low pressure airgrit entrained, or high pressure water jetting.

Other cleaning techniques must not be used as they can have an adverse effect on the detect ability of

surface breaking defects.




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3.4.2 Close Up Detailed Visual Inspection (CU-DVI)

Prior to commencing the detailed visual inspection a datum mark consisting of three vertical punchmarks are to be applied to the chord member at the 12 o’clock position, starting 25mm from the weldtoe. Should access be restricted, or for any other reason the 12 o’clock position cannot be used, amore suitable position may be substituted. See Fig.1. Note this may have been carried out from aprevious inspection, as such the weld and/or historical data should be checked for the existence ofsuch datum marks.

Any confirmed existing datum marks should be used, to ensure consistency of results.

From the datum mark the weld circumference is to be measured in a clockwise direction in 100mmincrements. Each increment is to be marked with a suitably coloured oil based paint stick, or similarand numbered sequentially. Datum will always be zero.

The datum mark position and total weld length are to be recorded on the Weld Inspection Data Sheet(Fig.2), the EMI Data Sheet (Fig.3), within the ACFM system software inspection log and within theCOABIS Workpack Diary.

The remote probe operator shall carry out a detailed visual inspection of the weld and parent material.Locate and record the position of any visible anomalies, corrosion pitting, temporary fabrication aids,geometry discontinuities, structural damage, etc.

3.4.3 Scope

All Electromagnetic Inspection will be conducted using the following general rules. More specificinformation regarding the Shell EPE requirements for the use of ACFM are specified in points 3.4.4and 3.4.5.

(1) This procedure is intended for the eddy current examination of nodal weldments using ACFMequipment, models U21 or U31D.

(2) This procedure is restricted to locate and depth size surface breaking cracks in weld toe regionsonly.

(3) This procedure is restricted to the use of the Standard Weld, Tight Access, Grind Repair(Pencil) and Mini probes. It is envisaged that the Standard Weld probes will be used in the main,with the other probe types used as appropriate.

(4) The inspection principle is based on manual scanning of nodal weldments, respectively alongthe Chord and Brace weld-toes for either longitudinal or transverse surface breaking cracks.The possibility of interbead cracks is to be ignored.

(5) This procedure is restricted to locating and sizing surface breaking longitudinal cracks with

length exceeding 20mm and depth exceeding 2mm, and all transverse cracks with a depthexceeding 2mm.

(6) This procedure can be applied to coated nodal weldments, but the applicability of this procedureis restricted to well adhered coating with a maximum coating thickness of <5mm.

Welded joints referred to in this procedure comprise all configurations fabricated in ferromagneticmaterial regardless of welding procedure or technique used.

The inspection shall be carried out in the remote operator mode, utilising a remote probe operator(Diver - CSWIP 3.1u minimum) and a CSWIP EMI (ACFM Level 1) topside operator for recording andanalysing of the scan data.

NOTE: An ACFM Level 2 operator will be required to carry out the inspection where a probe typenot listed in point (3) above is to be used, or where weld joint material is non-ferromagnetic.




0153-001

It is not envisaged that this should arise for standard weld inspections. Should a non-standard typeweld be required to be inspected, this should be identified in the workscope, highlighting therequirement for a Level 2 operator.

3.4.4 ACFM Survey and Operation (IN-ECI)

The ACFM equipment should be assembled with the correct probe, as identified from the GVI or DVI.This is typically the Standard Weld probe for weld toe inspection. The ACFM system does not requirea calibration check. A system check should be carried out on the ACFM function test block prior todeploying the ACFM equipment to the worksite.

3.4.4.1 Diver Briefing

The remote probe operator (diver) should be thoroughly briefed prior to carrying out the inspection.The briefing should include the following:

(1) Level of cleaning required.

(2) Marking up of the component weld prior to commencing inspection.

(3) Reporting of visual defects and relevant features.

(4) Dialog to be used during the inspection.

(5) Probe selection / operation and scanning techniques.

(6) Defect locating and visual marking of defect extents.

3.4.4.2 Topside Operation

Prior to commencement of any inspection operation, the storage facility within the ACFM systemsoftware should be prepared for accurate data handling, ease of use during subsequent analysis andtraceability.

The emphasis is to identify a distinct inspection region. The first operation would be the choice of asuitable filename for the inspection. Due to the requirement to store the ACFM data file within theCOABIS database, the filename must be unique, unrepeatable over subsequent years. To this end thefollowing base file naming system is to be adopted, as the ACFM filing system is restricted to 8characters. To enter the required information, proceed as follows:

Enter 'FILENAME' i.e. BA040107

Where BA = Facility Code - Brent Alpha

04 = Year (2004)

01 = Unique Workpack Reference, relating to the last two digits of a workpacknumber (BA/2004/B101)

07 = CTS Number, in this case CTS 7

NOTE: For Shearwater Alpha (SWA), or Charlie (SWC), either the year or CTS (preferably CTS ifsingle figured) should be shortened, to allow the full facility code to be entered.

In cases where the above numbering system is still not appropriate, use a suitablefilename, checking within historical data that such a file name has not been previouslyused.

All ACFM files are to be saved within the COABIS database.




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The following information should be logged on the title page within the ACFM software against theinitial function test scan:

(1) Computer: (6) Weld length.

(2) Software Version: (7) Direction of probe travel.

(3) Probe type and serial no. (8) Probe operator.(4) Function check block serial no. (9) Topside operator.

(5) Component under inspection

3.4.5 Reporting of ACFM Results

All surface breaking defects located should be sized for length and depth. Defect dimensions shouldbe recorded on the relevant title pages within the ACFM software and on the EMI Data Sheet (Fig.3).

On completion of the inspection, the information (data files) should be backed up on the ACFMcomputer hard drive and to floppy disk. Where multiple welds are inspected, all relevant files can besaved to the same floppy disk(s) pertinent to the individual Workscope. This disk(s) should be

submitted with the final Workscope report. The data files should be saved and linked within theCOABIS database, and referenced within the COABIS Workpack Diary report.

A screen dump showing the length and depth of all surface-breaking defects should be included in thefinal report, together with the relevant EMI Data Sheet (Fig.3).

The completed EMI Data Sheet (Fig.3), should include the following:

(1) Clear indication of Datum location.

(2) Distance of defect from indicated datum.

(3) Defect length and depth.

(4) Defect type.

(5) A clear sketch showing component and indications.

(6) Topside operators name.

(7) Date of Inspection.

Al l f indings should be reported to the Shel l QAQC/Coordinator.

4 OPTIONS

When specified in the Workscope or as directed by the Shell Offshore Representative or by sponsor,any of the following optional activities may be undertaken.

4.1 Clean for MPI Inspection (CL-GRT)

All marine growth, protective coating, corrosion and other deposits, shall be removed from the welditself and from areas extending 50mm from each weld edge, around the whole weld circumference, oras specified in the Workscope.

Cleaning System utilised will be such that the area cleaned shall conform to Swedish Standard SIS 0559 00 1969, Grade SA 2.5. The primary cleaning system will be a low-pressure air system with gritentrainment.








0153-001

BS 667: 2005

(Replaces BS 667: 1996)

: Illuminance meters. Requirements andtest methods

4.4 Indication Grinding – (CN-GRD) Optional

No grinding is to take place without the approval of the Shell Offshore Representative.

Where cracks have been identified, grinding up to a depth limit of 2mm or 5% of nominal WT (whichever is the lesser value) to remove surface defects is permitted without approval from the ResponsibleTechnical Authority (TA), as stated in the Weld Defect Anomaly Criteria actions (reference Section 2,Chapter 6, Point 2.2.19). Confirmation of the nodal nominal WT required prior to proceeding withgrinding required.

If the indication still remains, no further grinding shall take place unless authorised by the ShellOffshore Representative acting on advice from the responsible TA.

Note that the maximum length of grinding (in excess of 2mm depth) is to be limited to 25% ofthe brace circumference.

If the defect is greater than 75mm in length, only part of it should be ground at any one time.

Removal of surface cracks by deep grinding, i.e. greater than 2mm depth or 5% of the plate thickness,shall be conducted in accordance with a procedure approved by the Responsible Shell StructuralEngineer.

If indications are noted check whether the area has been previously ground and report all findings toShell Offshore Representative.

All grinding shall be carried out using spherical and hemispherical tipped tungsten carbide burrs,mounted in either hydraulic or air operated pencil grinders. 12mm diameter burrs are preferred. Use ofany smaller diameter burrs are only allowed after consultation and approval by the Shell OffshoreRepresentative.

NDT personnel are to familiarise themselves with the grinder on deck, or on a test piece at depth, inorder to ascertain how many passes are required to remove 0.5mm of metal.

Grinding will be carried out as specified in the Workscope or by the Shell Offshore Representative.(Grinding is normally carried out following the detection of indications found during MPI. It should alsobe carried out as a remedial measure for removing undercut and smooth contouring the surroundingsteel).

Where grinding, or further grinding, is to take place on a previously reported defect the NDT personnelare to refer to the previous MPI and Close Visual Inspection reports to verify the nature and extent of

the indication. Indication grinding is only to be carried out whilst the grinding area is set up for MPI.

The indication is to be ground in depth increments of 0.5mm, which are to be measured using a LAMgauge. Grinding depth is to be measured at maximum increments of 25mm along the indication tapedatum.

Before grinding, and subsequently after each grinding step, MPI is to be reapplied and the followinginformation noted:

(1) Location of crack.

(2) Length.

(3) Width.

(4) Orientation.

I 15 001 Re-issue 04/05Page 10 of 15



0153-001

(5) Crack increase or decrease in length.

(6) Crack increase or decrease in width.

(7) Direction in which crack is progressing, whether defect is in weld metal, parent metal or heataffected zone.

On completion of grinding, the ground area should be smoothly contoured. The ground area shall becontoured so that its profile conforms to a circumference of a 12mm minimum diameter circle. Thesurrounding areas should then be ground so that no sharp edges remain which could act as stressraisers. The final grinding pass should be made at right angles to the weld's longitudinal axis.

NOTES: (1) To ensure effective removal of crack-like defects by grinding, the ground depth shouldcontinue 0.5mm deeper than the indication to remove yielded material or any burrconcealing the indication. On completion of all grinding confirm as left conditionground depth with the use of the LAM gauge at maximum increments of 25mm alongthe ground path tape datum.

(2) ECI (ACFM) inspection may also be called for to indicate crack depth and to confirm

crack has been removed by grinding.

All works carried out and as left weld condition is to be recorded on the Weld inspection MagneticParticle Data Sheet. (Ref Fig 4).

4.5 Digi tal Stil l Images (PH-DIG)

If possible, digital images should be taken of any visual surface breaking cracks, or other C1 anomaly,should the video quality allow.

Digital images should be taken of any subsequent grinding, with suitable indicators confirming the startand end of the grinding, with at least two 100mm increment markers included in the image.

5 REPORTING

5.1 Final Reporting

The Job Completion Report is to précis the results of the inspection, and any subsequent actions asper the points of interest listed above, referencing any ACFM files and accompanying data sheets.Reference section 2, Chapter 1, Section 3.1.5.

All Weld Inspection Data Sheets (Fig.2), EMI Data Sheets (Fig.3) and MPI Data Sheets (Fig.4) are tobe included with the final report, along with ACFM screen dumps of any defects identified.

Any ACFM files are to be saved and linked within the COABIS database, including screen dumps of

any defect. These multiple files should be zipped into a single file for each weld. Multiple zipped files,for several welds, will be required to be submitted on CD or floppy disk(s) with the final report.

Re-issue 04/05 I 15 001Page 11 of 15





0153

L o c a t i o n s

F e a t u r e

G u i d a n c e

1

C h o r d H A Z

2

C h o r d T o e

3

W e l d C A P

4

B r a c e T o e

5

B r a c e H A Z

O K

N o D e f e c t s

U C 1

U n d e r c u t > 2 m m D X 1 0 m

m L

U C 2

U n d e r c u t < 2 m m D e e p

C R

C r a c k / L i n e a r I n d i c a t i o n

O T H

O t h e r D e f e c t s , C R , P D .

N o

*

Y e s

+

N o

X

Y e s

"

N o

C U - C V I W e l d L e n g t h

M e t r e s

0 . 0 0 0

A l l T a s k

s

V I - G V I

I N - E C I

C P - C O N

C L - G R T

C U - C V I

C U - M P

I

P H - 3 5 M

C N - R I G

A l l T a s k

s

V I - G V I

I N - E C I

C P - C O N

C L - G R T

C U - C V I

C U - M P

I

P H - 3 5 M

C N - R I G

A n o m a l i e s

W D

M a s t e r

D a t e s

S t a r t

E n d

S t r u c t u r e

S u b s t r u c t u r e

C o m p o n e n t

E l e v a t i o n

T o

D r a w i n g

L e n g t h

S p r e a d

W o r k p a c k

N o d a l W e l d I n s p e c t i o n -

D a t a R e c o r d e r ( s )

D e v e l o p m

e n t - A n o m a l o u s F i n d i n g s

L o c n

1 2 3 4 5 T a p e

0 . 0

D e v e l o p m

e n t - R o u t i n e F i n d i n g s

L o c n

1 2 3 4 5 T a p e

0 . 0

F e a t u r e

N o .

C o d e

L o c n .

C o d e

T a p e ( m m )

S t a r t

L e n g t h

I n t e r n /

C o n t i n /

% C o v e r

D e p t h ( m m )

M a x .

A v .

A n o m .

( Y / N )

C o m m e n t

C l o s e V i s u a l I n s p e c t i o n

C U - C V I

S h e l l E x p r o - U E I S 1 . 1

-001

Re-issue 04/05 I 15 001Page 13 of 15

Figure 2 Weld Detailed Inspection Summary Data Sheet



0153-001

Figure 3 Electro Magnetic Inspection Data Sheet

I 15 001 Re-issue 04/05Page 14 of 15



0153-001

Re-issue 04/05 I 15 001Page 15 of 15

L o c a t i o n s

F e a t u r e

G u i d a n c e

1

C h o r d H A Z

2

C h o r d T o e

3

W e l d C A P

4

B r a c e T o e

5

B r a c e H A Z

O K

N o D e f e c t s

U C 1

U n d e r c u t > 2 m m D X 1 0 m m L

U C 2

U n d e r c u t < 2 m m D e e p

C R

C r a c k / L i n e a r I n d i c a t i o n

O T H

O t h e r D e f e c t s , C R , P D .

N o

*

Y e s

+

N o

X

Y e s

"

N o

C U - M P I

A l l T a s k s

V I - G V I

I N - E C I

C P - C O N

C L - G R T

C U - C V I

C U - M P I

P H - 3 5 M

C N - R I G

A n o m a l i e s

W D

M a s t e r

D a t e s

S t a r t

E n d

S t r u c t u r e

S u b s t r u c t u r e

C o m p o n e n t

E l e v a t i o n

T o

D r a w i n g

L e n g t h

S p r e a d

W o r k p a c k

N o d a l W e l d I n s p e c t i o n -

D a t a R e c o r d e r ( s )

D e v e l o p m e n t - A n o m a l o u s F i n d i n g s

L o c n

1 2 3 4 5 T a p e

0 . 0

D e v e l o p m e n t - R o u t i n e F i n d i n g s

L o c n

1 2 3 4 5 T a p e

0 . 0

F e a t u r e

N o .

C o d e

L o c n .

C o d e

T a p e ( m m )

S t a r t

L e n g t h

I n t e r n /

C o n t i n /

% C o v e r

D e p t h ( m m )

M a x .

A v .

A n o m .

( Y / N )

C o m m e n t

M a g n e t i c P a r t i c l e I n s p e c t i o n

C U - M P I

S h e l l E x p r o - U

E I S 1 . 1

D e s c r i p t i o n

S y

m b o l A n o m

M e t h o d

I n k T y p e

C o n t r o l D e t a i l s

L u x L e v e l

D e m a g g e d

F i e l d C h e c k

Figure 4 Weld Inspection Magnetic Particle Data Sheet



0153-001

PROCEDURE I 15 002

WALL THICKNESS AND ULTRASONIC INSPECTION - GENERAL

CONTENTS

Para Page

1 INTRODUCTION 3

2 TASKS 3




3.2 General Visual Inspection (VI-GVI / VD-ROV) 3

3.3 Ultrasonic Digital Wall Thickness Measurements (WT-DIG) 4

3.3.1 General - Diver 4

3.3.2 ROV 4

3.4

Pulsed Eddy Current (PEC) Wall Thickness Measurements (WT-PEC) 5

3.4.1 WROV Dual PEC Probe Handling Frame 5

3.4.2 ROV PEC Frame Obtained Caisson Readings (ONEgas / Northern) 6

3.4.3 Single PEC Probe ROV Manipulator Held 6

3.4.4 Calibration Readings 7

3.4.5 Datum Reference 7

3.4.6 Anomalous Readings 7

3.4.7 Post Inspection Video (CL-INS / VI-DVI / VD-ROV) 7

3.5 Ultrasonic `A' Scan (IN-UTA) 7

3.5.1 General 7

3.5.2 Surface Preparation (CL-GRT) 8

3.5.3 Close Visual Inspection (VI-CVI) 8

3.5.4 Inspection Method 8

3.6

Video (VD-ROV / VD-DIV) 9

4 REPORTING 9

4.1 Final Report 9

FIGURES

No Page

1 Ultrasonic Inspection Report Data Sheet 10

2 Dual PEC Probe Handling Frame Schematic 11

3 Typical PEC Results Data Sheet Format 12






0153-001

PROCEDURE I 15 002

WALL THICKNESS AND ULTRASONIC INSPECTION - GENERAL

1 INTRODUCTION

The work method is to be applied to the Wall Thickness and Ultrasonic (UT) inspection of ferricmaterial for the location of discontinuities within that material. The requirement for UT inspection willbe specified in the Workscope. This procedure may be used in conjunction with Procedure I 15 001 toinvestigate anomalies.

2 TASKS

2.1 Optional Tasks



VD-ROV - ROV Video

CL-INS - Clean For Inspection

WT-DIG - Ultrasonic Wall Thickness – Digital


CL-GRT - Clean For Inspection (Air Grit Entrainment)

WT-PEC - Pulsed Eddy Current (PEC) Wall Thickness Measurement

IN-UTA - Ultrasonic 'A' Scan


Following a 'C1' anomaly report further investigative inspection may be required. These works will bespecified in the Workscope or by the Shell Offshore Representative acting on advice from theresponsible Structural Engineer.



Ultrasonic digital wall thickness inspection work is to be carried out by CSWIP 3.1u / 3.2u diver, underthe guidance of a CSWIP 3.4u Inspection Controller.

PEC wall thickness survey is to be carried out by a CSWIP 3.4u Inspection Controller, suitablyinstructed in the use of the PEC software and processes.

Ultrasonic ‘A’ scan inspection work is to be carried out by suitably qualified PCN, level 2 UT Operator.


A general visual inspection will be made of the inspection site and surrounding area, by ROV recordedon video, to establish the general integrity of the structure required and to check that the area is safe

for diver access. Marine growth will not be removed prior to this inspection. Note all debris of ahazardous nature for removal prior to inspection.






0153-001

3.4 Pulsed Eddy Current (PEC) Wall Thickness Measurements (WT-PEC)

Initially a topside system designed in house by Shell Global Solutions for taking wall thickness (WT)readings on coated steel components. The system uses eddy currents to determine WT, notultrasonics. A subsea system was developed specifically for use by ROV on Firewater and Seawaterlift caissons. This was to identify the existence of wall thinning due to the presence of an internal

pump. It can however be used on any steel component. The method of use of the PEC wall thicknesssystem is detailed in the current Shell Global Solutions operation manual (OG.02.20617).

This system may be used by ROV, diver and topside. However, at present for this manual it is onlyintended for ROV use. The benefits of the PEC method are that WT readings can be obtained thoughcoatings of most thicknesses and types, and without the need for marine growth cleaning, apart fromwhere excessive marine growth would prevent fitment of the PEC Probe Handling frames, discussedbelow.

There are three methods of use, which are further discussed below:

(1) WROV Dual PEC Probe Handling Frame. Two PEC probes mounted in a specifically designedframe for use by a dedicated WROV. Allows accurate positioning of the PEC probes once the

frame is established around the full circumference of a vertical or caisson. Designed for usewithin larger structures with suitable access to components, i.e. Shell Northern Structures. Thissystem can inspect vertical components with diameters of between 42”-22”.

(2) ROV Mini PEC Probe Handling Frame. A dual PEC probe mounted in a specifically designedframe for use by a dedicated mid sized ROV. Allows accurate positioning of the PEC probeonce the frame is established around a vertical or caisson, at two clock positions. The vehiclerequires to be repositioned for further readings at different clock positions. Designed for usewithin smaller structures with less restricted access, i.e. Shell ONEgas Structures. This systemcan inspect vertical components with diameters of between 22”-16”.

(3) Single PEC Probe ROV Manipulator Held. Use of a single probe, mounted in a bracket, heldby an ROV manipulator. Designed for use where access prevents use of either of the above.

Refer to 4.3.2.4.

The location and extent of readings will be specified in the workscope. Where these readings are notpossible due to access or other factors, alternative readings may be selected after consultation withthe Shell Offshore Representative, on advice from the responsible Structural Engineer.

Two types of probes are utilised, ‘wide’ and ‘narrow’ beam. The wide beam probes allow readings overa larger footprint, where the results give an average WT over the footprint. The narrow beam gives anaverage WT over a smaller footprint. As a result the narrow beam probe tends to be used on smallerdiameter tubulars, or where known perforations exist which may give a false indication of WT.

NOTE: All PEC readings taken are subject to post processing on completion of the survey. As aresult, evidence of thinning may not be fully apparent until post processing has beencompleted. Past history has shown that in the main, variations from the initial results are notlarge. However, post processing may result in readings initially not anomalous, becominganomalous, and vice versa.

NOTE: It has been proven that PEC cannot be used on flexible pipelines due to their method ofmanufacture, as is the case for UT methods also.

3.4.1 WROV Dual PEC Probe Handling Frame

This PEC Probe handling method allows accurate positioning of two PEC Probes for WT inspection ofcaissons or other near vertical tubular components, over large areas.

The WROV frame, designed by Sub-Atlantic, holds two standard PEC Probes diametrically oppositeeach other, when mounted around a tubular. The frame is permanently attached to a specificallyallocated WROV, and can currently be attached to any near vertical tubular.




0153-001

Once attached the frame allows 700mm vertical and 360 degree travel of the probes, monitored by anarray of cameras. The schematic Figure 2 shows the PEC frame mounted on an ROV, in position on avertical tubular/caisson.

The handling frame has the following specification, restricting its use on inclined tubulars:

PEC Tool System weight (in air): 540Kg

PEC Tool System weight (in sea water): Neutral

Pitch angle: 150 total, (7.5

0 either side of mid position)

Yaw angle: 300 total, (15

0 either side of mid position)

The extent of readings to be taken will be specified in the workscope. It is recommended that overlarge areas readings should be taken at 100mm or 250mm increments vertically, but readings can betaken in any increment of 50mm. Around the circumference of a tubular, readings can be taken ateach of the 12 clock positions. For large inspection areas, it is recommended to take readings local tothe area of interest at the 12 clock positions, and then at the 4 cardinal clock positions. It is

recommended that at least 2 full passes over the 12 clock positions are taken at some point.

Prior to commencement of readings in the inspection area, a calibration reading is required in an areapresumed to be free from any possible thinning, on a component of the same diameter and wallthickness. This is backed up by the taking of an ultrasonic Cygnus WT reading at the same location.

The PEC frame is typically mounted with wide beam PEC probes. If required these may be replacedby narrow beam probes.

Where the PEC frame cannot be employed, due to either diameter size or restricted access, theROV PEC frame (see 3.4.2) or the manipulator held PEC probe may be used (see 3.4.3).

3.4.2 ROV PEC Frame Obtained Caisson Readings (ONEgas / Northern)

This PEC Probe handling method allows accurate positioning of two PEC Probes for WT inspection ofcaissons or other near vertical tubular components. The allowable vertical travel of the inspectionprobes is 300mm when the frame is in position. Subsequent readings require repositioning of theframe by the ROV. As a consequence, accurate reporting, depth monitoring and cross reference toprevious readings is required.

The PEC frame is typically mounted with wide beam PEC probes. If required these may be replacedby narrow beam probes.

3.4.3 Single PEC Probe ROV Manipulator Held

The Single PEC probe method can be used in any location, tubular or flat, at any inclination, asaccess allows.

Two probe types exist, providing a broad and narrow inspection beam area. The narrow beam probeshould be used on tubulars of small diameter.

A mounting frame has been used in the past in the form of a ‘V’, which helps to centralise and stabilisethe PEC probe on the inspection area. This mounting frame must not be made from magnetic ferrousmetal, or aluminium. An acceptable material is Non-magnetic Stainless Steel, or plastic.

As for the taking of manipulator held Cygnus WT readings, this method is not as accurate in itspositioning of the PEC probe, due to vehicle movement, and general problems regarding the correctposition of the probe. However, best endeavours should be made to accurately record the locations of

readings taken.




0153-001

3.4.4 Calibration Readings

Prior to commencement of readings in the inspection area, a calibration reading is required in an areapresumed to be free from any possible thinning. The nominal WT of the component under inspectionshould be known. The workscope should detail any possible change in WT within the inspection area.

As a comparison with the calibration reading, ultrasonic Cygnus WT readings may additionally berequired. This is catered for on the WROV PEC frame, where a Cygnus probe is mounted to the top ofthe frame, as well as a rotary wire brush for cleaning. This measurement is to be used as acomparison with the given nominal WT, which is a required input for the PEC software.

3.4.5 Datum Reference

Readings taken should be referenced to a known datum. The most obvious reference feature is ahorizontal elevation. The ‘as-built’ depths of all horizontal elevations given are based on the verticalmid point of the elevation member.

To establish the position of the pump, the difference between the given pump depth and elevationdepth, should be added or subtracted from the ROV (or diver) depth for the vertical mid-point of the

elevation member.

Where tidal variations exist, or where different vehicles, or new dives are used to continue aninspection on a specific caisson, repeat checks on the offset should be taken.

3.4.6 Anomalous Readings

When using the PEC frame, where anomalous WT loss is established, to C1 level for risers ≥20%, C2

level for caissons ≥50%, and ≥20% for other steel components, PEC readings should be increasedback to the workscope stated minimum vertical increment (100mm or 50mm), and at all adjacent clockpositions, until WT levels are less than the above anomaly criteria, or as instructed by the ShellOffshore Representative, acting on advice from the Responsible Structural Engineer.

Where manipulator held PEC survey is employed, the above criteria still applies, however it isaccepted that this may not be possible. Attempts should be made to obtain the best possible resultsas time and operational constraints allow.

3.4.7 Post Inspection Video (CL-INS / VI-DVI / VD-ROV)

The benefit of this survey is that no initial cleaning is required. Therefore any meaningful video surveypost inspection would require cleaning. Video inspection should therefore be based on the results ofthe survey and should not be carried out unless WT loss to the anomaly levels above has beenidentified.

Unless specified in the workscope, cleaning and DVI should be restricted to the identified areas of WT

loss, or as directed by the Shell Offshore Representative, acting on advice from the ResponsibleStructural Engineer.

3.5 Ultrasonic ‘A’ Scan (IN-UTA)

3.5.1 General

Ultrasonic Inspection Systems to be utilised will be either the Wells Krautkramer USK-7 or theSubspek SM 3, complete with surface read out (SRO) Units. Deployment and operation of the unit willbe as per respective Manufacturers Operation manuals.

The Inspectors Divers hat mounted TV camera is to be utilised during the Ultrasonic Inspection toallow the topside inspection controller to monitor the exact probe position with relationship to the

inspection site.






0153-001

Any defects located are to be noted and further examination carried out to determine their size, extentand where possible, the type. The 6 dB and 20 dB drop methods are to be used as applicable.

3.6 Video (VD-ROV / VD-DIV)

Video confirming the area inspected and any markings used will be required.

A video survey is required to provide a supplement to the 'C1' Anomaly Report and is to provide avisual and narrative impression of the anomaly under inspection.

The video survey will take place on completion of all inspection and remedial work and will start with astand off view of the whole work site, which will clearly show the anomaly site in relation to structuralmembers. The video survey will incorporate all identification, scale, position and anomaly indicationarrows as used during the UT Inspection to allow cross-reference to hard copy report data.

The survey is to start at the Datum Mark in all instances and continue in a logical sequence with thecamera maintained in a vertical position until the survey ends, once more at the Datum Mark. Care isto be taken to prevent gas bubbles obstructing the weld at any time during the survey.

The stand off distance is to be such that the weld occupies the central 1/3 of the picture or that thecamera is at its close focus point with the weld held in focus, and that the survey is carried out at aspeed that is slow enough so that all anomalies are clearly observed and recorded (visual andnarrative).

Consideration is to be given, with the approval of the Shell Offshore Representative, to the choice ofequipment depending on the circumstances where high resolution black and white video may providebetter results than colour. The orientation and position of the subject video is to be identified on theVideo Log.

An as left survey is required to confirm that the worksite has been left clear of all rigging & inspectionequipment.

4 REPORTING

4.1 Final Report

The Job Completion Report is to précis the results of the inspection, and any subsequent actions asper the points of interest listed above, referencing any accompanying data sheets. Reference section2, Chapter 1, Section 3.1.5.

Where a large number of readings are taken, that cannot be suitably incorporated into the WorkpackDiary, a drawing showing the results and the location of the readings is to be submitted.

A hard copy of all PEC data results, and any associated Cygnus WT readings, are to be included in

the Results/Appendix section of the final report, in a similar format to that shown in fig.3 below. Thisformat is converted from the processed PEC data files, which is in an excel format. All PEC data filesare to be saved within the COABIS database and suitably linked.




0153-001

Figure 1 Ultrasonic Inspection Report Data Sheet

I 15 002 Re-issue 04/05Page 10 of 12



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PEC Probe Handling Frame

Vertical Tubular

Workclass ROV

Figure 2 Dual PEC Probe Handling Frame Schematic

Re-issue 04/05 I 15 002Page 11 of 12



0153-001

I 15 002 Re-issue 04/05Page 12 of 12

PEC Offline Wal l Thi ckness plot A + B (15% Smoothed + FFT filte red)

Location Nelson Date Saturday,12 Jun 2004

Job nr. NELSN/2004/C101 Filename RD16404C

Component nr. 43-007 Description Seaw ater caisson

Datum poin t -10m Recorded by John Dow nes / John Knight

Diameter 39 [inch] WT_nom 15 [mm]Grid vert. spacing longitudinal Vert.incr. 100 [mm]

Grid. hor . clockposi circumferential Hor. incr. 1 [hr]

Vertical

PositionHorizontal Position

1 2 3 4 5 6 7 8 9 10 11 12

+1500 14.6 14.4 14.9 14.7 14.6 15.2 15.3 15.3 14.5 13.9 13.6 19.7

+1400 13.3 13.5 14.0 13.9 14.2 14.8 14.4 14.7 14.0 11.7 12.3 19.7

+1300 11.1 13.0 13.1 13.9 13.9 13.8 13.8 13.6 13.3 11.6 11.2 18.7

+1200 11.0 12.1 11.6 12.3 13.4 13.2 13.7 12.4 11.9 10.8 10.3 18.1

+1100 9.9 11.6 10.9 11.5 12.9 13.3 13.6 12.5 12.0 11.8 9.9 17.3

+1000 9.4 12.6 11.8 13.7 14.0 13.6 13.8 12.2 12.5 11.7 10.7 17.6

+900 11.9 13.0 12.2 13.3 14.0 14.1 14.0 12.3 12.5 12.5 10.9 16.8

+800 11.9 12.8 11.3 13.5 13.9 13.9 13.7 12.5 13.4 12.3 12.1 18.1

+700 12.4 15.2 15.2 15.0 13.4 11.7 15.6 15.8 15.9 15.6 14.9 14.3

+600 13.2 15.4 15.3 14.5 15.7 15.6 16.1 15.0

+500 14.5 15.7 15.4 15.6 16.1 14.9

+400 15.5 15.2 15.5 14.8

+300 15.5 15.5 15.6 16.0 16.3 15.4 15.2 15.7 15.5 15.7 15.5 15.6

+200 15.5 15.4 15.6 16.1 16.0 15.9 15.6 15.7 15.6 15.8 15.7 14.8

+100 15.7 15.2 15.9 16.1 15.9 16.1 16.0 15.8 15.4 15.6 15.9 15.5

0 15.5 15.6 15.5 15.9 16.0 16.1 15.5 15.9 15.3 15.1 15.8 15.8

-100 15.6 15.8 15.9 15.9 16.3 16.1 16.1 16.3 16.1 16.0 15.5 18.1

-200 15.7 15.8 15.6 15.7 16.2 16.2 16.2 16.3 15.9 15.8 14.9 18.1

-300 15.6 15.3 15.5 15.6 15.8 16.1 16.5 15.0 14.9 15.2 14.5 18.2

-400 16.2 16.2 15.1 15.6

-500 15.4 16.6 15.1 15.0

-600 15.4 17.4 15.3 15.0

-700 15.0 17.1 15.2 14.5

-800 14.6 16.9 15.0 14.9

-900 14.8 16.6 15.1 15.0

-1000 15.2 16.2 15.1 14.9

-1100 15.0 15.2 15.5 14.8

-1200 15.0 14.7 14.7 14.6

-1300 15.0 15.0 16.0 14.0 13.7 13.6

-1400 15.0 14.5 14.8 15.4 14.3 14.0 13.3 14.5

-1500 14.6 14.9 14.7 14.7 14.7 15.1 14.9 14.8 14.8 14.6 12.9 14.6

-1600 14.5 14.3

10%+

(+/-) 10%

10% - 15%

15% - 20%20% - 25%

25% - 30%

30% - 35%

35% - 40%

>40%

ref_value 15

margin % 10

band_min 13.5

band_ma 16.5

perc_incr 5

Figure 3 Typical PEC Results Data Sheet Format

(Produced from PEC Excel Spreadsheet Both_offl2 Corrected)



0153-001

PROCEDURE I 15 003

FLOODED MEMBER DETECTION

CONTENTS

Para Page

1 INTRODUCTION 3

2 TASKS 3


2.2 Anomaly Tasks 3



3.2 Flooded Member Detection (FMD) Systems 3

3.3 Operational Appl ication and Constraints (IN-FMD) 4

3.4 Anomaly Tasks (Addit ional/Optional) 5

3.5

Weld Inspection (VI-DVI) 5

4 REPORTING 5

4.1 Final Report 5




0153-001




0153-001

PROCEDURE I 15 003

FLOODED MEMBER DETECTION

1 INTRODUCTION

Flooded Member Detection (FMD) will be employed as a first pass inspection method to inspectstructural members so as to identify which, if any, are flooded. FMD will also be required to inspectmembers for flooding following damage, report of weld cracking or to locate blockages in pipelines,caissons, etc, and will be specified in the Offshore Workscope.

This Procedure may be used in conjunction with Procedures I 15 001 and I 15 002 to investigateanomalies.

2 TASKS

2.1 Standard Tasks


IN-FMD - Flooded Member Detection

2.2 Anomaly Tasks

The following work tasks will be required to be conducted on finding a flooded member, as per Section2, Chapter 6, ‘Anomaly Reporting & Criteria’, or as specified in the workscope, and /or Shell OffshoreRepresentative, should a flooded member be suspected.


VD-ROV - ROV Video




The inspection is to be carried out by ROV, under the guidance of a CSWIP 3.3u or 3.4u InspectionController.

FMD System Operators will be supplied by the system's operating company. Suitably trainedadditional system operators may be provided by the contractor. All will be suitably qualified Radiation

Protection Supervisors (RPS).

The system may be employed by divers, however it is not envisaged that this option will be adopted. Ifused by divers, no inspection qualification is required, however suitable on site instruction into its useand risks will be provided by the FMD Operators technician.

3.2 Flooded Member Detection (FMD) Systems

The Pro-Sub Services Ltd., ‘Gamm@chek’, Gamma Radiation FMD technique is the preferred methodfor inspecting for flooded members. The method of use will only be operated as per the latest Pro-Sub’Gamm@chek’ Operating Procedure.

The use of Gamma Radiation to detect for water within a member is based on the principle that less

radiation will be able to pass through a flooded member.




0153-001

A gamma source is held at one side of the member, with a detector held diametrically opposite on theother side of the member to record the amount of passing radiation. Given the member diameter andwall thickness, it can thus be determined if the member is dry, flooded or % of partial flooding.

There are other diver operated ultrasonic FMD systems available, but it is not envisaged to utilisethese systems.

The ‘Gamm@chek’ system can be deployed by either ROV, diver or rope access and needs no sitecleaning prior to inspection being carried out.

There are two forms of ‘Gamm@chek’ FMD frames that can be employed:

(1) The primary frame is a mechanical device, which allows re-configuration of the frame fordifferent member diameters without need to recover the vehicle. This frame when employedwith a rotating manipulator, removes the requirement for any recovery for reconfiguration.

(2) The secondary frame requires recovery and reconfiguration to accommodate members ofdifferent sizes, and as such is less efficient than the mechanical frame. Its use is only allowedwith approval received prior to mobilisation from the Responsible Structural Engineer. Its use

therefore should only be necessary as a backup method, or where the mechanical frame is notcompatible with the ROV approved for its deployment.

Pro-Sub Services Ltd. are to be supplied with full details of the members to be inspected, includinglocation drawings, member diameter, wall thicknesses including location of WT changes and memberorientation prior to mobilisation. This is to allow the data for the members to be inspected, to be pre-entered into the software database. This will allow pre-planning, to increase the efficiency of thesurvey. Local rules for handling and use of Radioactive Material apply. A Company specified RadiationProtection Supervisor (RPS) is required on site to handle the Radioactive Source.

3.3 Operational Appl ication and Constraints (IN-FMD)

Although operation of the system will be carried out by the Manufacturing Company's personnel, the

following basic applications are to be carried out at inspection sites:

(1) The ROV is to inspect structural members in a logical sequence by member size andorientation, thereby minimising time spent on surface for FMD Jig reconfiguration.

(2) Readings, where possible, are to be taken clear of any obvious disturbances such as welds,doubler plates, other appurtenances such as grout pipes, and where significant drill mud existson members. All such items could give spurious results.

(3) All members are to be inspected at the lowest point:

(a) Horizontal Members - 6 o'clock position (mid point of member).

(b) Vertical members - Lowest accessible point.

(c) Vertical Diagonal Members - Underside at lowest accessible point.

(4) Where flooding is indicated at the base of a vertical or vertical diagonal member, no furtherinspection to ascertain the level of flooding is required.

(5) Where flooding is indicated on a horizontal member, no additional readings should be required,unless it is unsure as to whether internal diaphragm plates exist. In this case additional readingsmay be required, unless as-built drawings are available which can confirm the memberconfiguration.

Where partial flooding of the member diameter is identified, the systems own software can beused to identify the extent of partial flooding, or failing that by use of a comparison againstreadings on a known dry member having the same physical attributes.


mailto:Gamm@chek

mailto:Gamm@chek



0153-001


3.4 Anomaly Tasks (Addit ional/Optional)

Where flooding is indicated the following tasks are to be carried out;

(1) GVI of the member is to be carried out where there is no previous history of flooding, or nosuspicion of a likely cause for flooding. Investigations are to be conducted for the following

possible causes of flooding:

(a) Gross structural damage,

(b) Debris which may have caused gross damage,

(c) End weld connections

(d) Possible flooding/grouting holes, which would be, located at the member ends, at the 12and 6 o’clock positions.

(2) Video is only required, should a possible cause for the flooding be identified.

(3) Cleaning should only be carried out once a possible cause has been identified. No majorcleaning program is to be commenced without consultation with Shell Offshore Representative,acting on advice from the Responsible Structural Engineer.

3.5 Weld Inspection (VI-DVI)

If specified in the workscope, or advised by the Shell Offshore Representative, acting on advice fromthe Responsible Structural Engineer, carry out cleaning and inspection and detailed visual inspectionof both end welds. Seam or Circumferential welds may also be specified. Refer to Section 1, Chapter4 for cleaning and DVI specification.

4 REPORTING

4.1 Final Report


The report should list all flooded members, and any members not inspected giving reasons, i.e.restricted access.

Where flooding has been identified, confirmation of the extent and results of any resultant survey,including an indication of the extent of any cleaning is required.

An independent report is to be submitted by Pro-Sub Services Ltd.



0153-001

PROCEDURE I 20 001

CONCRETE SURFACE AND DAMAGE INSPECTION

CONTENTS

Para Page

1 INTRODUCTION 3

2 TASKS 3





3.2 Inspection Areas 4

3.2.1 Concrete Ring Beam Inspection (Reference Fig.1) 4

3.2.2

CGF to Concrete Ring Beam Interface Inspection (Reference Fig. 2) 4

3.2.3 Base of Leg/Shaft to Cell Top Interface Inspection (Reference Fig. 3) 4

3.2.4 Star Cell / Tri-Cell Inspection (Figure 3 & 4) 4

3.2.5 Outer Wall Cell Intersection Inspection (Reference Fig. 5) 5

3.2.6 Cell Wall and Shaft Construction Joints 5

3.3 Init ial Survey (VI-ROV / VD-ROV) 5

3.4 Debris (Drill Cuttings/Mud) Removal (DB-REM / CL-DRG) 5

3.5 Inspection - Diver or ROV 6

4 OPTIONS 7

4.1 Detailed Visual Inspection (IN-DVI) 7

4.2 Close Visual Inspection (IN-CVI) 7

4.3 Defect Mapping 7

4.3.1

First Time Measurement 8 4.3.2 Repeat Measurement: (Crack Monitoring) 8

4.4 Concrete Damage Survey 8

4.4.1 Preliminary Works (VD-ROV) 8

4.4.2 Damage Inspection (VI-DVI) 8

5 REPORTING 9

5.1 Final Report 9

FIGURES

No Page

1 Concrete Ring Beam Inspection Location - Typical 10

2 Leg to Cell Interface Inspection - Typical 11

3 Tri-Cell / Star Cell Inspection Areas 13

4 Vertical Cell Wall Interface Inspection 13




0153-001




0153-001

PROCEDURE I 20 001

CONCRETE SURFACE AND DAMAGE INSPECTION

1 INTRODUCTION

The work method is to be applied to the inspection of selected areas of the concrete structures. Theseareas consist of:

• Caisson roof to leg connection

• Concrete ring beam

• Vertical Cell/Cell, Star/Tri-Cell intersections and Concrete construction joints

• Conductor guide frame/Leg connection

The attached sketches at the end of this procedure detail the baseline inspection required at theselocations. Should the inspection areas be increased or decreased, this will be fully detailed in theworkscope.

In addition, the work method is to be applied for the dimensional survey of damage located onconcrete structures.

All works may involve debris, marine growth and mud/drill cutting removal, dimensional and videosurvey.

Inspection may be carried out by ROV and/or diver. The method - ROV or diver and level of inspection- Close Visual Inspection (CVI) or Detailed Visual Inspection (DVI) will be clearly defined in the

workscope. In the case of damage discovery during the course of a workscope, the availableresource, ROV or diver, will be utilised accordingly.

2 TASKS

2.1 Standard Tasks




DB-REM (CL-DRG) - Debris Removal (Dredging)



2.2 Optional Tasks



VI-CVI - Close Visual Inspection





0153-001

Should additional activities be carried out or anomalies noted, suitable work tasks and task codes maybe added to cover works. Specifically Contact CP readings (CP-CON) are required on exposed re-bar.

Should any anomalies be noted they are to be reported and acted upon as per the relevant section ofthe 'Subsea Inspection Anomaly Reporting Requirements' Section No 2.




3.2 Inspection Areas

Areas required to be inspected will be defined in the workscope. In the main they will be specified inthe locations and to the extents as listed below, and as shown in the referenced drawings at the end ofthis procedure. Where inspection is not in a standard location, extents will be specified in theprocedure.

3.2.1 Concrete Ring Beam Inspection (Reference Fig.1)

Inspection is required of an area of the concrete ring beam, to which conductor guide frames (CGF)are secured to the platform legs/shafts.

The inspection area is to the inboard, CGF, side of the leg. The extents are for 2m either side of theCGF centre line and for 300mm up the leg, and 300mm across the ring beam, from the leg/ring beamintersection.

3.2.2 CGF to Concrete Ring Beam Interface Inspection (Reference Fig. 2)

Inspection is required of the interface points where the CGF steel framework penetrates the concretering beam. The workscope will specify if all three interface points, the central box and outboard tubularsteel penetration points of the CGF framework, or individual penetration points are required forinspection.

The inspection area is for 150mm out from the end of the steelwork, covering the steel/concreteinterface and surrounding concrete.

3.2.3 Base of Leg/Shaft to Cell Top Interface Inspection (Reference Fig. 3)

Inspection is required of the interface between the base of the leg/shaft and the cell top.

A 5m arc, its position around the leg to be specified in the workscope, is to be inspected for 300mm up

the leg, and out along the cell top. Where defects are found to extend outside this area, clean andinspect as required as instructed by the Shell Offshore Representative, acting on advice from theresponsible structural engineer.

Should mud and debris build up preclude inspection of the specified area, an alternative site may beselected, as directed by the Shell Offshore Representative, acting on advice from the responsibleProject Engineer. Any alternative site, should take into account the location of previous inspections,which can be obtained from the COABIS database.

3.2.4 Star Cell / Tri-Cell Inspection (Figure 3 & 4)

Inspection is required on all internal walls of selected star cell, or tri-cell, and to the top of the cell.Unless otherwise specified in the workscope, inspection is required on all internal vertical walls for 1m

down. Where an overhang exists, the 1m inspection area is to be taken from the top of the verticalwall, not to include any overhang. Externally, the top of the cell is to be surveyed for 0.5m out from theStar Cell entrance, in all directions.




0153-001

Should cracks be identified, then the survey is to continue to ascertain the extent of the crack, asaccess/safety allows. Should, as a result, the duration of the survey become extensive, theresponsible Structural Engineer/TA should be consulted on how to proceed.

This inspection would normally be required to be performed by divers, due to access. However it maybe possible for small ROV’s to access the sites in some cases. In both cases, the diver and ROV are

to be aware of potential hazards, which may include debris.

3.2.5 Outer Wall Cell Intersection Inspection (Reference Fig. 5)

Inspection is required of the intersection between two adjacent outer cell walls. The required cell wallintersections will be specified in the workscope.

At the top of the cell wall intersections, the inspection area is required across the full width of theintersection, for 3m along both the horizontal ledge and vertical face. The inspection area should beincreased to cover any defects extending outside this area, except where the defect extends intoareas of mud and debris which will require further debris removal. In this case act as directed by theShell Offshore Representative, based on advice from the responsible Structural Engineer/TA.(Reference Fig. 5)

The workscope may specify a location lower down the cell wall on an intersection. This is usuallytowards the base of the cell wall intersection. In this case the inspection will be required over a 3mlength of the vertical face, at a depth specified in the workscope.

3.2.6 Cell Wall and Shaft Construct ion Joints

Individual construction joints will be specified for detailed visual inspection, typically requiring cleaningprior to inspection. Such construction joints have their own component number. Their locationwill be specified by depth and position on the cell wall or shaft leg. Construction Joints can typically beidentified by a pronounced joint within a band of epoxy coating.

Typically this inspection would be required to be performed by ROV, but may be required to be

inspected by diver. If diver inspection is required, an ROV is to be employed to check above theworksite for any hazardous debris.

3.3 Init ial Survey (VI-ROV / VD-ROV)

Carry out an initial survey by ROV of the area to be inspected. The objective of this survey is todetermine the extent of the debris and marine growth to be removed. A combination of the use ofvideo in SIT, for general location, and colour for more detailed survey is to be used. Continuous videorecording is to be taken throughout the survey.

Establish that the correct worksite has been identified using location markers (i.e. Cell Wall Numbers),and other salient points of reference. This is to be recorded on video.

All items of debris and mud/drill cuttings are to be noted and the following details recorded:

• Location

• Description

• Size - large, small

3.4 Debris (Dril l Cutt ings/Mud) Removal (DB-REM / CL-DRG)

On completion of the initial survey, remove debris and mud/drill cuttings from the area to be inspected.




0153-001

Mud/drill cuttings removal is likely for inspection areas at the base of the structure, or on cell toplocations specified above in 3.2.3 – Base of Leg/Shaft to Cell Top Interface Inspection (Fig.3), 3.2.4Star Cell / Tri-Cell Inspection (Figures 3 & 4), 3.2.5 – Outer Wall Cell Intersection Inspection (Fig 5).Where possible the workscope will give an indication to the extent of mud/drill cuttings to be removed.

For ROV operations, a combination of ROV mounted dredge pump and water jet is to be utilised. If

extensive mud/cuttings are known to be present, this will be highlighted in the workscope and suitabledredging equipment mobilised.

Where extensive mud/cuttings are likely to be present, diver intervention will usually be specified. AirLifts are the normal method for mud/cuttings removal, but where extensive mud/cuttings are known tobe present, this will be highlighted in the workscope and suitable dredging equipment mobilised.

If debris and mud/drill cuttings are found to be extensive, the Shell Offshore Representative is toconfirm the amount of time to be spent undertaking these tasks, as advised by the responsible ProjectEngineer.

3.5 Inspection - Diver or ROV

Cleaning will be required prior to the inspection, the levels of which are defined below, or as detailed inthe workscope. Where necessary, debris removal may also be required. Should the extent of debrisbe prohibitive, an alternative location may be selected on consultation with the Shell OffshoreRepresentative.

Inspection may be carried out by ROV or diver or a combination of both. The extent and level ofinspection shall be defined in the workscope. The level of inspection shall be defined as either aDetailed Visual Inspection (DVI) or a Close Visual Inspection (CVI) at the selected areas. (Refer to 4.1and 4.2 below for details).

The inspection (CVI or DVI) shall pay particular attention to any areas where the following occurs:

(1) Cracking or other discontinuities (excluding joints or normal discontinuities).

(2) Swelling, lumps, popout or spalling of the concrete surface.

(3) Change of aspect/colour of concrete.

(4) Disbonding or separation of bitumastic or epoxy coating.

(5) Appearance of salt secretion or chemical filtering through the skin.

(6) Exposed rebar. Where re-bar exists, contact CP readings are required on 1-2 differentexposed items, per inspection area. Specific locations have also been created for thetaking of reference CP readings at areas of known cracking. These will be specified in the

relevant workscope.

(7) Evidence of Corrosion which may relate to exposed rebar, at locations of cracks or spalling.

With respect to the above defects, the description of any damage or any anomalies discovered shouldbe reported using standard terminology in accordance with the Department of Energy, OffshoreTechnical Reports entitled 'Classification and Identification of Typical Blemishes Visible on the Surfaceof Concrete Underwater' OTH 84 206 and OTH 87 261.

NOTE: Any anomalies are to be referenced to a datum start point, accurately positioned andrecorded.

Digital Still Images (PH-DIG) should be taken of any anomalies or other areas of interest. These may

be supplemented by suitable drawings to show the location, size and details of the item of interest.




0153-001

4 OPTIONS

4.1 Detailed Visual Inspection (IN-DVI)

This level of inspection may be carried out by ROV or divers, and is to be recorded on video.

The purpose of the inspection is to establish the condition of the component, the condition of theconcrete surface and any attachments, and detect defects that would be otherwise obscured bymarine growth.

A limited amount of cleaning will be required to carry out this inspection. Cleaning shall be carried outby either water jetting, scrapers and/or wire brushes. Soft marine growth only should be removed, thestandard of cleaning shall be sufficient to enable details of the components to be seen. It will notnormally be necessary to remove hard marine growth unless it obscures detail. Care to be takenduring the cleaning to ensure any surface coatings are not damaged.

The detailed visual inspection of the area shall be carried out looking for any defects as categorised in3.5 above.

Should any anomalies be found then they shall be referenced to a known datum point and reported forfurther action.

4.2 Close Visual Inspection (IN-CVI)

This type of inspection may be carried out by divers or a suitably equipped ROV, and is to be recordedon video.

The purpose of this inspection is to establish a Close Visual Inspection of specific areas of interest,typically concrete joints, specifically looking for any cracks in the concrete surface.

Cleaning shall be carried out using medium pressure water jetting or scraper/wire brush for divers,to remove both soft and hard marine growth, taking care not to damage the surface and affect any finecracks that may be present. Hard marine growth, in the form of worm cast stains, may be left in placeunless it obscures detail.

A Close Visual Inspection is to be carried out looking for defects as categorised in 3.5 above.

Should any cracks be found, then additional cleaning shall be carried out to follow cracks and allbranches to the full extent and until they vanish from view. Particular attention should be given tocrack detection in the folds between any flat intersections and curved surfaces.

The level of inspection shall be sufficient to detect cracks with a crack width opening of 1mm andabove. Once detected, the inspection shall follow the crack until the width has reduced to 0.5mm orless. Where possible crack depth is to be recorded.

For the ROV to carry out this level of inspection a zoom camera (preferably manipulator mounted,unless suitability can be shown otherwise) will be required, with a suitable measuring device (typicallymanipulator held). It is recommended that such a measuring device comprises of two rules, mountedat 90 degrees, marked in 10mm increments, length of which to be determined by the area underinspection.

4.3 Defect Mapping

All defects found shall be categorised, i.e. cracks, pop-outs, spalling, etc. The location and extent shallbe fully detailed in a dimensional drawing to be included in the Final Report, including any grid patternthat may have been employed.




0153-001

The description of any damage or any anomalies discovered should be reported using standardterminology in accordance with the Department of Energy, Offshore Technical Reports entitled'Classification and Identification of Typical Blemishes Visible on the Surface of Concrete Underwater'OTH 84 206 and OTH 87 261.

4.3.1 First Time Measurement

All characteristic points should be marked up in such a way that the marks or markers are visible instand-off. Characteristic points include crack ends, branch points and points where the cracks changedirection. Permanent markers should be employed where possible for cracks, for future crackpropagation monitoring. This inspection is to be recorded on video, to include any markers.

Where divers are employed, crack ends are to be chisel marked for permanency, and marked withblack crayon. A dimensional drawing should be made of the crack pattern, noting any markers.

4.3.2 Repeat Measurement: (Crack Monitoring)

Where an adequate dimensional drawing of defects/cracking exists from inspection in previous years,any repeat measurement is to be aimed at detecting extension of the crack pattern (new

branches or cracks being longer) or change in crack morphology. When the crack pattern haschanged, the changes should be documented as under 'first time measurement', i.e. starting with thedrawing from the most recent inspection, noting any growth or changes. This inspection is to berecorded on video.

4.4 Concrete Damage Survey

4.4.1 Prelim inary Works (VD-ROV)

The ROV will carry out, and fully video record, a general visual survey of the area of interest notingarea of damage, item of debris which may have caused the damage or any other cause, marinegrowth coverage and confirm as built configuration for access and rigging for dimensional survey.

4.4.2 Damage Inspection (VI-DVI)

On completion of the general visual survey the diver or ROV is to carry out and video record aDetailed Visual Inspection (DVI) of the damaged area prior to cleaning. The damaged area is to besuitably identified, where possible, and is to clearly show all aspects of the damage.

Any debris noted during the initial survey is to be removed by whatever means is considered suitableand that will allow safe and unrestricted access to the inspection area. Mud/drill cuttings may beremoved using dredge pump or Propwash dredging equipment.

Deploy cleaning equipment and clean the damaged area to allow DVI.

On completion of cleaning operations, the diver is to carry out a DVI of the area, to fully describe anddimension the damage as found.

The diver is to probe the area of damage with a suitable tool to establish whether the surface is looseor crumbling.

Carry out a dimensional survey of the damage to define its overall dimensions and where appropriateits depth. Where surface cracks are identified their width is also to be reported.

Any exposed reinforcement or aggregate where appropriate is to be inspected and reported.

Dependant on size, consideration should be given to the use of a grid pattern, in which to accuratelyplot the defect.

Where impact damage is found, a straight edge or taut wire should be used to ascertain the depth ofconcrete loss/damage.




0153-001

The description of any damage or any anomalies discovered should be reported using standardterminology in accordance with the Department of Energy, Offshore Technical Reports entitled'Classification and Identification of Typical Blemishes Visible on the Surface of Concrete Underwater'OTH 84 206 and OTH 87 261.

Digital Still Images (PH-DIG) are to be taken of any anomalies or other areas of interest. These may


5 REPORTING

5.1 Final Report

Inspection data format, video log and anomaly report format, where applicable, are to be completedfor all works carried out.


All anomalies are to be referenced, with a general statement made concerning the types and extent of

anomalies identified. Any C1 anomalies are to be commented on more specifically. Other referencesare to be made to any digital still images and drawings.

Detailed drawings or sketches shall be produced for all anomalies found. These shall clearly show theextent of any defects found referenced to a known datum point as discussed under 3.5 and section 0. As stated above, where ‘Repeat Measurements’ are undertaken, any drawing should reference theprevious results, with any propagation highlighted. Previous survey drawings are contained within theCOABIS database.






0153-001

CGF-EL

150mm INSPECTIONADJACENT TO CONCRETE/ STEEL AREA

CONCRETERING BEAM

CGF

LEG

CGF BRACING(TYPICAL)

STEEL BOXED SECTIONWITH PROTECTIVECOATING

STEEL/CONCRETEINTERFACE

CONCRETE STRUCTURE

MARINE GROWTH TREMOVED OVER 150mmAREA TO ALLOW DVI OFCONCRETE SECTION.AREA HAS AN EPOXYCOATING

CLEANING AND INSPECTION AREA DETAIL

INSPECTION SITE

O BE

AREA

Figure 2 CGF to Leg Interface Inspection – Typical

Re-issue 04/05 I 20 001Page 11 of 13



0153-001

Tri Cell /Star Cell(see fig 4)

Figure 3 Leg to Cell Interface Inspection - Typical

I 20 001 Re-issue 04/05Page 12 of 13





0153-001

PROCEDURE I 20 002

GENERAL CONCRETE SURFACE INSPECTION - SUBSEA AND TOPSIDE

CONTENTS

Para Page

1 INTRODUCTION 3

2 TASKS 3




3.1 Inspection Qualification 3

3.2 Subsea Inspection (VI-GVI / VD-ROV) 3

4 OPTIONS 5

4.1

Topside Inspection 5

5 REPORTING 5

5.1 Final Report 5




0153-001




0153-001

PROCEDURE I 20 002

GENERAL CONCRETE SURFACE INSPECTION - SUBSEA AND TOPSIDE

1 INTRODUCTION

The work method is to be applied to a general video survey by an ROV of large areas on concretestructures. The purpose of the survey is to visually inspect a large area for possible damage and alsoto note general marine growth coverage.

As an option, above water and splash zone visual inspection may be required to be carried out fromthe diving support vessel, including topside photographs.

2 TASKS

2.1 Standard Tasks






2.2 Optional Tasks








3.1 Inspection Qualification

The inspection is to be carried out by ROV, under the guidance of a CSWIP 3.3u, or 3.4u InspectionController. Topside inspection to be carried out by CSWIP 3.3u, or 3.4u Inspection Controller.

Should any anomalies be noted they are to be reported and acted upon as per the relevant Section ofthe 'Subsea Inspection Anomaly Reporting Requirements’ Section 2.

3.2 Subsea Inspection (VI-GVI / VD-ROV)

The ROV will carry out, and fully video record, a general visual inspection of all the concrete surfacesas specified in the Component Task Sheet (CTS), or as directed by the Shell Offshore Representative.




0153-001

The inspection is to commence with a SIT view of the general area, to confirm the correct componenthas been identified, with reference to known local components. Continuous video recording in SITmode for overall coverage and colour for detailed close up work is to be conducted throughout thesurvey.

The purpose of this inspection is to record the following:

(1) As-built configuration.

(2) Any damage to concrete.

(3) Any discolouration of the concrete i.e. rust staining.

(4) Condition of interface of steel fixtures to concrete.

(5) Condition of temporary opening/closures.

(6) Any debris.

(7) Any erosion of concrete.

(8) Marine growth coverage. Describing marine growth as hard or soft, giving estimated thicknessand percentage cover of each.

The description of any damage or any anomalies discovered should be reported using standardterminology in accordance with the Offshore Technical Reports entitled 'Classification andIdentification of Typical Blemishes Visible on the Surface of Concrete Underwater' OTH 84 206,HMSO and OTH 87 261, HMSO.

No cleaning is required unless specified. However, should an area of particular interest be obscuredby marine growth, or if the surrounding area shows signs of damage or deterioration, then all soft

marine growth and any hard marine growth, which obscures the area of interest is to be removed.

Camera movement must be slow and deliberate. Lighting must be adequate to give good colourrendition. Ensure that lighting and viewing is optimised to avoid flare and fade out. Standoff light andfocus is to be optimised.

Where possible the camera and lights are to be orientated at right angle to inspection surface to giveoptimum viewing, as viewing at differing angles will cause flare on screen close to subject and fadeout at the far edges of the screen. The areas to be inspected should be covered in a logical order toease subsequent topside interpretation.

The video survey is to be carried out at a speed that is slow enough to allow the observer toadequately observe, comment on and note the condition of the structure.

All route details should be mentioned i.e. moving east on heading 093 degrees along horizontalconstruction joint cell top 8, depth -86m, now arrived at vertical intersection between cell 8 and 7, startsurvey following vertical intersection toward sea bed. Components should be identified as they appearin the camera's view, not when they appear in the pilot's view unless coincident. Constant referenceshould also be made to depth and direction.

The camera standoff is to be adequate so as to show the subject, without loss off definition. Wherenecessary, the standoff distance should be increased to show a larger area i.e. temporaryopening/closure.

Other than in exceptional circumstances, the camera is to be oriented in the vertical plane. If thecamera is rotated, the extent and direction of the rotation must be frequently mentioned on the videocommentary. Any camera tilt must be described, in terms of orientation, up or down, in thecommentary.






0153-001

PROCEDURE I 30 001

SEAWATER INLET INSPECTION

CONTENTS

Para Page

1 INTRODUCTION 3

2 TASKS 3





3.2 Safety 4

4 ROV CONCRETE SHAFT/LEG INLET (SEA CHEST) INSPECTION 4

4.1

General Visual Inspection (VI-GVI / VD-ROV) 4

4.2

Proximity (Contact) CP Readings General (CP-PRX / CP-CON) 6

4.3 Options: 6

4.3.1 Cleaning for Inspection (CL-INS) 6

4.3.2 Detailed Visual Inspection (VI-DVI) 6

4.3.3 Wall Thickness Measurements (WT-DIG) 6

4.3.4 Diver Concrete Shaft Leg Inlet (Sea Chest) Inspection (VI-DVI) 6

4.4 ROV FPSO Sea Chest Inspection (VI-GVI / VD-ROV) 8

5 REPORTING 9

5.1 Final Report 9

FIGURES

No Page

1 Brent Bravo Inlet 26-035, Shaft 1 10

2 Brent Bravo Inlet 26-036, 037 & 038, Shaft 1 11

3 Cormorant Alpha Typical Inlet Arrangement 12

4 Dunlin Alpha Inlets 26-027 & 028 13

5 Anasuria FPSO Sea Chest Orientat ion and Mark ing 14




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0153-001

PROCEDURE I 30 001

SEAWATER INLET INSPECTION

1 INTRODUCTION

This work method is to be applied to the inspection of seawater inlets (sea chests) by both diver andROV, on concrete structures and FPSO’s (Floating Production Storage & Offtake Tankers).

Dependant on requirements of the responsible Structural Engineer, work will include; General ROVsurvey, ROV CP survey, external cleaning for DVI, cleaning of blockage from grille, removing andreplacing the protective grille, internal cleaning of the inlet (sea chest), debris clearance, UT wallthickness measurements, Cathodic Potential (CP) measurements, anode and video survey.

NDT methods under Procedure I 15 002, section 3.3, may be required to conduct UT wall thicknessinvestigation.

2 TASKS

2.1 Standard Tasks



VD-ROV - ROV Video Survey


CP-PRX (CON) - Proximity (Contact) CP Readings

2.2 Optional Tasks


CP-CONC - Proximity CP Readings for Concrete Structures



CN-RGR - Remove Grille/Replace Grille


WT-DIG - Wall Thickness Readings


Any number or combination of the listed work tasks may be used or called for on the workscope, orduring the course of the inspection, or to fully investigate and report damage as found.




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The standard inspection is to be carried out by ROV, under the guidance of a CSWIP 3.3u or 3.4uInspection Controller. More detailed inspections may be required to be carried out by a

CSWIP 3.1u/3.2u diver, under the guidance of a CSWIP 3.4u Inspection Controller.


3.2 Safety

WARNING: PRIOR TO ANY SUBSEA INSPECTION WORK ON SEAWATER INLETS, A TASKRISK ASSESSMENT (TRA) SHOULD BE CARRIED OUT. SHOULD THE TASKREQUIRE CLEANING OF THE INLET GRILLE, OR DIVER INTERVENTION, THEPLATFORM INTAKE IS TO BE ISOLATED.

Risks involved with inspection of a seawater inlet are:

(1) ROV entrapment due to inlet suction.

(2) Diver hazard due to inlet suction.

(3) Damage to platform internal pumps, due to marine growth/debris ingress caused by cleaningwithout prior isolation of the inlet and its associated pumps.

For a general ROV survey, isolation of the inlet should not be required. The rate of suction from aninlet is generally of low volume and all inlets have a grille. However, the TRA may raise an area ofconcern due to vehicle size.

Where cleaning for inspection is required on the external components of the inlet, excluding thegrille, again it is envisaged that isolation should not be required.

Cleaning of the grille may be required as part of the workscope, or as a result of an anomaly raiseddue to marine growth or debris blockage. In this instance cleaning is not allowed without the priorapproval of the platform, with all relevant isolations in place.

Isolation of the inlet is required, for all diver intervention works.

For platform inspections, if diver intervention is required, the TRA should take into account thepossible lack of security of any work platform below the inlet. The initial ROV survey should assess thesecurity of the platform, with further diver integrity checks made on arrival at the site.

When working alongside an FPSO. An ‘FPSO Pre-Entry Checklist’ requires to be carried out by thevessel DP Operators, as part of their field entry trials.

4 ROV CONCRETE SHAFT/LEG INLET (SEA CHEST) INSPECTION


Inspection activities will vary, dependant on the requirements of the workscope.

Figures 1-4 show various types of seawater inlet encountered on the Shell Northern Field Platforms.Some of the drawings are platform specific, but will be relevant to other platforms such as BrentCharlie and Brent Delta.




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ONEgas East has a single concrete platform (F3-FB-1P), which has two Sea Water inlets on its centralutility shaft, which differ from the Northern platform inlet designs. The inlets are in the form of largediameter short stubs, with a meshed grille. No drawings are available of these inlets, at the time ofproduction of this procedure.

Typically inspection requirements will be for ROV intervention only. Diver intervention may be required

as a result of ROV findings, or for general concerns raised by the responsible Structural Engineer.

The basic requirement for the inspection of an inlet (sea chest) on a concrete shaft/leg is as for aGeneral Visual Inspection (GVI). Areas of interest are:

(1) Damage to the inlet and surrounding concrete,

(2) Debris and other obstructions,

(3) Integrity of any biocide pipework,

(4) Anode integrity/wastage,

(5) Particular attention should be paid to the inlet/shaft steel/concrete interface for any evidence ofcracking or disbondment.

(6) Inlet stub and flanges for evidence of corrosion/coating damage. See Note (1).

(7) If a diver platform is present (below the inlet) its integrity, in particular its securing points, shouldbe checked.

Any debris found should be removed if possible.

NOTES: (1) Past history has found severe corrosion of the stub, which has been hidden by thepresence of an outer coating. To this end, the internal components of the inlet,

particularly the stub walls, and the stub externally should be checked for evidence ofcorrosion externally and through the grille. Note WT readings required should coatingdamage be evident, see 4.3.3 below.

(2) It is a design feature of some of the grille bolting arrangements at Dunlin Alpha thatsome bolts have deliberately been left slack, and therefore are not anomalous. Seeaccompanying drawings fig.4.

Prior to commencement of the inspection, the inlet ident marker should be identified, to confirm thecorrect inlet. This should then be recorded at the start of the video inspection. This is typically a raisednumber, above the inlet, but which are not always present.

Action to be taken if inlets are blocked (greater than 30%):

• Raise anomaly, take Digital Still images - Report onshore and to the platform.

• Confirm/agree with the platform that cleaning may proceed. Isolate inlet prior to carrying out anycleaning. Do not commence cleaning without clearance from the platform, and with thecorrect isolation permit in place.

• Carry out cleaning activities - video on completion and take Digital Still images.




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4.2 Proximi ty (Contact) CP Readings General (CP-PRX / CP-CON)

Proximity probes are the preferred method for obtaining the required readings. However, with themethod of use of the Shell preferred Pro-Sub CP-Chek CP system, contact readings are inevitable,but should be discussed prior to use with the Shell Offshore Representative.

CP readings are to be taken prior to any cleaning. Readings should be taken at four cardinal clockpositions on the inlet stub, on the grille arrangement (or blanking flange) and any anodes. Note that insome cases, the grille may be galvanized, as such no readings may be obtained.

Where insufficient COABIS Workpack task boxes exist, relevant additional CP task boxes need to beraised to accommodate all readings taken.

All CP readings taken by ROV (including methods discussed below) are to be hard wired into thevideo recorder such that the CP readings are continuously displayed on the video screen during theROV survey. CP readings are to be included in the video commentary.

CP readings are to be carried out prior to any cleaning. Calibration readings are required before andafter each dive. Refer to Procedure I 60 004 – Cathodic Protection Monitoring.

4.3 Options:

4.3.1 Cleaning for Inspection (CL-INS)

Cleaning may be required by the workscope, or if marine growth prevents confirmation of integrity. Inparticular the inlet/shaft penetration, the external flange and stub sufficient to confirm integrity.

No cleaning is to be conducted without prior confirmation from the Shell Offshore Representative thatit is safe to do so, with all relevant isolations in place if necessary. The ROV HP water jet is to be usedfor all cleaning purposes.

4.3.2 Detailed Visual Inspection (VI-DVI)

On completion of cleaning, check the inlet for evidence of corrosion, damage to the stub coating andthe inlet/shaft penetration for evidence of cracking or disbondment.

4.3.3 Wall Thickness Measurements (WT-DIG)

WT readings taken by ROV will be required at the four cardinal clock positions on the inlet stub, or atother locations as specified in the workscope.

As part of an anomaly investigation, WT readings are required to be taken on the inlet where areas ofthe protective coating are missing.

4.3.4 Diver Concrete Shaft Leg Inlet (Sea Chest) Inspection (VI-DVI)

4.3.4.1 Worksite Check (VI-ROV)

The worksite area and areas above are to be checked for diver safety, refer to Standard Procedure I01-003, point 4.1. Attention is also to be paid to any work platform beneath the inlet, in particular itssecuring points to confirm its suitability for use.

A general ROV inspection of the inlet will be conducted as per 3.3.1 above.

4.3.4.2 Remove Gril le (CN-RGR)

Any items of debris found on the protective grille, or within the inlet are to be reported and removed.






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4.3.4.6 Wall Thickness Measurements (WT-DIG)

Wall thickness measurements are to be taken on the internal or external surface of the inlet, as accessallows, on areas where the protective coating is missing. The location of each reading should bemarked with a suitable underwater paint marker and suitably reported.

4.3.4.7 Replace Gril le (CN-RGR)

On completion of the inspection work replace the protective grille. If the original fasteners weredestroyed during the grille removal, replacements will be supplied by Shell Expro, or sourced by theCONTRACTOR.

The site is to be de-rigged, and an as-left survey to be conducted by ROV, to be recorded on video.

4.4 ROV FPSO Sea Chest Inspection (VI-GVI / VD-ROV)

At the time of writing this procedure, there is presently only one FPSO requiring regular inspection, thisbeing the Anasuria in the Central Sector. It is envisaged that FPSO Sea Chests will only be inspectedby ROV. Should diver intervention be required, then follow point 4.3.4 – Diver Inlet Inspection.

Prior to commencement of the inspection, the inlet ident marker should be identified, to confirm thecorrect inlet. This is particularly relevant for the aft sea chests, which are close together and havecaused confusion in the past. The ident is marked adjacent the sea chest, with the prefix ‘S’ and thennumber, as listed below. This should then be recorded at the start of the video inspection.

Inspection is required to check for any signs of damage, debris and in particular excessive marinegrowth.

Proximity CP readings are to be taken on the sea chests prior to any cleaning. However, with themethod of use of the Shell preferred Pro-Sub CP-Chek CP system, contact readings are inevitable,but should be discussed prior to use with the Shell Offshore Representative.

The CP probe is to be hard wired into the video recorder such that the CP readings are continuouslydisplayed on the video screen during the ROV survey. CP readings are to be included in the videocommentary. Refer to Procedure I 60 004 – Cathodic Protection Monitoring.

The sea chests are to be cleaned on an annual basis. Video and digital photographs are required preand post cleaning, of each sea chest.

Prior to any cleaning confirm/agree with the Anasuria that cleaning may proceed. Isolate inletprior to carrying out any cleaning. Confirm with Shell Representative that required isolationsare in place.

The Anasuria has 9 Sea Chests. The Sea Chest locations are marked on the ship’s hull above thewaterline, in line with the underwater location. In addition, the idents are marked with the outline of theident number created by weld beading 100mm high, on the hull adjacent to the inlets.




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The following table gives the idents, and their relative name, location and COABIS component number

Ident Sea Chest Location Side Component

S1 No 1 Fire Pump Sea Chest Aft Machinery Space Stbd 38-003S2 No 1 Seawater Sea Chest Aft Machinery Space Stbd 38-004

S3 No 2 Seawater Sea Chest Aft Machinery Space Port 38-005

S4 No 3 Seawater Sea Chest Aft Machinery Space Port 38-006

S5 No 2 Fire Pump Sea Chest Aft Machinery Space Port 38-007

S6 Draft Gauge Sea Chest Aft Machinery Space Stbd 38-008

S7 W.B.P. Sea Chest Mid Ships Stbd 38-010

S8 W.B.P. Sea Chest Mid Ships Port 38-011

S9 Fwd Fire Pump Sea Chest Fwd Machinery Space Stbd 38-009

Sea Chest orientation and location markings (topside and Subsea) are shown on figure 5, with thelocations shown in the Anasuria UMDB (2605-001), pages 3-0-13 and 3-0-14.

5 REPORTING

5.1 Final Report


Report the state of the inlet; any blockage found; any resultant cleaning; confirmation of isolations ifany; general results of any CP and WT readings; the presence, location and number of any identmarkers. Include references to all anomalies, video logs and or digital still images taken.

If the full results of any CP or WT readings taken cannot be suitably entered into the COABISdatabase, then the full results may be entered into the Workpack Diary, or a suitable referenceddrawing.




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Figure 1 Brent Bravo Inlet 26-035, Shaft 1

I 30 001 Re-issue 04/05Page 10 of 14



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Figure 2 Brent Bravo Inlet 26-036, 037 & 038, Shaft 1

Re-issue 04/05 I 30 001Page 11 of 14



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Figure 3 Cormorant Alpha Typical Inlet Arrangement

I 30 001 Re-issue 04/05Page 12 of 14



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Figure 4 Dunlin Alpha Inlets 26-027 & 028

Re-issue 04/05 I 30 001Page 13 of 14



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I 30 001 Page 14 of 14

S8

S 8

Dou

Above Waterline

White Paint Mark

S4S5

S 5

S 4

White Paint Mark

Sea Chest Marker Above Waterline

Double Sea Chest

Handle (Eye Plate)

S 1

S 2

S1S2

S6

S 6

S3 Sea Chest MarkerNote:

1. Refer to table page 6, for Sea ChestInformation.

2. Refer to Anasuria UMDB 2605-001,drawing pages 3-0-13 and 3-0-14, for location of Sea Chests in relation tothe vessel hull.

3. Apart from the Draft Gauge (S6), allSea Chests are present on theunderside of the flat hull section. Assuch these Sea Chests are viewedfrom below.

Aft Machinery Space38-008 S6 38-004 S2 38-003 S1

Mid Ships38-011 (S8)

Aft Machinery Space38-007 (S5) 38-006 (S4) 3

Figure 5 Anasuria FPSO Sea Chest Orientation and Markin



0153-001

PROCEDURE I 32 001

BOAT LANDING AND BARGE BUMPER SURVEY

1 INTRODUCTION

The work method is to be applied to a boat landing and barge bumper survey to confirm theintegrity of all landings, access ladders and barge bumpers up to and including their attachmentpoints to the jacket structure. The work will include video survey, debris and damage inspection,dimensional survey and photography.

NDT methods under Procedure I 15 001 may also be required to fully investigate and reportdamage as found.

2 TASKS

2.1 Standard Tasks


VI-SPZ - Splash Zone Inspection





CH-BLT - Hand Bolt Check



PH-DIG - Digital Photographs

Should additional activities be carried out or anomalies noted, suitable work tasks and task codesmay be added to cover works.





3.2 Boat Landing/Access Ladders

Carry out, and fully video record, a general visual survey of the boat landing area and associatedaccess ladders, up to and including the lower landing level. The purpose of this survey is to recordthe following:

(1) Site conditions are currently identified in accordance with the relevant location drawings.




0153-001


(2) Any debris or obstructions in the work area to be removed by whatever means isconsidered suitable to allow safe and unrestricted access to the inspection area.

(3) Confirm integrity of all attachment points to the main structure, including the security of allbolted or clamped connections.

(4) Any areas of damage, distortion, missing grating, ladder rungs or any other anomalies,noting the location and dimensions of each.

On completion of the general visual survey, a sequence of digital images both topside and Subsea(if visibility allows) (PH-TOP / PH-DIG) are to be taken which clearly show the as-built configurationof the complete boat landing.

3.3 Barge Bumpers

Carry out and fully video record, a general visual survey of each of the barge bumpers. Thepurpose of this survey is to record the following:

(1) Site conditions are correctly identified in accordance with the relevant location drawings.

(2) Any debris or obstructions in the work area is to be removed by whatever means isconsidered suitable to allow safe and unrestricted access to the inspection area.

(3) Confirm integrity of all attachment points to the main structure, including the security of allbolted or clamped connections and tyres.

(4) Any areas of damage, distortion, missing tyres or any other anomalies, noting the locationand dimensions of each.

On completion of the general visual survey, topside digital images (PH-TOP) are to be taken whichclearly show the Barge Bumper(s).

4 REPORTING

4.1 Final Report

The Job Completion Report is to précis the results of the inspection, and any subsequent actionsas per the points of interest listed above. Reference section 2, Chapter 1, Section 3.1.5.

All anomalies are to be referenced, with a general statement made concerning the types andextent of anomalies identified. Any C1 anomalies are to be commented on more specifically. Otherreferences are to be made to any digital still images and drawings.

If not anomalous, reference is to be made to any marine growth results taken, confirming thelocation where the data can be obtained, i.e. COABIS database.

Any other specific inspection tasks requested in the workscope are to be commented upon. If thetask could not be completed, a statement is required stating reasons.




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PROCEDURE I 43 001

CAISSON INSPECTION

CONTENTS

Para Page

1 INTRODUCTION 3

2 TASKS 3





3.2 Safety 4

3.3 Above Water Inspect ion (VI-TOP / PH-TOP) 4

3.4 Subsea Inspection 5

3.4.1

General ROV Inspection (VD-ROV) 5

3.5 Cathod ic Protection Monitoring (CP-PRX) 5

4 INSPECTION OPTIONS 6

4.1 Intake / Discharge Cleaning (CL-MGR) 6

4.2 Detailed Visual Inspection (CL-INS/VI-DVI) 6

4.3 Pump Caisson Inspections 6

4.3.1 Pump Depth Location 7

4.3.2 Pulsed Eddy Current (PEC) Wall Thickness Survey (WT-PEC) 7

4.3.3 Cygnus Wall Thickness Survey (CL-INS / WT-DIG) 10

4.3.4 Detailed Visual Inspection (CL-INS/VI-DVI) 10

5 REPORTING 11

5.1 Final Report 11

FIGURES

No Page

1 WROV PEC Inspection Area 9

2 Typical PEC Results Data Sheet Format 12

Am 01 05/05 I 43 001Page 1 of 12



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I 43 001 Am 01 05/05Page 2 of 12



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PROCEDURE I 43 001

CAISSON INSPECTION

1 INTRODUCTION

The work method shall be applied to the integrity inspection of Cuttings Chute, Drain, Firewatersuction, Seawater suction, Dump caissons and their associated fittings and attachments.

The work shall include underwater inspection consisting of General Visual Inspection, including marinegrowth and debris surveys. Additional surveys may be required, in particular for Firewater andSeawater caissons, where a known problem exists due to internal corrosion at the location of thepump due to dissimilar metals.

Above water visual inspection will also be required from the Diving/ROV Support Vessel using a digitalstill camera.

Inspection methods under the following procedures may be employed in conjunction with this

procedure.

I 15 002 - Ultrasonic Inspection -General

I 15 003 - Flooded Member Detection

I 60 004 - Cathodic Protection Monitoring – ROV

2 TASKS

2.1 Standard Tasks









2.2 Optional Tasks


WT-PEC - Pulsed Eddy Current (PEC) Wall Thickness Survey

WT-DIG - Wall Thickness (WT) Readings

CL-MGR - Marine Growth Cleaning (General)


Am 01 05/05 I 43 001Page 3 of 12



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VI-DVI- Detailed Visual Inspection

IN-FMD - Flooded Member Detection





The inspection is to be carried out by ROV, under the guidance of a CSWIP 3.3u or 3.4u InspectionController, or CSWIP 3.1u/3.2u diver, under the guidance of a CSWIP 3.4u Inspection Controller.Topside inspection is to be carried out by a CSWIP 3.3u/3.4u Inspection Controller.

3.2 Safety

WARNING: DEPENDANT ON THE RESULTS OF THE TRA, IT MAY BE REQUIRED FORPLATFORM INTAKES OR DISCHARGES TO BE ISOLATED, PRIOR TOCARRYING OUT INSPECTIONS, PARTICULARLY FOR DIVERS AND SMALLROV’S.

Suitable notice is to be given to the platform prior to any inspection work on a caisson, whereisolations are required.

ROV pilots and divers are to be aware of other caissons in the vicinity, which may be a hazard. Thesemay be required to be isolated or idled. HOWEVER, DUE TO PLATFORM CONSTRAINTS THIS MAYNOT BE POSSIBLE.

ROV

For all suction caissons, generally all suctions within 5m of the radial extents of the tether may requireto be idled and isolated, unless it can be demonstrated by a site TRA that there is no risk of the ROVblocking (or being sucked into) the caisson. It may be necessary for a suction caisson to be “madesafe” by local platform manual over-ride control of the specific fire-water pump which would permitROV access up to the actual specific caisson inlet in some instances.

Typically, precautions for approach limits to discharges may be established in field during the TRA,giving due consideration to potential threats from loss of control, discharge medium, or visibility. Limitson the length of tether deployed, and the vehicle route to the jobsite, are to be established in advance.

Divers

In most cases, where diving activities are required on a caisson, the caisson will be required to beisolated. Following a TRA, if it is established that the work location is suitably distant from the intakelocation, with diver umbilical shorter than the termination distance, then it may be that isolations arenot required.

3.3 Above Water Inspection (VI-TOP / PH-TOP)

A topside visual inspection of the caisson and its associated clamps/guides is to be carried outbetween LAT and the under deck of the platform, paying particular attention to the region from LAT to+3m. Only gross defects (C1 category) are to be reported.

Topside digital photographs are required of the above areas of the caisson from two opposite sides.

These should be taken on an opportunity basis only, with no specific vessel move made to obtainthese images, unless specifically requested in the workscope.

I 43 001 Am 01 05/05Page 4 of 12



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3.4 Subsea Inspection

3.4.1 General ROV Inspection (VD-ROV)

The ROV will carry out and fully record, a General Visual Inspection (GVI) of the full length of thecaisson including all guides, clamps and inlet grilles/flanges. The purpose of this survey is todetermine the following:

The survey is to cover, as best as practicable, 360° of the circumference of the Caisson. This wouldgenerally require 2 passes.

(1) Extent of marine growth cover. Describe marine growth as hard or soft, giving estimatedthickness and percentage cover of each.

(2) Condition of welded support connections to the primary structure.

(3) Loose or missing bolts from any of the guides, clamps or retention clamps or grille flanges.

(4) Any debris or obstructions. Where possible debris is to be removed. The Shell OffshoreRepresentative is to be consulted prior to removal.

(5) Condition of any protective coatings.

(6) Whether a grille exists at the end termination of the caisson, and what form this takes.

(7) That suction perforation holes and inlet grilles are clear of any blockages or obstructions.(Digital Still Images to be taken of any blockage).

(8) Anode wastage, give estimation of percentage wastage. (Note: There is not envisaged to beany anodes on caissons).

(9) Any areas of damage or corrosion. In the case of firewater and seawater lift caissons, payparticular attention to caisson in vicinity of internal pump, depth of which should be specified inthe workscope, for evidence of wall thinning in form of holes.

(10) Evidence of caisson movement within guides. Any areas of wear or corrosion in the vicinity ofguides or clamps.

(11) Any variance to as-built specification or UMDB's.

No cleaning is to be carried out as part of this routine inspection. However, if anomalies are notedduring the course of the GVI, marine growth removal may be carried out, sufficient to allow DVI ofanomalous finds.

Where blockage of caisson intakes are identified by any debris, or by Marine Growth (≥30%), ananomaly is to be raised. Cleaning of the grille is then required, but only with the prior approval ofthe platform, with all relevant isolations in place.

All cleaning requirements are to be agreed and authorised by the Shell Offshore Representative,acting on advice from the responsible Structural Engineer.

Digital Still Images (PH-DIG) are to be taken of any cleaned intakes, pre and post.

3.5 Cathodic Protection Monitoring (CP-PRX)

Proximity CP readings are required at the mid point of each section, on both sides, and at each guide.

Where the guide/clamp is bolted, where there appears to be the chance that components of the clampmay be isolated from the structure, a contact reading is required for each suspect component.

Am 01 05/05 I 43 001Page 5 of 12



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Where insufficient COABIS Workpack task boxes exist, relevant additional CP task boxes need to beraised to accommodate all readings taken.

The CP probe is to be hard wired into the video overlay such that the CP readings are continuouslydisplayed on the video screen during the survey. CP readings are to be included in the videocommentary.

Readings should be taken prior to any cleaning. However, should operational constraints make thispractice prohibitive, then readings can be taken post cleaning, after agreement with the Shell OffshoreRepresentative. This fact should be clearly stated within the final report.

Refer to Standard Procedure I 60 004 for taking CP measurements.

4 INSPECTION OPTIONS

When specified in the Workscope, or as directed by the Shell Offshore Representative, acting onadvice by the responsible Structural Engineer, any of the following optional activities may beundertaken.

4.1 Intake / Discharge Cleaning (CL-MGR)

Where regular inspection of a caisson is not carried out, it may be a requirement to clean intake ordischarge terminations as a matter of course during any inspection programme. Caisson terminations,including the region of any caisson intake perforations at the lower ends of the caissons, are to becleaned of the bulk of marine growth, in particular mussels.

Video (VD-ROV) and digital stills (PH-DIG) are required pre and post cleaning. The final report is todetail any areas unable to be cleaned, in particular any remaining internal marine growth, mainly withrespect to mussels. Where internal marine growth could not be removed to the anomaly criteria of

≥30% at the termination, an anomaly is only required should intake perforations not exist, or wherethey have not have been suitably cleaned.

No cleaning is to take place without prior approval of the platform, and with the necessaryisolation documentation in place.

4.2 Detailed Visual Inspection (CL-INS/VI-DVI)

As part of the five/ten year inspection plan for each structure, a programme of marine growth removaland Detailed Visual Inspection (DVI) of guides/clamps will be instigated. The clamps required forcleaning and DVI will be specified in the workscope.

For guides/clamps, pertinent areas for cleaning and DVI are the stub/structure & stub/guide welds, allbolts, the top and bottom of the caisson guide/clamp looking for evidence of movement andassociated metal loss, and the ends of any secondary clamps for evidence of movement.

Levels of cleaning will require the bulk, but not all marine growth to be removed, to allow sufficientdetail for DVI of the specified area to be inspected.

Where defects exist a drawing should be produced, and/or digital still images taken, clearly showingthe size and location of the defects.

Additional cleaning and DVI may also be required during the inspection of Firewater and Seawater Liftcaissons. This is discussed in section 4.3.4.

4.3 Pump Caisson Inspections

The following options are envisaged to be specifically used on pump caissons, Firewater and

Seawater Lift, however it may be required for some of these options to be employed on other caissontypes.

I 43 001 Am 01 05/05Page 6 of 12



0153-001

For Firewater and Seawater lift caissons, where an internal pump exists, the caissons are prone tointernal corrosion at the location of the pump. This has on a number of occasions resulted in the lossof the lower section of caisson, from the pump depth down.

For this reason a number of additional inspection tasks may be required to check for evidence ofinternal corrosion. The main method of inspection is by the use of the ‘Pulsed Eddy Current’ (PEC)

Wall Thickness (WT) tool.

Other techniques may also be employed, either as specified in the workscope, or based on PECresults. These techniques:- FMD, Cleaning, DVI, Digital WT and the use of PEC are discussed below.

4.3.1 Pump Depth Location

Prior to carrying out any wall thickness readings, the positions of the internal pump must be locatedand recorded.

Where known, the workscope should specify the pump depth. This should be an ‘as-built’ depth, i.e.relative to features of known depth on the structure, unless otherwise stated. The most obviousreference feature is a horizontal elevation. The ‘as-built’ depths of all horizontal elevations given are

based on the vertical mid point of the elevation member.

To establish the position of the pump, the difference between the given pump depth and elevationdepth, should be added or subtracted from the ROV (or diver) depth for the vertical mid-point of theelevation member.

Where tidal variations exist, or where different vehicles, or new dives are used to continue aninspection on a specific caisson, repeat checks on the offset should be taken.

4.3.1.1 Establ ishment of Pump Depth (IN-FMD)

If the pump depth is not known, or is suspect, possibly due to the installation of a new caisson; newpump; altered pump depth; or otherwise, the pump depth is to be established using the Gamma FMD

technique. This identifies the pump location due to its increased density.

Method of use of the FMD system, is as specified in procedure I 15 003 - Flooded Member Detection,Section 3.3.

Once established, the pump ‘as-built’ depth is to be calculated by measuring the offset between thelocated pump position and the vertical mid-point of the nearest horizontal elevation.

4.3.2 Pulsed Eddy Current (PEC) Wall Thickness Survey (WT-PEC)

Operational use of three possible methods of PEC deployment and inspection, is discussed instandard procedure I 15 002 – Wall Thickness and Ultrasonic Inspection. The correct utilisation of the

individual methods with respect to caissons are given below:

(1) WROV Dual PEC Probe Handling Frame. Two PEC probes mounted in a specifically designedframe for use by a dedicated WROV. Allows accurate positioning of the PEC probes once theframe is established around the full circumference of the caisson. Designed for use within largerstructures with suitable access to components, i.e. Shell Northern Structures. This system caninspect caissons with diameters of between 42”-22”.

(2) ROV PEC Probe Handling Frame. A dual PEC probe mounted in a specifically designed framefor use by a dedicated mid sized ROV. Allows accurate positioning of the PEC probe once theframe is established around the caisson, at two clock positions. The vehicle requires to berepositioned for further readings at different clock positions. Designed for use within smallerstructures with less restricted access, i.e. Shell ONEgas Structures. This system can inspect

caissons with diameters of between 22”-16”.

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(3) Single PEC Probe ROV Manipulator Held. Use of a single probe, mounted in a bracket, heldby an ROV manipulator. Designed for use where access prevents use of either of the above.Refer to 4.3.2.4.

No cleaning is intended to be carried out specifically for PEC readings. This is as the use of PECallows WT readings without the requirement for cleaning, except where extensive marine growth exists

which may prevent fitment of the Sub-Atlantic designed PEC handling frames.

Cleaning will only be required for DVI (See 4.3.4) or where digital WT readings are required (See4.3.3), which are optional.

NOTE: All PEC readings taken are subject to post processing on completion of the survey. As aresult, evidence of thinning may not be fully apparent until post processing has beencompleted. Past history has shown that in the main, variations from the initial results are notlarge. However, post processing may result in readings initially not anomalous, becominganomalous, and vice versa.

4.3.2.1 Calibration Reading

Prior to commencement of readings in the inspection area, a calibration reading is required in an areapresumed to be free from any possible thinning, away from the pump location. Such an area is morelikely to be below the pump depth, outside of the inspection area. However, several caissons arecomprised of tubular sections of two different wall thicknesses. To identify if this situation exists,reference to as-built drawings should be made. This should preferably have been specified in theworkscope, along with the nominal WT. If not specified in the workscope, operators should be awareof this possibility, should a significant sharp step change in results occur, which may not in fact be dueto internal corrosion.

As a comparison with the calibration reading, ultrasonic Cygnus WT readings may additionally berequired. This measurement is to be used as a comparison with the given nominal WT, which is arequired input for the PEC software. For the WROV frame a Cygnus probe is mounted to the top of theframe, as well as a rotary wire brush for cleaning.

4.3.2.2 WROV PEC Frame Obtained Caisson Readings (Northern)

The PEC inspection area is to be 1.5m above and below the pump depth, unless stated otherwise inthe workscope, or access does not allow.

Reading locations are to be reported relative to the pump depth (taken to be zero), where positive isabove the datum (Less deep, i.e. less –ve), and negative is below (Deeper, i.e. more –ve).

Over the inspection area, 1.5m above and below the pump depth (datum zero), PEC readings arerequired at datum zero, and every 100mm above and below datum for 300mm at the 12 cardinal clockpositions; then every 250mm from the 500mm position, at the four cardinal clock positions.

The method of use of the PEC system requires 1 or 2 further single bands of readings to be taken ateach clock position, above and below datum, to act as reference readings. (See Fig.1.).

I 43 001 Am 01 05/05Page 8 of 12



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+300mm

+1500m

-300mm

-1500mm

m

Summary of PEC Locations -Not To Scale

Datum

Figure 1 WROV PEC Inspection Area

Should restricted access prevent clear access for the PEC frame, i.e. pump depth near to elevationmembers, consult the Shell Offshore Representative for alternative inspection locations, or method.Thought should be given to use of alternative PEC tools, ROV Frame or Manipulator held, oralternative locations above or below the restriction.

Where evidence of thinning is found i.e. >25% loss, additional WT readings are to be taken at clockpositions adjacent to the thinned area in 100mm vertical steps, until WT readings obtained are back tonominal WT. Inform the Shell Offshore Representative, prior to taking any readings, to confirm extentof additional readings required.

Note: Any wall thinning >50% is to be reported as a C2 anomaly.

A C1 anomaly relates only to visible cracks or holes.

Where area of thinning appear to extend outside the originally specified inspection area inspectionmay continue outside this area until the above acceptable WT levels have been attained, asoperational constraints allow, after consultation with the Shell Offshore Representative, acting onadvice from the responsible Structural Engineer.

4.3.2.3 ROV PEC Frame Obtained Caisson Readings (ONEgas / Northern)

The survey is initially to be restricted to four clock positions around the circumference of the caisson,as access allows, equally spaced if possible. Readings are to be taken in 100mm incrementsvertically.

The area of inspection is to be conducted as specified in the workscope.

Where evidence of thinning is found i.e. >25% loss, additional WT readings are to be taken at clockpositions adjacent to the thinned area in 100mm vertical steps, until WT readings obtained are back tonominal WT. Inform the Shell Offshore Representative, prior to taking any readings, to confirm extentof additional readings required.

Note: Any wall thinning >50% is to be reported as a C2 anomaly.

A C1 anomaly relates only to visible cracks or holes.

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4.3.2.4 Single PEC Probe ROV Manipulator Held

Where access is restricted, or the diameter of the caisson prevents use of the PEC frame, a singlePEC probe is to be used, held in the ROV manipulator. Readings are to be taken, as best aspracticable, in the workscope specified locations.

This method of use is not as accurate in its positioning of the PEC probe, due to vehicle movement,and general problems regarding the correct position of the probe. However, best endeavours shouldbe made to accurately record the locations of readings taken. Use of a known depth reference is to beused (see section 4.3.1 above).

Two probe types exist, providing a broad and narrow inspection beam area. The narrow beam probeshould be used on tubulars of small diameter.

A mounting frame has been used in the past in the form of a ‘V’, which helps to centralise and stabilisethe PEC probe on the inspection area. This mounting frame must not be made from magnetic ferrousmetal, or aluminium. An acceptable material is Non-magnetic Stainless Steel, or plastic.

Where anomalous readings are found, increase the survey readings as per best as practicable, as perthe anomaly survey requirements in 4.3.2.2 above, dependant on the originally specified surveyextents.

4.3.3 Cygnus Wall Thickness Survey (CL-INS / WT-DIG)

Cygnus WT readings may be required to be taken by ROV or diver, over areas either specified in theworkscope, or by the Shell Offshore Representative, acting on advice from the responsible StructuralEngineer based on earlier survey results.

For diver inspection, where multiple readings are to be taken over an extensive area, a grid patternshould be marked on the caisson, the depth of which should be recorded relative to a known ‘as-built’reference point.

For both ROV or diver survey, a drawing and/or table of the results should accompany the final report.

The method of cleaning and survey to be adopted is as specified in standard procedure I 15 002,section 3.3.

4.3.4 Detailed Visual Inspection (CL-INS/VI-DVI)

Unless specified in the workscope, cleaning and DVI will only be required if the results of the Pulsed

Eddy Current (PEC) wall thickness survey (see 4.3.2) indicate a wall thickness loss ≥50%, as specifiedin the anomaly criteria. This inspection is intended to be carried out by ROV, utilising zoom camerasfor detail, to look for evidence of through wall defects and/or corrosion. The extent of the area to becleaned and inspected is to be advised by the Shell Offshore Representative, based on the PEC

results.

Diver inspection may be required to further investigate defects identified by ROV.

Cleaning will require the bulk, but not all, marine growth to be removed to allow sufficient detail for DVIof the area specified to be inspected.

Where perforations due to thinning are visible a drawing should be produced, and/or digital still imagestaken (PH-DIG), clearly showing the size and location of the defects.

If inspected by ROV, estimated dimensions are required as a minimum, but preferably a moreaccurate method of report should be utilised, i.e. a manipulator held scale.

If inspected by Diver, a suitable grid should be used to plot the defects.

I 43 001 Am 01 05/05Page 10 of 12



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5 REPORTING

5.1 Final Report


This should include - lack or presence of a grille and type at termination points, any blockage of thegrille and any resultant cleaning activities. Where PEC readings, DVI or cleaning has taken place, alldepths given should be ‘as-built’ depths, converted from actual ROV/Diver depths, which is to beclearly stated. A general statement concerning results should be made, i.e. max/min of CP, and/or WTreadings. If CP readings are taken post cleaning, this should be stated. Any inspection data or PECfiles are to be referenced.

Where visible perforations exist due to wall thinning, a drawing and/or digital still images are to beincluded. Hard copies of all digital still images are to be included with the report, saved and correctlylinked within the COABIS database.

Where significant WT readings have been taken, that cannot be suitably represented within the

COABIS results, or as a table in the Job Completion Report, a drawing should be produced.

A hard copy of all PEC data results, and any associated Cygnus WT readings, are to be included inthe Results/Appendix section of the final report. The PEC results are to be presented in the formatshown in Fig.2 below. This format is converted from the processed PEC data files, which is in an excelformat. All PEC data files are to be saved within the COABIS database and suitably linked.

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I 43 001 Am 01 05/05Page 12 of 12

PEC Offline Wall Thickness plot A + B (15% Smoothed + FFT filtered)

Location Nelson Date Saturday,12 Jun 2004

Job nr. NELSN/2004/C101 Filename RD16404C

Component nr. 43-007 Description Seawater caisson

Datum point -10m Recorded by John Downes / John Knight

Diameter 39 [inch] WT_nom 15 [mm]Grid vert. spacing longitudinal Vert.incr. 100 [mm]

Grid. hor. clockposit circumferential Hor. incr. 1 [hr]

ert ca

Position Horizontal Position

1 2 3 4 5 6 7 8 9 10 11 12

+1500 14.6 14.4 14.9 14.7 14.6 15.2 15.3 15.3 14.5 13.9 13.6 19.7

+1400 13.3 13.5 14.0 13.9 14.2 14.8 14.4 14.7 14.0 11.7 12.3 19.7

+1300 11.1 13.0 13.1 13.9 13.9 13.8 13.8 13.6 13.3 11.6 11.2 18.7

+1200 11.0 12.1 11.6 12.3 13.4 13.2 13.7 12.4 11.9 10.8 10.3 18.1

+1100 9.9 11.6 10.9 11.5 12.9 13.3 13.6 12.5 12.0 11.8 9.9 17.3

+1000 9.4 12.6 11.8 13.7 14.0 13.6 13.8 12.2 12.5 11.7 10.7 17.6

+900 11.9 13.0 12.2 13.3 14.0 14.1 14.0 12.3 12.5 12.5 10.9 16.8

+800 11.9 12.8 11.3 13.5 13.9 13.9 13.7 12.5 13.4 12.3 12.1 18.1+700 12.4 15.2 15.2 15.0 13.4 11.7 15.6 15.8 15.9 15.6 14.9 14.3

+600 13.2 15.4 15.3 14.5 15.7 15.6 16.1 15.0

+500 14.5 15.7 15.4 15.6 16.1 14.9

+400 15.5 15.2 15.5 14.8

+300 15.5 15.5 15.6 16.0 16.3 15.4 15.2 15.7 15.5 15.7 15.5 15.6

+200 15.5 15.4 15.6 16.1 16.0 15.9 15.6 15.7 15.6 15.8 15.7 14.8

+100 15.7 15.2 15.9 16.1 15.9 16.1 16.0 15.8 15.4 15.6 15.9 15.5

0 15.5 15.6 15.5 15.9 16.0 16.1 15.5 15.9 15.3 15.1 15.8 15.8

-100 15.6 15.8 15.9 15.9 16.3 16.1 16.1 16.3 16.1 16.0 15.5 18.1

-200 15.7 15.8 15.6 15.7 16.2 16.2 16.2 16.3 15.9 15.8 14.9 18.1

-300 15.6 15.3 15.5 15.6 15.8 16.1 16.5 15.0 14.9 15.2 14.5 18.2

-400 16.2 16.2 15.1 15.6

-500 15.4 16.6 15.1 15.0

-600 15.4 17.4 15.3 15.0

-700 15.0 17.1 15.2 14.5

-800 14.6 16.9 15.0 14.9

-900 14.8 16.6 15.1 15.0

-1000 15.2 16.2 15.1 14.9

-1100 15.0 15.2 15.5 14.8

-1200 15.0 14.7 14.7 14.6

-1300 15.0 15.0 16.0 14.0 13.7 13.6

-1400 15.0 14.5 14.8 15.4 14.3 14.0 13.3 14.5

-1500 14.6 14.9 14.7 14.7 14.7 15.1 14.9 14.8 14.8 14.6 12.9 14.6

-1600 14.5 14.3

10%+

(+/-) 10%

10% - 15%

15% - 20%

20% - 25%

25% - 30%

30% - 35%

35% - 40%

>40%

ref_value 15

margin % 10

band_min 13.5

band_ma 16.5

perc_incr 5

Figure 2 Typical PEC Results Data Sheet Format

(Produced from PEC Excel Spreadsheet Both_offl2 Corrected)



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PROCEDURE I 49 057

TALON JOINT INSPECTION

CONTENTS

Para Page

1 INTRODUCTION 3

2 TASKS 3

2.1 ROV Survey 3

2.2 Full Survey 3



3.2 ROV Survey (VD-ROV) 4

3.3 Full Survey (Including Options) 4

3.3.1 Preparation 4

3.3.2

Initial ROV Inspection (VD-ROV) 5

3.3.3 Rigging (CN-RIG) 5

3.3.4 Talon Inspection with Armawrap 5

3.3.5 Deploy cleaning equipment to site and remove marine growth as fol lows (CL-INS): 5

3.3.6 Inspection of Talon with Scalloped Sleeve 7

3.3.7 Inhibi tor Gel Injection (Optional) 7

3.3.8 Final Inspection (VD-ROV) 8

4 REPORTING 8

4.1 Final Report 8

FIGURES

No Page

1 Installation of Digital Micro OHMS Unit on Talon Joint 10

2 Probe Head Posit ioned on Talon Join t 11

3 Armawrap Protective Sleeve Installation Tool 12

4 Operation and Armawrap Protective Sleeve Installation Tool 13

5 Armawrap Protective Sleeve Attachment Details 14

6 Rotation Monitor Installation Talon Joint 15




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PROCEDURE I 49 057

TALON JOINT INSPECTION

1 INTRODUCTION

The work method is to be applied to the maintenance and inspection of Talon Joints. The work willinclude marine growth removal, electrical resistance survey, installation of Armawrap and rotationindicators, and injection of inhibitor gel and video survey.

Eddy Current Inspection (EMI) using ACFM, as per Procedure I 15 001, may be required to beemployed in conjunction with this procedure.

2 TASKS

2.1 ROV Survey

The following work tasks are required for an ROV only survey.


VI-ROV - General Visual Inspection

MG-GEN - Marine Growth Check



CH-FXW - Check Armawrap (Flexi-wrap)

2.2 Full Survey

The following work tasks are required for a full Talon Joint survey, including various options.



CN-RIG - Rig/De-rig Equipment


CN-FXW - Remove/Apply Flexi-wrap

IN-ERS - Talon ERS Survey

VD-DIV - General Diver Video


CN-STD - Standard Construction Task (Inject Inhibitor Gel)

VI-CVI - Close Visual Inspection (As per I 15 001)

IN-ECI - Eddy Current Inspection (As per I 15 001)




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The inspection is to be carried out by ROV, under the guidance of a CSWIP 3.3u or 3.4u InspectionController. Diver intervention works may be carried out by any grade of diver. However, inspectionorientated work is to be carried out by CSWIP 3.1u, CSWIP 3.2u diver, as directed by a CSWIP3.3u/3.4u Inspection Controller.

3.2 ROV Survey (VD-ROV)

The ROV will carry out, and fully video record, a visual survey of the Talon Joint. The following actionsare required:

(1) Carry out an initial survey (VI-ROV) to correctly identify the joint in accordance with the givenworkscope location and UMDB drawings. Confirm depth of joint referenced against a known

elevation. Cleaning may be required to correctly identify the joint.

(2) Extent of marine growth (MG-GEN).

(3) Any debris or obstructions in work area.

(4) Clean (CL-INS) the Talon Joint.

(a) Where no Armawrap is present clean localised to the joint, to a standard to allow adetailed visual inspection to be carried out.

(b) Where Armawrap is present, clean sufficiently to confirm the integrity of the Armawrapseam and securing bolts. Clean above and below the Armawrap sufficient to checkalignment of the rotation indicators.

(5) Complete a detailed visual inspection (VI-DVI) of each Talon joint. The format of the survey isdependant on whether an Armawrap protection sleeve is present:

(a) If no Armawrap is present - check for any damage, corrosion staining, movement orseparation of the joint. Check the status of the grease injection port to the top of the joint.

(b) If Armawrap is present - Confirm the integrity of the Armawrap, including bolts.

(c) Identify the presence of rotation indicators, if any, looking for evidence of rotation.Rotation indicators should be present where Armawrap is present, and should be in line

with the seam of the Armawrap. (See anomaly criteria, point 2.2.16).

CP readings are not required, except as part of a relevant anomaly investigation.

3.3 Full Survey (Including Options)

3.3.1 Preparation

Before work can commence on the Talon Joints carry out the following, where applicable.

(1) Marshal all necessary materials for this work on the vessel's deck.

(2) Check off materials list.




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(3) Make available inhibitor gel, in the event it is required from the inspection results, or specified inthe workscope.

(4) Pressure up digital micro OHM unit and test.

3.3.2 Init ial ROV Inspection (VD-ROV)

The ROV will carry out, and fully video record, an initial visual survey of the Talon Joint. The purposeof the survey is to record the following:

(1) An initial survey (VI-ROV) to correctly identify the joint in accordance with the given workscopelocation and UMDB drawings. Confirm depth of joint referenced against a known elevation.Cleaning may be required to correctly identify the joint.

(2) Position of any rotation indicators, if any, looking for evidence of rotation.

(3) Is Armawrap protective sleeve installed.

(4) Extent of marine growth to be removed.


If operational constraints allow, cleaning of the joint can be carried out by the ROV, as per therequirements below.

3.3.3 Rigging (CN-RIG)

Diver to establish downline to worksite. Use of a diver work stage at site may be considered, howeverrecent inspections have not found it necessary (CN-RIG).

Where rotational indicators are installed, the diver is to note and report any displacement prior toremoval. If displacement is seen, record on video prior to removal. (See anomaly criteria, point 2.2.16).

3.3.4 Talon Inspection with Armawrap

On Talon Joints where Armawrap protective sleeving has been installed, it will require removal to allowelectrical resistance checks to be carried out (CN-FXW).

3.3.5 Deploy cleaning equipment to site and remove marine growth as fol lows (CL-INS):

(1) 400/500mm above the Armawrap to allow it to pull up clear of the talon joint.

(2) To remove Armawrap protective sleeve attach a span set above the Talon Joint as a riggingpoint, slacken off the Armawrap protective sleeve securing bolt sufficiently to allow sleeve to be

pulled up clear of the Talon Joint and hang off on the span set.

(3) With the Armawrap removed, clean the Talon Joint to allow for DVI and to allow the ‘Talon Tool’probe assembly to make good contact with steel surface.

(4) At the four cardinal clock positions, a vertical strip area 150mm (High) x 50mm (wide) across the joint and both rebates, must be cleaned to bright shiny metal, to allow contact of the SERIS II‘Talon Tool’ head probes and obtain resistance readings.

3.3.5.1 On completion of cleaning, electrical resistance checks using the Talon Tool are required (IN-ERS). Assemble the probe head clamp around conductor and position the probe assembly as shown in Figs1 and 2.




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NOTE: When positioning the tool initially, it is essential that the four probe heads are fully retracted.Only when the tool is secure in the desired position should the probes be brought forwardinto contact position by operating the 'cam' lever.

(1) Activate diver held electrical resistance tool, obtain and record a minimum of three authenticsignals on monitor, calculate and record the mean value. Adjust equipment and move probe to

repeat monitoring exercise at each cardinal clock position. Add the four mean values, calculateand record the overall mean.

(2) Inform the Shell Offshore Representative of the readings obtained. Raise anomaly reports ifnecessary. (See anomaly criteria, point 2.2.16).

(3) Complete a detailed visual inspection (VI-DVI), recorded on video, of the Talon joint. Check forany damage, corrosion staining, movement or separation of the joint. Check the status of thegrease injection port to the top of the joint.


If required by the workscope, inject Inhibitor Gel, to the injector port found to the top of the joint, as persection 3.3.7.

3.3.5.2 Re-install Armawrap protective sleeve as follows (CN-FXW):

(1) Fit the Armawrap sleeve around the conductor and tie off so that it is positioned centrally acrossthe joint, ensuring that the injection nipple is covered by the soft part of the wrap.

(2) Using the Armawrap sleeve installation tool Figs. 3 and 4 in the central bolthole draw the wrapflanges together sufficiently to allow installation of two 175mm bolts, which are then used to fullyclose the flange faces. Finally replace the sleeve installation tool with a 175mm bolt and tighten,approx 70-80 ft lbs, fit double nylon lock nuts to all bolts. Replacement nuts and bolts should besupplied. See Fig 5.

3.3.5.3 On completion of all works rotation indicators are to be installed, ensuring correct alignment with the Armawrap flange. See Fig 6.

Talon Inspection without Armawrap

Where Talon Joint has not been previously inspected and/or is not protected by an Armawrap. Deploycleaning equipment to site and remove marine growth as follows (CL-INS):

(1) Clean the conductor 400mm either side of the Talon joint removing all marine growth and loosecoating.

(2) Clean Talon Joint at cardinal clock positions over an area 150mm (High) x 50mm (wide) to allow

probe assembly to make good contact with steel surface.

3.3.5.4 On completion of cleaning, electrical resistance checks using the Talon Tool are required (IN-ERS). Assemble the probe head clamp around conductor and position the probe assembly as shown in Figs1 and 2.

NOTE: When positioning the tool initially, it is essential that the four probe heads are fully retracted.Only when the tool is secure in the desired position should the probes be brought forwardinto contact position by operating the 'cam' lever.

Activate diver held electrical resistance tool, obtain and record a minimum of three authentic signalson monitor, calculate and record the mean value. Adjust equipment and move probe to repeatmonitoring exercise at each cardinal clock position. Add the four mean values, calculate and record

the overall mean.




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Inform the Shell Offshore Representative of the readings obtained. Raise anomaly reports ifnecessary.

Complete a detailed visual inspection (VI-DVI), recorded on video, of the Talon joint. Check for anydamage, corrosion staining, movement or separation of the joint. Check the status of the greaseinjection port to the top of the joint.


If required by the workscope, inject Inhibitor Gel, to the injector port found to the top of the joint, as persection 3.3.7.

3.3.5.5 Install Armawrap protective sleeve as follows (CN-FXW):

(1) Fit the Armawrap sleeve around the conductor and tie off so that it is positioned centrally acrossthe joint, ensuring that the injection nipple is covered by the soft part of the wrap.

(2) Using the Armawrap sleeve installation tool, Figs 3 and 4, in the central bolthole draw the wrapflanges together sufficiently to allow installation of two 175mm bolts, which are then used to fullyclose the flange faces. Finally replace the sleeve installation tool with a 175mm bolt and tighten,approx 70-80 ft lbs, fit double nylon lock nuts to all bolts. See Fig 5.

3.3.5.6 On completion of all works, rotation indicators are to be installed, ensuring correct alignment with the Armawrap flange. See Fig 6.

3.3.6 Inspection of Talon with Scalloped Sleeve

3.3.6.1 Where Talon Joint has a scallop sleeve welded across the Talon Joint, cleaning to SA 2.5 will benecessary at the following locations:

(1) Upper 'peak' lobe at 12 o'clock position.

(2) Upper 'trough' lobe at 3 o'clock position.

(3) Lower 'peak' lobe at 9 o'clock position.

(4) Lower 'trough' lobe at 6 o'clock position.

(5) Full length of one of the vertical welds.

3.3.6.2 Talon Joints with welded scalloped sleeves are to be subjected to close visual inspection (VI-CVI), ACFM (IN-ECI) inspection and video as per Procedure I 15 001.

3.3.7 Inhibi tor Gel Injection (Optional)

3.3.7.1 The joint should then be injected with inhibitor gel and Armawrap installed as follows (CN-FXW):

(1) Ensure Talon Joint and Conductor 400mm either side of Talon Joint is clean and free of marinegrowth cover.

(2) Visually inspect Talon Joint, record any damage or observed movement, and photograph asnecessary.

(3) Remove the 1/2-inch NPT plug by backing out using a 1/4-inch Allen key. Ensure the Allenprofile in the plug is cleaned out and the key fully home before attempting to remove the plug.

In the event that the Allen head profile is deformed. Confirm with the responsible Technical Authority whether to proceed with injection operations. If confirmed, the plug is to be removedas follows:




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The plug must be drilled (1/8 inch at first) to 1/4 inch-5/16 inch and an extractor used to removethe plug. It is possible to detect when the drill has penetrated the joint interface, as an area ofno resistance will be encountered immediately after drilling through plug. Use the largest sizeextractor suitable for 5/16-inch hole as considerable torque may be required, and removal of asheared extractor is a laborious process.

(4) Surface preparation for inhibitor gel injection - prior to gel injection the two components of thegel must be mixed. It is vital that the container of Activator (Corexit 3328) is thoroughly agitatedfor 5 minutes prior to adding it to the inhibitor (Corexit 3327). The two components must then bethoroughly agitated for a further 5 minutes (add the full contents of the agitated 5 litre containerto the 25 litre container).

Gelling should start to take place in 1-2 hours; the mixture should not be used unless gellinghas started.

Transfer the gel to hydraulic pumps using 140cc syringes provided, when pump reservoir is fullallow time for any air bubbles to settle out and check pump displacement per stroke (Usesyringe as measure).

NOTES: (1) An alternative gel may be supplied, if so, full instructions for its use will beincluded in the workscope.

(2) Hydraulic pump may be used both above and below water as the need arises.

(5) Gel to be injected to a maximum pressure of 2,500psi or until 500cc (by counting pump strokes)has been injected. The latter instance would indicate that defective '0' seals are allowing the gelto pass into the annulus. Should this occur inform the Shell Offshore Representative. Also in theevent of leakage of the gel being observed at the visible external Joint, inform the ShellOffshore Representative who, after consultation with the responsible Structural Engineer, willdecide on the course of action to be taken.

NOTE: During pumping the pump should be slung vertically with the pump head down to

avoid air being forced into the joint.

On completion of inhibitor gel injection, vent any pressure via the downstream valve (not thevalve on the pump head) otherwise there is a risk of corrosion products entering the pump anddamaging the seals.

(6) Disconnect hydraulic pump and fit a new 1/2-inch NPT plug.

NOTE: A surface GKN type hydraulic pump has been used to good effect for gel injection, inthis case ensure the reservoir and umbilical are purged with inhibitor gel, and observethe same pressure/volume constraints as (5) above.

3.3.8 Final Inspection (VD-ROV)

On completion of all diver works the ROV will carry out, and full video record, a general visual surveyof each Talon Joint, paying particular attention to the final placement of the Armawrap protectivesleeve and rotation indicators.

4 REPORTING

4.1 Final Report


This is to confirm the presence of alignment indicators; whether any misalignment was noted; thepresence of Armawrap; full results of the Electrical Resistance checks; whether inhibitor gel was used;




0153-001

confirming re-instatement of Armawrap and alignment indicators. Reference any ACFM files andaccompanying data sheets.

Any ACFM files created are to be saved and correctly linked within COABIS.

Any other specific inspection tasks requested in the workscope are to be commented upon. If the task

could not be completed, a statement is required stating reasons.




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SPANSET STRAP

ASSEMBLY

HAND HELD PROBE

ASSEMBLY

SPANSET OMITTED

POWER LEADALON CONNECTOR

DIGITAL MICRO

OHM UNIT ( DMO )

T

Figure 1 Installation of Digital Micro OHMS Unit on Talon Joint

I 49 057 Re-issue 04/05Page 10 of 15





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5 0 0 m m . x 2 0 m m

D I A . T U B I N G

M 1 2 W A S H E R

M 1 2 W A S H E R S

M 1 2 L O C K N U T

M 1 2 N U T A N D W A S H E R

W E L D E D T O G E T H E R

3 0 0 m m . B A R , N U T A N D W A S H E R

W E L D

E D T O G E T H E R

1 0 0 m m . B A R

1 0 0 0 m m . M 1 2 T H

R E A D E D B A R

Figure 3 Armawrap Protective Sleeve Installation Tool

I 49 057 Re-issue 04/05Page 12 of 15



0153-001

A R M A W R A P

I N N E R S E A L F L A P

B O L T H O L E S

C L O S U R E S E A L S

A R M A W R A P

Figure 4 Operation and Armawrap Protective Sleeve Installation Tool

Re-issue 04/05 I 49 057Page 13 of 15



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K E Y :

C O N D U

C T O R P I P E W A L L

A N T I - F O U L A N T C O A T E D P O L Y E S T E R F E L T

P O L Y P

R O P E N E S E A L

N E O P R

E N E S E A L S

G R P P U L T R U S I O N

N E O P R

E N E / N Y L O N

N E O P R

E N E

P R O T E C T I V E S L E E V E

C L O S U R E S Y S T E M

M O N E L S E C U R I N G N U T

( T Y P . B O T H E N D S )

N Y L O N L O C K I N G R I N

G

( T Y P . B O T H E N D S )

S L E E V E O V E R L A P

Figure 5 Armawrap Protective Sleeve Attachment Details

I 49 057 Re-issue 04/05Page 14 of 15



0153-001

Re I 49 057Page 15 of 15

750mm

ROTATION MONITOR

ALIGN MARKER WITH

ARMAWRAP FLANGE

CONDUCTOR

SPANSET STRAP

ARMAWRAP

PROTECTIVESLEEVE

NOTE: Rotational monitors are to be installed at all Talon joints

irrespective of Armawrap protective sleeve being fitted

Figure 6 Rotation Monitor Installation Talon Joint

-issue 04/05



0153-001

PROCEDURE I 60 004

CATHODIC PROTECTION MONITORING

CONTENTS

Para Page

1 INTRODUCTION 3

2 TASK OPTIONS 3



3.2 CP Calibrations 3

3.2.1 Calomel Cell Calibration 4

3.2.2 Pre, Post and Mid Dive Calibrations 4

3.3 Proximity CP Readings - (CP-PRX) 4

3.3.1 Remote Reference CP System 5

3.3.2

Direct Earthing Cable Method 6

3.4 Contact CP Readings – (CP-CON) 6

3.4.1 ROV Contact CP Readings 6

3.4.2 Diver Contact CP Readings 7

4 OPTIONS 7

4.1 Anode Inspection 7

4.1.1 Anode CP Survey – (CP-AN) 7

4.1.2 Detailed Anode Inspection – (VI-AWD) 7

4.2 Cathod ic Protection Potential Survey – Zonal (CP-ZON) 8

4.2.1 CP Survey - Zonal 8

4.3 Cathod ic Protection Potential Survey – Nodal (CP-NOD) 9

4.3.1 CP Survey - Nodal 9

4.4

Anode Direct Current Measurement – (CP-GSC/IN-GSC) 9 4.4.1 Inspection Qualifications 9

4.4.2 Anode CP Survey – (CP-GSC) 9

4.4.3 Anode Measurement – (IN-GSC) 10

4.4.4 System Calibration 11

4.5 Final Report 11

FIGURES

No Page

1 Example of Format for Anode Inspection 12

2 Typical Structural Cathodic Potential Reference Point 13

3

Typical Anode Volumetric Measurements 13

4 Example of Format for Zonal CP Survey 14

5 Example of Format for Nodal CP Survey 14

6 Example of Format for Anode Direct Current Measurement Monitor ing- Blank 15

7 Example of Format for Anode Direct Current Measurement Monitor ing-Completed 15




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0153-001

PROCEDURE I 60 004

CATHODIC PROTECTION MONITORING

1 INTRODUCTION

The work method is to be applied for the inspection monitoring of structural Cathodic Protection (CP)systems. The work will include anode inspection, Cathodic Potential readings and anode directcurrent measurement monitoring.

2 TASK OPTIONS


CP-CON - Contact Measurements



VI-AWD - Detailed Anode Check

CP-AN - Detailed Anode CP Survey


CP-ZON - Zonal CP Survey

CP-NOD - Nodal CP Survey

CP-GSC - G-Scan CP Survey

IN-GSC - G-Scan DC Measurement





The inspection is to be carried out by ROV, under the guidance of a CSWIP 3.3u or 3.4u Inspection

Controller, or CSWIP 3.1u/3.2u diver, under the guidance of a CSWIP 3.4u Inspection Controller.

3.2 CP Calibrations

At the start of an inspection campaign all CP units, including all spare probes, are to be calibratedusing Calomel Cells and results logged. Subsequent calibrations using Calomel cells are to be carriedout or at suitable intervals over a prolonged inspection campaign, as directed by the Shell OffshoreRepresentative, or when a probe is suspect.

Subsequent calibrations pre, post and during dives (for diver inspections) are to be carried out againsta zinc block.




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3.2.1 Calomel Cell Calibration

Calomel cells and CP probes should be soaked in fresh salt water, for up to 2 hours prior todeployment, in a non-metallic container. The container is to be free from zinc blocks or other metallicdebris.

Three Calomel cells are required, each cell to be labelled 1, 2, 3 or A, B, C. Compare each calomelcell against each other using a multimeter, i.e. 1 v 2, 1 v 3 and 2 v 3. Acceptable limits are to be -4mV,+/-5mV. Select the best cell from these comparisons, closest to 0mV.

The selected Calomel cell should then be read against a zinc block, and is to be within the range1000mV to -1050mV. The selected Calomel cell number, calibration reading against both the calomelcell and zinc block are to be recorded within COABIS.

Calibrate the required CP probes against the selected Calomel cell, with the Calomel cell connected tothe -ve terminal of the multimeter. Acceptable readings should again be within –4mV, +/-5mV. Onceproven the probe is to then be calibrated against a zinc block, and should read the same as theCalomel cell zinc block reading, plus the difference between probe and Calomel Cell.

Note, when using Bathycorrometer type Calomel cells which screw directly onto the Bathycorrometer,the polarity of the acceptable readings is reversed. This is as the cell connects to the +ve terminal ofthe Bathycorrometer and should therefore read +4mV, +/-5mV.

Note: Calomel Cells are only valid for 2 years from their production date.

3.2.2 Pre, Post and Mid Dive Calibrations

CP probes should be soaked in fresh salt water, for up to 2 hours prior to deployment, in a non-metallic container. The container is to be free from zinc blocks or other metallic debris.

For ROV inspection, all systems are to be calibrated pre and post dive against a zinc block. In tidalconditions, the ROV is to be recovered once operations have been stopped due to current, to ensure

post and pre-dive checks are carried out.

For Diver hand held Roxby Bathycorrometers, all units are to be calibrated pre and post dive, and priorto use subsea against a zinc block.

Acceptable calibrations against the zinc block are between -1000mV and -1050mV. All calibrationresults are to be recorded within the COABIS database.

Inspection procedure and calibration of equipment is to conform to the following standard:

Det Norske Veritas - Recommended Practice, Monitoring of Cathodic Protection Systems.

RP B403, March 1987. In particular Sections 3 and 4, Calibration and Equipment Checks

3.3 Proximi ty CP Readings - (CP-PRX)

NOTE: Cathodic Potential Data, where necessary, is to be obtained prior to any marine growthremoval or any site cleaning operations.

Presently there are two methods employed in the taking of Proximity CP readings. The preferredoption is the use of a Remote Reference CP system. The other option is the traditional Direct EarthingCable method. The benefits of the Remote Reference CP system, is that it allows readings without theneed for permanent direct contact to the facility being inspected. The use of these methods isdiscussed below.

Both systems are to be used by ROV, but can be used by Diver.




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3.3.1 Remote Reference CP System

There are a number of these non permanent contact proximity systems available, provided by thefollowing companies:

• Pro-Sub Services Ltd.

• Subspection Ltd.

• IIcorr

The Pro-Sub Services system allows operation of the unit by any 3.3u/3.4u Inspection Controller. Theother systems require specialised operators. For information on the use of these systems, refer to therelevant manual, or as instructed by the system operator.

These systems use the standard philosophy of Cathodic Potential measurement but allow the takingof proximity readings without the need for a permanent contact to the facility being inspected. This ispossible by means of taking an initial contact CP ‘stab’ reading on the subject to be inspected, or toanother component that is directly earthed to the inspection subject, to which the CP system iscalibrated. All subsequent proximity readings are taken using the same probe for the contactcalibration reading in close proximity to the inspection subject, using a standard Silver/Silver Chloride(Ag/AgCl) CP probe. These systems employ a second ‘reference’ probe, which is suspended in thewater away from the inspected facility.

The benefits of this method are that for the inspection of platforms, no assistance is required from theplatform in connecting an earthing cable. For the inspection of risers, there is no concern as towhether the risers are isolated from the remainder of the platform, and no need to obtain direct contactof the earthing cable to the riser. For subsea facilities, the proximity CP method can be employed, asopposed to direct contact. In addition the probe can also be used for contact readings during the samesurvey.

Due to the method of calibrating the system for proximity readings, subsequent CP readings can onlybe taken on components earthed to the component used for the calibration reading. Therefore wheninspecting a caisson, CP readings can be taken on the caisson and also on any associated guideswithout need for additional calibration readings. However, for risers where it is assumed, unlessotherwise known, that guides/clamps are isolated from the riser by liners, a separate set of CPreadings are required for the riser and for clamps/guides. In this latter case, and in other similarsituations, where additional individual readings are required, contact readings would be acceptable, toremove the need to re-calibrate after each set of additional readings.

When using these systems, contact calibration readings are to be taken for each new dive, for eachnew component type, and/or each new Component Task Sheet (CTS) worked on. Therefore newcontact calibration readings are not required for each individual member to be inspected on astructure, but would be needed for a new structural elevation, caisson, riser, or any other electricallyisolated component.

3.3.1.1 General CP Survey

The locations for readings are specified in the relevant standard procedure, or as specified in theworkscope.

During a survey the distance that the CP probe is from the component is dictated by the camera view.Best endeavours should be made to keep the probe as close as possible, but out of the view of the

camera as best as possible. Where a specific CP reading is requested, the CP probe should bepresented to the component, but there is no need for contact.




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3.3.1.2 Riser and Other Subsea Facil ity Pressurised Pipework CP Survey

For riser and other pressurised pipework (i.e. igloo/wellhead pipework and pipelines) inspections,direct contact CP readings are not to be carried out on the pipework itself, unless specified in theworkscope or otherwise directed by the Shell Offshore Representative, acting on advice from theresponsible Structural Engineer. A large proportion of risers and pressurised pipework are coated, and

as such do not allow direct contact readings.

To obtain a contact reading for calibration purposes either a flange, anode or other earthedappurtenance is to be used.

Due to the nature of the remote reference CP system, contact readings are required to be taken on ariser clamp/guide, or other appurtenance electrically isolated from the pipework, either as part of theworkscope or to investigate an anomaly. Where a clamp is comprised of a number of parts, i.e. innerand outer shell, contact CP readings are to be taken on each part.

Dependant on the system used, on completion of these contact readings it should be possible tocontinue the riser survey, without need to re-calibrate to continue the proximity survey. If not,re-calibrate using the nearest suitable location.

3.3.2 Direct Earthing Cable Method

This method of survey can only be used on manned platforms.

This method requires an earthing cable to be passed to the platform to be inspected. Assistance isrequired of the platform to connect the earthing cable to bare steelwork, not stainless steel, i.e. nothandrails. Where it is known that the platform risers are electrically isolated from the remainder of theplatform, for the proximity method to work, the earthing cable requires to be connected directly to theriser to be inspected. Connection may require cleaning of the platform connection point using a wirebrush.

Suitable notification is required to be given to the platform, prior to vessel arrival at the

platform. Due to platform manning levels, it may only be possible to make such connectionsduring day shift.

Two earthing cables are required to be passed to the platform, to check the continuity of theconnection. To allow connection of the earthing cables to the platform, a ‘G-Clamp’ and/or CrocodileClip is required to be connected to the end of each cable. Prior to connection to the ROV interfacepanel, the continuity between the two cables is to be checked. +/-5mV is the required tolerance.

3.4 Contact CP Readings – (CP-CON)

NOTE: Cathodic Potential Data, where necessary, is to be obtained prior to any marine growthremoval or any site cleaning operations.

Contact CP readings may be taken by both ROV and diver.

As discussed above, contact CP readings should not be taken on the pressurised pipework (i.e. risers,igloo/wellhead pipework and pipelines), unless specified in the workscope or otherwise directed by theShell Offshore Representative, acting on advice from the responsible Structural Engineer.

Coating may only be removed where coating damage (i.e. paint coat blistering) has occurred orsuspected, unless specified in the workscope or otherwise directed by the Shell OffshoreRepresentative, acting on advice from the responsible Structural Engineer.

3.4.1 ROV Contact CP Readings

A steel tipped contact CP probe is to be used for this method of survey. This method is only to beemployed where the Proximity method is not suitable, i.e. on wellheads, and other electrically isolatedstructures.




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The Remote Reference CP systems described above can be used in a contact CP mode.

3.4.2 Diver Contact CP Readings

Bathycorrometer hand held CP meters are to be used for diver contact CP surveys.

Video overlay of these readings are not possible, but where taken, best endeavours should be madeto obtain video from the diver camera of the obtained readings. All readings obtained should berepeated by the inspection controller on the video commentary.

4 OPTIONS

4.1 Anode Inspection

In addition to general anode wastage inspection, as specified in procedure I 01 007 – General Video

Survey, other anodes may be specified for more detailed inspection, including CP. This type of surveyis typical of internal igloo inspections.

Anodes selected for inspection will be listed in the Workscope, or specified by the Shell OffshoreRepresentative.

The presence, location and specification of the anode is to be confirmed as per UMDB layoutdrawings.

4.1.1 Anode CP Survey – (CP-AN)

Cathodic protection potential readings are to be taken at three positions on the anode; one on each ofthe two attachment stubs, and one in the centre of the anode.

Proximity probes are the preferred method for obtaining the required readings. Contact probes shallnot be used without the prior approval from the Shell Offshore Representative acting on advice fromthe responsible Structural Engineer.

Calibration data is to be noted and verified before and after each dive and before each set of readingsif the contact probe method is used (See 3.2).

4.1.2 Detailed Anode Inspection – (VI-AWD)

Describe marine growth coverage as hard or soft, giving estimated thickness and percentage cover ofeach (MG-GEN).

The integrity of the anode support (bracket, bracelet, earthing strap) is to be checked.




0153-001

A guide to estimate percentage wastage on an anode is given below (VI-AW):





ANODE DEPLETION SCHEMATIC

To obtain volumetric information on the remaining anode material it will be necessary to measure theanode for overall length, and at three positions around its perimeter, being 100mm in from each endand at the centre point of the anode, see Fig 3.

ROV measurements are to be taken using a graduated, right angled, measuring stick for the threeperimeter positions and a long graduated pole, or graduated marks on the manipulator, for measuringthe overall length. Graduation marks to be in increments of 10mm and black/white alternatively.

Diver measurements are to be taken around the perimeter using a tape measure.

NOTE: On an anode bracelet it will only be necessary to carry out the inspection on one anodesegment.

On completion of the inspection the ROV is to carry out, and fully video record, a general visual surveyat each anode location, which is to clearly show an overall view of the anode and attachment,brackets.

The result of the inspection is to be recorded on the Anode Inspection Summary Report Format, Fig 1,and Anomaly Report Format where applicable.

4.2 Cathodic Protection Potential Survey – Zonal (CP-ZON)

4.2.1 CP Survey - Zonal

Cathodic potential reference sampling points will be listed in the workscope.

For the purpose of data analysis taken from structural steel jackets, the cathodic potential monitoringdata is to be gathered from two zones, namely:

Zone 1: From the water level at LAT to first horizontal framing below LAT, 10 reference points tobe allocated.

Zone 2: From the first horizontal framing below LAT to the seabed. Typically 50 referencepoints to be allocated.

Cathodic potential reference point will be defined as:

• One reading taken on each of the selected anodes either side of the mid point.




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• One reading taken on structural steelwork midpoint between the selected anodes.

• Two readings, one each one metre each side of the midpoint reading location. See Fig 2.

Proximity probes are the preferred method for obtaining the required readings. Contact probes shallnot be used without the prior approval from the Shell Offshore Representative acting on advice from

the Sponsoring Engineer.

Calibration data is to be noted and verified before and after each dive and before each set of readingsif the contact probe method is used.

The result of the inspection is to be recorded on the Cathodic Potential Inspection Summary ReportFormat, Fig. 4, which is to include make and serial number of equipment used, and Anomaly ReportFormat where applicable.

4.3 Cathod ic Protection Potential Survey – Nodal (CP-NOD)

4.3.1 CP Survey - Nodal

Cathodic potential reference sampling points will be listed in the Workscope or specified by the ShellOffshore Representative.

For the purpose of data analysis taken from structural steel jackets, the cathodic potential monitoringdata is to be gathered from selected nodal joints at the four cardinal clock positions at the followinglocations:

(1) At the Weld.

(2) 1m along the Brace Member from the Weld.

(3) 2m along the Brace Member From the Weld.

Proximity probes are the preferred method for obtaining the required readings. Contact probes shallnot be used without the prior approval from the Shell Offshore Representative acting on advice fromthe Sponsoring Engineer.

Calibration data is to be noted and verified before and after each dive and before each set of readingsif the contact probe method is used (See 3.2).

The result of the inspection is to be recorded on the Cathodic Potential Inspection Summary ReportFormat, Fig 5, which is to include make and serial number of equipment used, and Anomaly ReportFormat where applicable.

4.4 Anode Direct Current Measurement – (CP-GSC/IN-GSC)

4.4.1 Inspection Qualifications

The gathering of G-Scan data is to be carried out by a Level II G-SCAN System Operator.

Use of the Swain Sea Clip can be carried out by any topside operator.

4.4.2 Anode CP Survey – (CP-GSC)

Anodes selected for inspection will be listed in the workscope, or selected by the Shell OffshoreRepresentative.

Cathodic Protection Potential readings are to be taken at three positions on the anode; one on each of

the two attachment stubs and one in the centre of the anode.




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Proximity probes are the preferred method for obtaining the required readings. Contact probes shallnot be used without the prior approval from the Shell Offshore Representative acting on advice fromthe Sponsoring Engineer.

Calibration data is to be noted and verified before and after each dive and before each set of readings,if the contact probe method is used (See 3.2).

4.4.3 Anode Measurement – (IN-GSC)

Measurement readings are to be taken on anode attachment brackets, and/or standoff stubs, and/orbonding cables. One reading at each position.

The selected anode will be inspected and reported upon as follows, prior to carrying out the directcurrent measurements and any cleaning.

The presence, location and specification of the anode is to be confirmed as per UMDB layoutdrawings.

Describe Marine Growth (MG-GEN) coverage as hard or soft, giving estimated thickness and

percentage cover of each.

On completion of the above, the anode and attachment brackets are to be cleaned of all excessivemarine growth; hard stubborn growth need not be removed.


A guide to estimate percentage wastage on an anode is given below (VI-AW):






Measurements of pitting are to be carried out listing maximum and minimum depth and maximum andaverage diameter.

The anode is to be measured for length, and at three positions for circumference being 100mm in fromeach end of the anode and at the centre point of the anode.

To obtain volumetric information on the remaining anode material it will be necessary to measure theanode for overall length, and at three positions around its perimeter, being 100mm in from each endand at the centre point of the anode, see Fig 3. Measurements are to be taken using a graduated,right angled, measuring stick for the three perimeter positions and a long graduated pole, or graduatedmarks on the manipulator, for measuring the overall length. Graduation marks to be in increments of10mm and black/white alternatively.

NOTE: On an anode bracelet it will only be necessary to carry out the inspection on one anodesegment.

I 60 004 Re-issue 04/05Page 10 of 15



0153-001

Anode direct current measurements are to be taken using the Millstrong G-Scan System, or SwainSea Clip. The procedures to follow are as per the manufactures manual. The G-Scan unit is to beoperated by a Level II G-SCAN System Operator topside.

4.4.4 System Calibration

Calibration of the G-Scan System will be performed prior to each dive or planned inspectionprogramme, but as a minimum at least every 24 hours if to be used over an extended period.

Calibration of the Swain Sea Clip, is as per manufacturers instructions.

4.5 Final Report

Inspection data format, CP data format, video log and anomaly report format, where applicable, are tobe completed for all works carried out.

Each individual CP reading taken is to be recorded within the COABIS database. Where only one CPtask box is present against a component, but several readings are required, i.e. on a riser or caissonsection, additional CP task boxes are to be created, and the relevant location of the reading entered,

i.e. depth, along with the CP results.

The COABIS Workpack Diary report is to include the maximum and minimum of all CP readings takenare to be reported for a specific section of a survey, i.e. CTS or specific elevation, or where a sectionof a survey has been conducted during a specific dive. Reference should be made confirming thelocation where the full survey data can be obtained, i.e. COABIS database. Any C1 anomalies are tobe commented on more specifically.

Locations of all anodes chosen for inspection are to be specified in the report.

Any completed data sheets are to be included with the final report, and suitably referenced. If possible,they should be part of the final electronic COABIS Word document, not separate sheets. If createdelectronically they should be stored within the COABIS database and suitably linked.

Where Anode Direct Current Measurements have taken place, the results of the inspection are to berecorded on the Anode Direct Current Inspection Report format, Fig 6 and 7, and Anomaly ReportFormat where applicable.

Re-issue 04/05 I 60 004Page 11 of 15



0153-001

AnodeNo

-mVMarineGrowth

%

Cover

SupportWastage% and

CategoryMeasurement (mm) Video

Ref Conditions

L C1 C2 C3

Figure 1 Example of Format for Anode Inspection

I 60 004 Re-issue 04/05Page 12 of 15



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LEG A

1 24 5

12204

6201062009

NOTE:

THIS IS AN ILLUSTRATION OF THE 5 READINGS

TO BE TAKEN AT EACH "REFERENCE POINT"

3

LEG B

Figure 2 Typical Structural Cathodic Potential Reference Point

100mm

100mm

C3

C2

C1L

= OVERALL ANODE LENGTH

= OUTSIDE, PERIMETER MEASUREMENT, 100mm IN FROM

EACH END OF ANODE.

= OUTSIDE, PERIMETER MEASUREMENT, MID-POINT OF ANODE

NOTE:

L

C1, C3

C2

THE RIGHT ANGLED MEASUREMENT AT EACH OF THE 3 LOCATIONS IS TO

BE DOUBLED TO GIVE APPROXIMATE FULL OUTSIDE MEASUREMENT OF ANODE.

Figure 3 Typical Anode Volumetric Measurements

Re-issue 04/05 I 60 004Page 13 of 15



0153-001

Calibration: (Pre/Post, -mV) (138) 1054/1054 (141) 1052/1046 (142) 1046/1034 (145) 1034/1035

Dive RefNo

MemberNo

Anodes CP Readings -mV VideoTape

DateCompleted

1 2 Anode

1

1m

Away

Midwa

y

1m

Away

Anode

2

ZONE1

145 1 61001 A B 1029 999 994 994 996 5506 12-06-96

145 2 61002 A B 1021 1002 1001 1001 1028 5506 12-06-96

145 3 61003 A B 1027 948 999 999 997 5506 12-06-96

145 4 61004 A B 1026 990 940 974 981 5506 12-06-96

145 5 62101 A B 1026 994 999 999 932 5506 12-06-96

ZONE2

146 6 61101 A B 1032 999 993 1025 992 5507 12-06-96

146 7 63101 A B 1027 1000 999 1028 1004 5507 12-06-96

141 8 61102 A B 1030 1000 1000 1000 1038 5502 11-06-06

146 9 63102 A B 1022 996 999 1029 1001 5507 12-06-96

146 10 63103 A B 1028 999 997 1000 1031 5507 12-06-96

142 11 61103 A B 1032 991 993 995 1025 5503 11-06-96

142 12 63104 A B 1033 991 991 992 1025 5503 11-06-96

142 13 61104 A B 1026 987 998 991 1028 5503 11-06-96

141 14 62204 A B 1037 1012 1012 1013 1036 5502 11-06-96

141 15 62208 A B 1033 1002 1007 1008 1022 5502 11-06-96

138 16 61201 A B 1028 996 986 999 1029 5500 10-06-96

Figure 4 Example of Format for Zonal CP Survey

Start Cal: -1027mV End Cal: -1030mV

Location (-mV) 12 O/C 3 O/C 6 O/C 9 O/C

Before At weld 953 952 951 953

Cleaning 1m from weld 956 957 958 957

2m from weld 959 961 960 959

Figure 5 Example of Format for Nodal CP Survey

I 60 004 Re-issue 04/05Page 14 of 15



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Re-issue 04/05 I 60 004Page 15 of 15

IN – GSC

AMPSUPPER

AMPSLOWER

TOTAL AMPS

SECURE DEPLETION MGCOVER

LENGTH C1 C2 C3 AVERAGEPIT

MAXIMUMPIT

AVERAGEDIAMETER

MAXIMUMDIAMETER

CP - GSC (-mV)

TOPSTUB

ANODE BOTTOMSTUB

Figure 6 Example of Format for Anode Direct Current Measurement Monitoring- Blank

IN - GSC

AMPS

UPPER

AMPS

LOWER

TOTAL

AMPS

SECURE DEPLETION MG

COVER

LENGTH C1 C2 C3 AVERAGE

PIT

MAXIMUM

PIT

AVERAGE

DIAMETER

MAXIMUM

DIAMETER

0.74 0.62 1.36 YES 25 100 2430 900 980 920 15 20 80 130

CP - GSC (-mV)

TOPSTUB

ANODE BOTTOMSTUB

Note 1: Total output (amps) is the sum of the G-Scan output (amps) from upper and lowercolumns

948 945 935

Figure 7 Example of Format for Anode Direct Current Measurement Monitoring-

Completed



0153-001

PROCEDURE I 97 001

INSPECTION OF ABANDONED / SUSPENDED WELLHEAD

CONTENTS

Para. Page

1 INTRODUCTION 3

2 TASKS 3


2.2

Optional Tasks 3



3.2 Wellhead Identification (VI-ROV) 4

3.3 General ROV Inspection (VD-ROV) 4

3.3.1 Wellhead Survey 5

3.3.2 80m Radius survey 5

3.4 Rig Intervention Activities 6

3.4.1 Final ROV Inspection 6

4 REPORTING 7

4.1 Final Report 7

FIGURES

No. Page

1 Seabed Clearance Certificate - PT1, Typical 8

2 Seabed Clearance Certificate - PT2, Typical 9

Am 02 08/05 I 97 001 Page 1 of 9



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I 97 001 Am 02 08/05Page 2 of 9



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PROCEDURE I 97 001

INSPECTIONINSPECTION OF ABANDONED / SUSPENDED WELLHEAD

1 INTRODUCTION

This work method is to be applied to the inspection of a wellhead, which has either been abandonedor suspended. The levels of inspection will depend upon whether the work is required to check onwells general state, or as a prelude to future rig intervention. The work shall include damage survey,video survey, debris clearance, cleaning and dimensional survey.

The procedure incorporates both a general inspection of the wellhead, or inspection, cleaning anddebris removal for the purposes of rig intervention.

Debris removal under Procedure I 01 003 is to be employed in conjunction with this procedure.

2 TASKS

2.1 Standard Tasks









CH-VLV - Valve Position Check


2.2 Optional Tasks




Am 02 08/05 I 97 001 Page 3 of 9







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The grid pattern is to be displayed within the 80m radius on the vessels positioning screen. With theROV positioning beacon also registered. The ROV is to conduct the survey following the set gridpattern. SIT camera views are to be used for the bulk of the survey, with colour camera to be used toevaluate items of debris, and other areas of interest.

Sonar is to be used set to 20m, to give suitable overlap to the SIT views, checking for debris and other

seabed features. Video of the sonar display should be intermittently displayed, and where items ofinterest are identified. All items identified by Sonar, not previously identified visually are to beinvestigated and recorded on video.

All items of debris or interest are to be position fixed by the ships surveyor, or Bridge personnel. Thisreading is to be noted, verbally included on the video commentary and included in the final report.

Unless specifically requested, there is no requirement for debris removal.

3.4 Rig Intervention Activities

Should the survey be required for Rig Intervention purposes, or as stated in the workscope, thefollowing actions should be taken, either by ROV or diver:

(1) Identify wellhead position. Approach with caution as per warning above.

(2) Complete 80m radius survey as per 3.3.2.

(3) Recover and remove all debris within the immediate area of the wellhead and from within an80m radius of the wellhead.

On completion of debris removal the ROV or diver shall carry out the following:

(4) Clean and inspect the bullseye level indicator, recording the position of the ball bearing on theboard and give compass heading. Take digital still image.

(5) Deploy cleaning equipment to site and remove all marine growth and any corrosion productfrom the top 500mm of each guidepost latch profile.

(6) Carry out a close inspection of each guidepost latch profile recording any damage or anomaliesnoted. Where old guide wires are located within the guideposts, these are to be removed sothat there is no protrusion above the top surface of the post.

(7) Locate and clean the corrosion cap. Care is to be taken to ensure all mating and latchingprofiles are thoroughly cleaned so recovery tool will engage all faces correctly. Carry out adetailed inspection of the corrosion cap recording any damage or anomalies noted.

(8) If required, remove the corrosion cap and clean the AX/VX sealing area. The use of nylon

brushes; suction or LP water jet is only permitted. Remove any silt, mud, shell or other debrisfrom in or around the tubing hanger, control and production bores. Carry out a detailedinspection of the AX/VX sealing area recording any damage or anomalies noted. Replacecorrosion cap on completion.

3.4.1 Final ROV Inspection

Should the survey be required for Rig Intervention purposes, or as stated in the workscope, oncompletion of all debris removal and cleaning work the ROV shall carry out, and fully video record, avisual survey of the wellhead, paying particular attention to the following:

(1) Check each guidepost for out of vertical alignment, giving angle and direction of tilt. (Estimatefrom video screen).

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0153-001

(2) Check if guide base is horizontal, giving direction and degree of tilt. Bullseye reading if fitted, orestimate from screen. Give Digiquartz readings on all four faces and mid-point, if fitted.

(3) All cleaned areas on guideposts showing detail of each guideline latch profile.

(4) All cleaned areas on corrosion cap showing detail of all recovery tool latching faces, and fit up

of corrosion cap.

(5) Site survey of the wellhead and surrounding area within an 80m radius. Use sonar and videorecording (sonar sweep to be recorded).

4 REPORTING

4.1 Final Report


The given and as-found position fix co-ordinates are to be stated.


Forms PT1 (Fig 1) & PT2 (Fig 2) are to be completed, electronic versions saved within COABIS andhard copies submitted with the report.

Am 02 08/05 I 97 001 Page 7 of 9



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Figure 1 Seabed Clearance Certificate - PT1, Typical

I 97 001 Am 02 08/05Page 8 of 9



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LIST OF TARGETS

Position (Distand Brg)

ApproxDimensions (m)

Description Means ofIdentification

Y/NRecoverable

1

2

3

4

5

6

7

8

9

10

MEANS OF IDENTIFICATION REASONS FOR NOT REMOVINGREMAINING DEBRIS

A SONAR SCAN D VESSEL RECORDS

B DIVING INSPECTION

C ROV

SIGNATORIES (1) (2)

NAME ____________________ NAME ____________________

POSITION ____________________ POSITION ____________________

COMPANY ____________________ COMPANY ____________________

GUIDANCE NOTES

(1) Survey should extend to at least 80m from the wellhead.

(2) The first signatory should be the person responsible for the client or his representative.

Second signatory should be the person supervising the seabed survey, i.e. the Sonar Operator, ROVSupervisor.

Figure 2 Seabed Clearance Certificate - PT2, Typical

Am 02 08/05 I 97 001 Page 9 of 9



0153-001

PROCEDURE I 97 002

INSPECTION OF SUBSEA TREE

(PRODUCTION AND WATER INJECTION)

CONTENTS

Para Page

1 INTRODUCTION 3

2 TASKS 3




3.2 Wellhead Identifi cation (VI-ROV) 4

3.3 Init ial ROV Inspection (VI-ROV / VD-ROV) 4

3.4

Visual Inspection (VD-ROV/VI-DVI) 4

4 REPORTING 6

4.1 Final Report 6




0153-001




0153-001

PROCEDURE I 97 002

INSPECTION OF SUBSEA TREE

1 INTRODUCTION

This work method is to be applied to the inspection of a subsea production tree. The work shall includedamage and video survey. The purpose of the survey is to record the following:

(1) Any sign of debris/fishing nets.

(2) Any sign of leaks from the wellhead conductor or from any of the tree components.

(3) Any scour and seabed level around the perimeter of the tree.

(4) Any obvious damage to the subsea equipment.

2 TASKS

2.1 Standard Tasks







VI-AW - - Anode Wastage

VI-DVI- - Detailed Visual Inspection

CH-LKS - Check for Leaks

PH-DIG - Digital Photographs









0153-001

3.2 Wellhead Identi fication (VI-ROV)

Survey data, including the position of the well to be inspected, will be provided by the Shell Surveydepartment prior to commencement of operations. All survey data shall be based on InternationalSpheroid, European Datum 1950 (ED50), Transverse Mercator Projection. For UK Sector CentralMeridian is 0 deg and for Dutch Sector Central Meridian is 5deg E. Reference Section 1, Chapter 2,Figure 1, for further datum shift parameters.

On arrival at the worksite, it should be established that the correct tree has been identified, by use ofsuitable markings on the tree itself, or by use of the Shell survey data provided, and/or field layoutdrawings to provide other suitable means of confirmation. The Shell Offshore Representative is to beconsulted should no markings be present, and the latter method is used to confirm that the correct treehas been identified.

If doubt persists as to the correct identification of the tree, then a positional fix is to be taken of the topcentre of the tree. Should this fix disagree with the workscope stated position by more than +/-5m, andthen initiate checks to resolve errors. Such checks should confirm that the vessel's positioning systemhas been suitably calibrated.

If required a spin check should be carried out to verify the USBL positioning system. If the spread ofthe position data is more than the accuracy of the positioning systems, (i.e. DGPS 1-3m & USBL 1%of water depth) checks should be initiated to resolve errors. Prior to this, a CTD profile of the full watercolumn should be observed and the relevant data entered into the USBL system.

3.3 Init ial ROV Inspection (VI-ROV / VD-ROV)

The ROV shall carry out, and fully video record, an initial visual survey of the tree and the seabed areaimmediately around the wellhead.

WARNING: THE ROV SHOULD INITIALLY APPROACH THE WORK SITE FROM UPCURRENT TO MINIMISE THE POSSIBILITY OF ENTANGLEMENT FROM FISHING

GEAR DEBRIS.

For survey and video work the ROV should be positioned to maximise visibility. Initially the ROVshould position itself above the tree and, with the camera in SIT mode, carry out a full 360 degreesweep around the structure ensuring that a good video coverage of the tree and surrounding seabedis obtained. The survey is to include the flowbase and control jumper approaches.

The purpose of this survey is to record the following:

(1) Site conditions are correctly identified in accordance with relevant location drawings. This is toinclude that the correct tree has been identified, by suitable tree markings.


(3) Any sign of debris/fishing nets.

(4) Any obvious damage or anomalies. Checking for any signs of leaks from the tree conductor,seabed or from the tree components.

(5) Any obvious areas of scour or the extent of any build up of mud around the perimeter of thebase of the tree or the flowbase.

3.4 Visual Inspection (VD-ROV/VI-DVI)

Although detailed in nature, no cleaning is required unless an anomaly is identified. To this extent theinspection standard required is partway between a GVI and DVI, to ensure that all tree components

have been identified, and sufficient views have been obtained to confirm its integrity.




0153-001

On completion of the initial visual inspection the ROV or diver shall carry out a visual inspection of thetree flowbase checking for any signs of damage, debris, anode wastage or leaks.

A seabed survey around the perimeter of the tree/flowbase is to be carried out by checking for anysigns of scour/build up of mud. The survey shall include any flowlines and umbilicals from theirconnection points on the tree down to the seabed touchdown only, checking for any signs of leakage

or damage.

A detailed visual inspection is to be carried out on each of the four faces of the wellhead. TheROV/diver should set up position on each face in turn and, using the colour camera, carry out aninspection on each of the components – clearly identifying each component in turn. The videocommentary is also to clearly state which face is being surveyed.

The survey shall pay particular attention to the following areas:

(1) Check all major components i.e. valves, control panels, hydraulic/electrical jumpers, hydraulicconnections (a common area for failure), flanges etc for any signs of leaks. Attempt to show theposition of the valve indicators, although no comment is required as to the valve position. Checkcomponents for any areas of obvious damage, i.e. coating damage, blistering, corrosion etc.

(2) Should any areas show signs of corrosion then contact CP readings should be taken.

(3) Check under the tree cap/roof area of the tree for any signs of oil. (CH-LKS).

(4) Check the tree cap and guide posts, in particular the Regan latches at the top of the posts, forany signs of obvious damage or debris.

NOTE: Guide wire at the base of a guidepost is not anomalous.

(5) The serial number of any control module, where appropriate, is to be recorded.

(6) The survey is to include any flowlines/control jumpers from their connection point on theflowbase down to the seabed touchdown. At touchdown, views are required to show the route ofthe flowlines/jumpers away from the tree, to confirm the presence and integrity of any supports,protection bags/mats or point of burial.

Check all connections for leaks. With respect to jumpers, check the respective hoseconnections to the back of stab plates for any leaks or damage.

For jumpers, check that there is no tension on any jumpers and their connections.

(7) Anode wastage. (VI-AW)

(8) ROV to move around the perimeter of the tree/flowbase reporting any scour/build up of mud on

the seabed around the guide base. (DM-SCR). Note: There are specific anomaly criteria withrespect to igloo scour. See Section 2, Chapter 6, Point 2.3.13.

(9) Check for any gas bubbles emanating from the seabed area around the centre of the tree and inparticular where the conductor penetrates the seabed. (CH-LKS).





0153-001


4 REPORTING

4.1 Final Report



Where any problems may have arisen in confirming the correct tree identification, report on the stepstaken to confirm correct identification.



0153-001

SECTION 4

CONSTRUCTION PROCEDURES

CONTENTS


R 01 011 DREDGING

R 26 001 INSTALLATION AND REMOVAL OF CLAMPED BLANKING FLANGE

R 48 001 INSTALLATION AND REMOVAL OF BLIND FLANGE

R 48 002 INSTALLATION AND REMOVAL OF INLET BLANKING PLUG (ROV

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0153-001

PROCEDURE R 01 011

DREDGING

1 INTRODUCTION

The work method is to be applied to the excavation of alluvial materials. Typical requirements to

necessitate material removal are:

(1) Remove of excessive drilling mud and cuttings build up to permit inspection of covered

members, concrete surfaces, or to reduce structural loading on cell tops.

(2) Trenching for pipeline repair.

(3) Clearing and levelling the seabed.

(4) Seabed excavation during light construction operations and remedial works.

Depending on which type of dredging equipment is employed the operation can be accomplished

with either ROV or diver assistance or be remotely controlled from surface.

2 TASK OPTIONS



CL-DRG - Dredge Pump



Work may be carried out by any grade of diver.

3.2 Dredging

WARNING: DURING THE DEPLOYMENT AND RECOVERY OF THE DREDGE PUMP THE

DIVER SHOULD FOR SAFETY REASONS REMAIN INSIDE THE BELL.

Carry out an initial survey of the area to be cleared by ROV. The object of this survey is to

determine the extent of the dredging operation and locate any debris that will require removal prior

to deploying dredging equipment.

On completion of this initial survey the diver is to remove debris, if any, from the area to be cleared.

Debris is to be recovered to the surface, as is any other debris that may be uncovered during the

dredging operation. Dredging equipment to be prepared and deployed ready for use in accordance

with the particular manufacturers operating instructions.

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Dredge pump to be positioned at the work location in such a way as to afford the best access to

the area to be dredged thereby minimising frequent movements of the pump.

If a remotely operated dredge pump is being employed the diver is to withdraw from the work area

prior to the commencement of dredging operations.

Dredging operations will commence as per particular manufacturers operating instructions.

Method of dredging is dependant on the location and the material being excavated but will

generally be as follows:

(1) Soft Materials. Allow the suction head to pull itself down into the material to a depth of 2m to

3m. This method will create a self dredged crater which has been found in practice to be the

most effective method for escavating soft materials. This technique reduces diver fatique

when using a diver operated dredge and improves visibility around the work area.

(2) Hard or Compacted Materials. Hard material will require to be disintegrated to assist in

excavation. Most dredge pump systems have a high presure water jetting systemincorporated into the suction head to accomplish this task. Jetting also serves to reduce the

density of the solids/water mixture, thus easing the flow through the dredge pump system.

The main disadvantage of jetting is the resultant poor visibility.

(3) Propwash Dreging. The principle of this system is the removal of materials by directing a jet

of water at the mound, liquifying it and then letting it disperse by action of tide/current. The

units are remotely deployed but require the assistance of divers to remove debris as it

becomes exposed and possibly prevents access to the work site. As with jet dredging a

disadvantage of this method is poor visability.

Should the dredging equipment pump choke during operations the shutdown and clearing

procedure as per the particular manufacturers operating instructions are to be followed.

Progress during dredging operations is usually dependant on a diver assessment as the loss of

visibility precludes the use of video monitoring by ROV. Where operaton allows the use of ROV

mounted sonar may be used to monitor progress.

3.3 Final Report

Dredging data format and video logs where applicable are to be completed for all works carried

out.



0153-001

PROCEDURE R 26 001

INSTALLATION AND REMOVAL OF CLAMPED BLANKING PLATE

1 INTRODUCTION

The work method is to be applied for the blanking of inlets where bolted blind flanges can not be

fitted. The work will include marine growth removal, blank plate installation and removal and

general visual video inspection.

2 TASK OPTIONS

VI-ROV - V Worksite Check

VD-ROV General ROV Video

DB-CHK Visual Debris Check

CL-INS Clean for Inspection

CN-RBP Remove/Replace Blanking Plate

Should additional activities be carried out, suitable work tasks and task codes may be added to

cover works.


WARNINGS: (1) PRIOR TO ANY SUBSEA WORK ENSURE PLATFORM INTAKE OR

DISCHARGE IS ISOLATED.

(2) THE DIVER IS TO KEEP CLEAR OF EQUALISING VALVE OPENING

WHILE OPERATING THE VALVE.


Works may be carried out by any grade of diver. However, inspection orientated work is to be

carried out by CSWIP 3.1u, CSWIP 3.2u diver and CSWIP 3.3u ROV Controller.

3.2 Preparation

Before work can commence on the installation of the blanking plate carry out the following, where

applicable.



NOTE: Specific details of blanking plate size, neoprene gaskets, clamp type and equalising

valves will be given in the Workscope.

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0153-001

3.3 Initial ROV Inspect ion

The ROV will carry out, and fully video record, and initial visual survey of the inlet. The purpose of

this survey is to record the following:




(4) Confirm the presence of inlet grille cage.

(5) Any obvious damage or anomalies.

3.4 Diver Work Scope - Installation

(1) Establish downline and messenger line.

(2) Remove marine growth and any debris as necessary to access work site.

(3) Remove bolts, if present, from inlet grille cage, attach lift bag to lifting lug and messenger

line on downline. Inflate lifting bag to lift inlet grille cage from retaining guides and recover to

surface.

(4) Clean inlet faces to receive blanking plate.

(5) Lower blanking plate with messenger line on downline, manoeuvre into position using lift bag

to assist and lower into retaining guides. Care to be taken that neoprene gasket is not

damaged or misplaced.

NOTE: Prior to final tightening ensure equalising valve on blanking plate is open and plug

removed.

(6) Fit clamps and tighten to secure blank to inlet. Close equalising valve and fit plug.

(7) Derig work site.

NOTE: ROV to monitor and video record the final stage of blanking plate lowering and

positioning on inlet.

3.5 ROV Inspect ion - Post Installation

On completion of diver works the ROV will carry out, and fully video record, a general visual survey

of the blanking plate, paying particular attention to the final placement of the clamps, equalising

valve and fit up.

3.6 Diver Work Scope - Removal

SEE WARNING (2) BEFORE COMMENCING THESE ACTIVITIES

(1) Establish downline and messenger line

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0153-001

(2) Remove securing clamps, attach lift bag to blanking plate and messenger line on downline.

Remove plug from equalising valve and open valve slowly, check for flow.

On confirmation of no flow through equalising valve, inflate bag to lift blanking plate from retaining

guides and recover to surface.

(3) Lower inlet grille cage with messenger line on downline, manoeuvre into position using lift

bag to assist and lower into retaining guides. Replace and tighten securing bolts if fitted.


NOTE: ROV to monitor and video record the removal of blanking plate and fitting of inlet grille

cage.

3.7 ROV Inspect ion - Post Removal


of the inlet, paying particular attention to final placement of the grille cage and fit up.

3.8 Final Report

As built data format and video logs are to be completed for all works carried out.

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0153-001

EQUALISING

VALVE

PLAN

A A

SECTION C - C

CLAMPS

GRILLE

CAGE

SECTION B - B

GUIDE

SUPPORT

BLANKING

PLATE

C

B C

SHAFT 1

SECTION A - A

B

Fig 1 Inlet Grille Cage and Blanking Plate - General Arrangement

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0153-001

PROCEDURE R 48 001

INSTALLATION AND REMOVAL OF BLIND FLANGE

1 INTRODUCTION

The work method is to be applied for the blanking of inlets where bolted blind flanges are present.

The work will include marine growth removal, bland flange installation and removal and general

visual video inspection.

2 TASK OPTIONS

CN-DRP - Deck Preparation






CN-RBP - Remove/Replace Blanking Plate

CN-RIG - Rig/Derig Worksite



cover works.

WARNING: PRIOR TO ANY SUBSEA WORK ENSURE PLATFORM INTAKE OR DISCHARGE

IS ISOLATED.



Works may be carried out by any grade of diver. However, inspection orientated work is to be

carried out by CSWIP 3.1u, CSWIP 3.2u diver and CSWIP 3.3u ROV Controller.

3.2 Preparation

Before work can commence on the installation of the blind flange carry out the following, where

applicable.


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0153-001


NOTE: Specific details of blind flange size, studs and nuts, neoprene gasket, equalising valves

and gauging tool will be given in the Workscope.


The ROV will carry out, and fully video record, an initial visual survey of the inlet. The purpose of






(5) Where possible, establish internal valve status.


3.4 Diver Work Scope - Installation

3.4.1 Embedded Flange



(3) If fitted, attach lift bag to lifting lug on grille cage and messenger line on downline. Inflate

lifting bag to support grille cage. Remove all bolts from around grille cage, when free,

recover to surface.

(4) Clean inlet face taking care not to damage the coating on the flange and pipe internal.

Report status of bolt holes, if threaded, fixed nut or clearance.

(5) Locate holes in embedded flange, insert gauging tool, check for thread engagement and

mark positions of all accessible holes.

If the number and location of usable threaded holes is within acceptable limits (Details asstated in the Workscope) then blind flange can be fitted.

(6) Lower blind flange with messenger line on downline, manoeuvre into position using air bag

to assist, care to be taken that neoprene gasket is not damaged or misplaced, insert studs in

accessible holes, fit nuts and tighten up.

NOTE: Prior to final tightening ensure equalising valve on blind flange is open and plug removed.

(7) Flog up all nuts sufficiently to ensure a good seal. Close equalising valve and fit plug.

(8) Derig work site

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0153-001

Where it is found that there are insufficient holes within acceptable limits to fit the blind flange, then

the internal diameter of the embedded flange will need cleaning and more accurate measurements

taken for the purpose of making and fitting an internal plug.

The following measurements, as a minimum, will be required:

(a) Accurate internal diameter of embedded pipe, checked at two positions.

(b) Flange face diameter, checked at two positions.

(c) Flange face thickness.

(d) Check internal pipe clearance for a minimum distance of 1.5 times the diameter for any

obstructions.

Report on any features that may restrict the fitting of an internal plug.

NOTE: ROV to monitor and video record the final stage of blind flange lowering and positioningon inlet.

3.4.2 External Spool



(3) Clean inlet face taking care not to damage the coating on the flange and spool internal.

Report status of bolt holes, report any damage or corrosion.

(4) Clean holes for studs (details of number and spacing stated in the workscope), if withinacceptable limits then blind flange can be fitted.

(5) Lower blind flange with messenger line on downline, manoeuvre into position using air bag

to assist, care to be taken that neoprene gasket is not damaged or misplaced, insert studs in

accessible holes, fit nuts to both sides and tighten up.

NOTE: Prior to final tightening ensure equalising valve on blind flange is open and plug removed.

(6) Flog up all nuts sufficiently to ensure a good seal. Close equalising valve and fit plug.


3.5 ROV Inspection - Post Installation


of the blind flange, paying particular attention to position of the equalising valve and fit up.

3.6 Diver Work Scope - Removal

WARNING: THE DIVER IS TO KEEP CLEAR OF EQUALISING VALVE OPENING WHILE

OPERATING THE VALVE.


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0153-001

(2) Attach lift bag to blind flange and messenger line on downline. Inflate bag to support blind

flange, remove plug from equalising valve and open valve slowly, check for flow.

On confirmation of no flow through equalising valve, remove all nuts from around blind

flange, remove blind flange and recover to surface.

(3) Remove all studs from embedded flange, or external spool.

(4) If necessary, lower inlet grille cage with messenger line on downline, manoeuvre into

position using lift bag to assist, insert bolts and tighten up.


NOTE: ROV to monitor and video record and removal of blind flange and fitting of inlet grille

cage.

3.7 ROV Inspect ion - Post Removal


of the inlet, paying particular attention to final placement of the grille cage and fit up.

3.8 Final Report


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0153-001

1 1/2"

NEOPRENE GASKET6mm THICK

28" Dia

25" Dia

1 1/2"

20 HOLES - 1 3/8" DIAAT 29.5" PCD

EQUALISING VALVE /

PLUG

34" DIA

PAD EYE (LIFTING LUG) MAY BE

ATTACHED TO EASE INSTALLATION

Fig 1 Typical 34" Diameter Blind Flange - General Arrangement

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0153-001

6mm NEOPRENE GASKETADHERED TO BLIND

VE/PLUG

LIFTING LUG

B7 STUDS TO SUIT

EMBEDDED FLANGE

CAPTIVE NUTS

WAISTED SHANK

GAUGE BAR

TO SUIT

BLIND FLANGE

OMMY BAR

CONCRETE LEG

FIXED T

EQUALISING

VAL

Fig 2 Blind Flange Installation - General Arrangement - Embedded Flange

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0153-001

EXTERNAL

WALL

CONCRETE WALL

1 1/4" DIA

STUDS

NEOPRENE

GASKETS

RUBBER

NUTS

WELDED

LIFTING EYE

Fig 3 Internal Plug Installation - General Arrangement - Embedded Flange

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Fig 4 Blind Flange Installation - General Arrangements - External Spool



0153-001

PROCEDURE R 48 002

INSTALLATION AND REMOVAL OF INLET BLANKING PLUG - ROV

1 INTRODUCTION

The work method is to be applied for the blanking of inlets using blanking plugs specifically

designed for ROV use. The work will include marine growth removal, blanking plug installation and

removal and general visual video inspection.

2 TASK OPTIONS

CN-DRP - Deck Preparation


VD-ROV - General ROV




CN-RBP - Remove/Replace Blanking Plate/plug

CN-RIG - Rig/Derig Worksite



cover works.

WARNING: PRIOR TO ANY SUBSEA WORK ENSURE PLATFORM INTAKE OR DISCHARGE

TO BE WORKED IS ISOLATED.



Works may be carried out by any suitably experienced ROV pilot. However, any inspection

orientated work is to be carried out by CSWIP 3.3u ROV Controller or CSWIP 3.4u Inspection

Controller.

3.2 Preparation

Before work can commence on the installation of the blind flange carry out the following, where

applicable.


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0153-001


NOTE: Specific details of blind flange size, studs and nuts, neoprene gasket, equalising valves

and gauging tool will be given in the workscope.


The ROV will carry out, and fully video record, an initial visual survey of the inlet. The purpose of





(4) Any debris or obstructions in work area, confirm the bore of the inlet is clear.

(5) Where possible, establish internal valve status.


3.4 Installation Workscope



(2) If fitted, attach lift bag to lifting lug on grille cage and messenger line on dowline. inflate liftingbag to support grille cage. Remove all bolts from around grille cage by grinding or impact

driver, when free, recover to surface.

(3) Clean inlet face and bore over the length required for sealing, taking care not to damage the

coating on the flange and pipe internal. Report status of bolt holes, if threaded, fixed nut or

clearance.

(4) Lower the inlet plug worksite in work basket or dummy inlet. Remove plug with the ROV and

insert into the inlet, push fully home. Insert the needle valve tool (NVT) into the plug

operating interface and apply the stated torque for the plug. Record number of turns

necessary to seal plug.

(5) Close equalising valve.

NOTE: Prior to inserting the inlet plug, ensure that equalising valve is open.

3.4.2 ROV Inspection - Post Installation

On completion of inlet plug installation the ROV will carry out, and fully video record, a general

visual survey of the inlet plug, paying particular attention to the fit of the plug and confirming the

equalising valve is closed.

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0153-001

3.5 Removal Workscope


(1) Open the equalisation valve.

(2) Insert the NVT into the plug interface and apply stated torque for the plug. Record number of

turns necessary to unseal plug.

(3) Remove inlet plug and recover to surface.

NOTE: It will be necessary to modify grille for ROV installation.

(4) Lower modified inlet grille cage in work basket frame to work site, ROV to collect grille,

manoeuvre into position and install.

NOTE: ROV to video record removal of inlet plug and fitting of inlet grille cage.

3.5.2 ROV Inspection - Post Removal

On completion of inlet plug removal and grille cage installation the ROV will carry out, and fully

video record, a general visual survey of the inlet, paying particular attention to final placement of

the grille cage and fit up.

3.6 Final Report


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0153-001

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S e t t o 1 5

5 1

1 1 5

375

460 Dia

3 2 7

6 5 0 D i a

3 0 0 D i a

Fig 1 Inlet Plug - Typical



0153-001

SECTION 5

PIPELINE AND RISER PROCEDURES

CONTENTS


I 41 001 RISER AND J-TUBE INSPECTION

I 90 001 VALVE ASSEMBLY SPOOL PIECE (VASP) INSPECTION

I 90 002 PIPELINE DAMAGE INSPECTION

I 91 001 IGLOO INSPECTION - FULMAR TEE SKID

I 91 002 SUBSEA INTERVENTION VALVE (SSIV) INSPECTION - NORTHERNBUSINESS UNITS

I 91 003 IGLOO INSPECTION - WELGAS NUMBER 1 AND 2

I 91 004 IGLOO INSPECTION - 20 INCH FULMAR 'A' TO ST FERGUS GAS PIPELINE

I 91 005 IGLOO INSPECTION - SUBSEA UMBILICAL SPLITTER BOX BRENT ALPHA

I 91 006 SUBSEA INTERVENTION VALVE (SSIV) INSPECTION - SOUTHERN

BUSINESS UNIT (UNDER REVIEW)

I 91 007 IGLOO / MANIFOLD INSPECTION – GENERAL

I 91 008 IGLOO INSPECTION - BRENT SPAR MANIFOLD - ROV

I 91 009 IGLOO INSPECTION – OSPREY TO DUNLIN A FLOWLINE BUNDLE

CARRIER PIPE

I 93 001 PIPELINE PROTECTION COVER INSPECTION

I 98 001 CONCRETE PROTECTION COVERS AND PBSJ INSPECTION

NON STANDARD TASKS

R 90 003 PIPELINE SPAN STABILISATION

R 90 053 INSTALLATION OF PROTECTION MATTRESSES

Am 04 04/08 5-0-1



0153-001

PROCEDURE I 41 001

RISER AND J-TUBE INSPECTION

CONTENTS

Para Page

1 INTRODUCTION 3

2 TASKS 3





3.2 Above Water Inspect ion (VI-TOP / PH-TOP) 4

3.3 Sub Sea Inspection (VD-ROV/VI-GVI) 4

3.3.1 Cathod ic Protection Monitoring (CP-PRX) 5

4

OPTIONS 6

4.1 Detailed Visual Inspection (VI-DVI) 6

4.2 Condit ion of Protection Fender in the Splash Zone (VI-GVI) 6

4.3 Seabed Supports and Protection Frames 7

4.4 Ultrasonic Wall Thickness Measurement (WT-DIG) 7

4.5 Pulsed Eddy Current (PEC) Wall Thickness Measurement (WT-PEC) 7

5 REPORTING 7

5.1 Final Report 7

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0153-001

PROCEDURE I 41 001

RISER AND J-TUBE INSPECTION

1 INTRODUCTION

The work method is to be applied to the inspection of Risers, J-Tubes and their associatedcomponents, from the underside of the deck to the seabed.

Above water visual inspection will also be required from the Diving/ROV Support Vessel using a digitalstill camera.

Underwater inspection will consist of a General Video Inspection (GVI), marine growth survey, debrissurvey and anode wastage measurement. If explicitly stated in the Workscope, it may also includeCathodic Potential (CP) measurement, Ultrasonic Thickness (UT) and Pulsed Eddy Current (PEC) wallthickness measurement and cleaning of specific areas such as clamps/guides, to enable DetailedVisual Inspection (DVI) to be carried out.

Inspection methods under the following procedures are to be employed in conjunction with thisprocedure.

I 15 002 - Ultrasonic Inspection - General.

I 60 004 - Cathodic Protection Monitoring - ROV

2 TASKS

2.1 Standard Tasks




VD-ROV (VD-DIV) - General ROV Video


CP-PRX - Proximity CP Measurements




2.2 Optional Tasks


CL-INS - Cleaning for Inspection


CH-BLT - Bolt Tightness Checks

WT-DIG - UT Wall Thickness Measurements

WT-PEC - Pulsed Eddy Current (PEC) Wall Thickness Measurements

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The inspection is to be carried out by ROV, under the guidance of a CSWIP 3.3u or 3.4u InspectionController, or CSWIP 3.1u/3.2u diver, under the guidance of a CSWIP 3.4u Inspection Controller.Topside inspection is to be carried out by a CSWIP 3.3u/3.4u Inspection Controller.

3.2 Above Water Inspection (VI-TOP / PH-TOP)

A topside visual inspection of the riser/J-Tube and its associated clamps/guides is to be carried outbetween LAT and the under deck of the platform, paying particular attention to the region from LAT to+3m. Only gross defects (C1 category) are to be reported.

Topside digital photographs are required of the above areas of the riser/J-Tube from two oppositesides. These should be taken on an opportunity basis only, with no specific vessel move made to

obtain these images, unless specifically requested in the workscope.

3.3 Sub Sea Inspection (VD-ROV/VI-GVI)

The survey is to be carried out by ROV. Carry out, and fully video record, a GVI of the Riser or J-Tubeincluding all guides, clamps and anodes.

Unless specified by the workscope, the survey is to be performed between LAT, the seabed tie-inflange/weld or bellmouth and out for 20m from the tie-in flange/weld or bellmouth, or to touchdownpoint if this is further away. Should the tie-in flange/weld be greater than 20m away from the edge ofthe platform, then the tie-in flange/weld is to be the extent of the survey.

For flexible risers and umbilicals where no tie-in flange/weld or bellmouth exist, the survey is to betaken out to touchdown or 20m out from the platform, which ever is the greater.

The survey is to cover, as best as practicable, 360° of the circumference of the Riser/J-Tube. Thiswould generally require 2 passes.

The purpose of this survey is to determine the following:

(1) Obvious damage.

(2) Corrosion in the splash zone area.

(3) Areas of wear or corrosion in the vicinity of guides or clamps.

(4) Condition and integrity of any intermediate flanges, guides and clamps.

(5) Condition of protective coating checking for lack of adhesion, blistered, cracked or missingcoating.

(6) Integrity of splash zone sheathing which covers the location and condition of theMonel/Neoprene sheathing paying particular attention for any signs of splitting or bulgingespecially at the circumferential and longitudinal welds.

(7) Presence of debris or obstructions (DB-CHK). As per anomaly criteria, all contacting metallicdebris is to be removed. If deemed to be a Diver/ROV hazard, then attempts should be made toremove such debris.

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(8) Extent of marine growth (MG-GEN). Describe the marine growth as hard or soft, givingestimated thickness and an estimate of the percentage of cover of each.

(9) CP readings at the mid point of each riser section between clamps, and at each clamp. Seesection 3.3.1.

(10) Anode condition and wastage (VI-AW).


A guide to estimate percentage wastage on an anode is given below:


6-20% LOSS - ANODE IN GOOD CONDITION,

CORNERS ROUNDED, SLIGHT PITTING.




(11) Report any differences between the Workscope drawings and the observed configuration.

(12) Position of Seamark identification boards.

(13) Record the distance of touchdown or burial point of the pipeline or umbilical out from the tie-inflange/weld or bellmouth.

Or If buried record the depth at which burial occurs on the Riser or J-Tube. Where buried,complete the pipeline survey to the full extent required, to confirm that the riser or J-Tuberemains in burial, or to establish re-exposure.

No cleaning is to be carried out as part of the routine inspection. If cleaning of a Riser/J-Tube sub-component is required, these sub-components shall be clearly identified in the Workscope.

However, if anomalies are noted during the course of the General Visual Survey, sufficient cleaningshall be carried out to allow a DVI and accurate description of the anomaly.


3.3.1 Cathod ic Protection Monitoring (CP-PRX)

CP readings are required to be taken prior to any cleaning of marine growth.

Proximity measurements are preferred to contact measurements. Only if unavoidable should ContactCP readings be taken on a Riser, and should only be conducted with the approval of the ShellOffshore Representative.

Contact Readings are acceptable on J-Tubes, these being un-pressurised sections of pipe. Note thatsome J-Tubes or J-Tube Bundles terminate with emerging pressurised flexible risers.

Proximity CP readings are required at the mid point of each section, on both sides, and at eachguide/clamp.

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Where the guide/clamp is bolted, where there appears to be the chance that components of the clampmay be isolated from the structure, a contact reading is required for each suspect component. Whereinsufficient COABIS Workpack task boxes exist, relevant additional CP task boxes need to be raisedto accommodate all readings taken.

The CP probe is to be hard wired into the video overlay such that the CP readings are continuously

displayed on the video screen during the survey. CP readings are to be included in the videocommentary.

Refer to Standard Procedure I 60 004 for taking CP measurements, point 3.4.1.

4 OPTIONS

When specified in the Workscope or as directed by the Shell Offshore Representative or by thesponsor, any of the following optional activities may be undertaken.

4.1 Detailed Visual Inspection (VI-DVI)

Areas required to be cleaned and then subjected to DVI will be specified in the workscope.

The purpose of this type of inspection is to establish the condition of an area, or a component and itsattachments, to detect defects that would otherwise be obscured by marine growth. A limited amountof cleaning will be required to carry out this inspection.

Soft marine growth should be removed by either water jetting, scrapers and or wire brushes. Thestandard of cleaning shall be sufficient to enable details of the component to be seen. It will not benecessary to remove hard marine growth unless it obscures detail (CL-INS).

Care is to be taken during the cleaning process to ensure any surface coatings are not damaged.

On completion of the cleaning, the Detailed Visual Inspection shall consist of:

(1) Checking the general condition of the component noting the number, alignment and condition ofany securing bolts (CH-BLT) both around the Riser and back to the structure.

(2) Checking the alignment of the component.

(3) Reporting any movement between the Riser and the component and reporting on any wear orcorrosion.

(4) Reporting the gap between the Riser pipe and the component where appropriate.

(5) Reporting on the presence and condition of any liners.

(6) Checking integrity of any continuity straps or bonding cables.

4.2 Condit ion of Protection Fender in the Splash Zone (VI-GVI)

The following areas are to be noted and fully reported on:

(1) Obvious damage or distortion.

(2) Corrosion.

(3) Confirm integrity and presence of any bolts (CH-BLT).

(4) Marine growth levels. Describe growth as hard or soft, giving estimated thickness and estimate

of percentage cover of each.

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(5) Anodes. Percentage wastage is to be observed using standard depletion categories.

(6) Pintle/fender seating.

(7) Presence of debris. Remove by ROV if possible.

(8) Protective coating. Lack of adhesion, blistered, cracked or missing coating, presence ofcorrosion product at these locations is to be noted.

4.3 Seabed Supports and Protection Frames

The following areas are to be noted and fully reported on:

(1) Obvious damage or distortion.

(2) Corrosion.

(3) Marine growth levels. Describe growth as hard or soft, giving estimated thickness and estimateof percentage cover of each.

(4) Anodes. Percentage wastage is to be observed using standard depletion categories.

(5) Presence of debris. Remove by ROV if possible.

(6) Protective coating, lack of adhesion, blistered, cracked or missing coating, presence ofcorrosion product at these locations is to be noted.

(7) Seabed condition.

(8) Scour or build up of sediments around base of the support or protection frame is to be reportedon.

4.4 Ultrasonic Wall Thickness Measurement (WT-DIG)

Readings can be taken by both ROV and diver. The measurement locations shall be clearly specifiedin the Workscope and a final report shall clearly identify the exact location where the readings aretaken.

Refer to Standard Procedure I 15 002 for taking UT wall thickness measurements, section 3.3.

4.5 Pulsed Eddy Current (PEC) Wall Thickness Measurement (WT-PEC)

Readings can be taken by ROV. The measurement locations shall be clearly specified in theWorkscope and a final report shall clearly identify the exact location where the readings are taken.

Refer to Standard Procedure I 15 002 for taking UT wall thickness measurements, section 3.4.

5 REPORTING

5.1 Final Report



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I 41 001 Am 03 04/06Page 8 of 8

If not anomalous, reference is to be made to any marine growth results taken, confirming the locationwhere the data can be obtained, i.e. COABIS database.

The maximum and minimum of all CP readings taken are to be reported for a specific section of asurvey, i.e. CTS or specific elevation, or where a section of a survey has been conducted during aspecific dive. Reference should be made confirming the location where the full survey data can be

obtained, i.e. COABIS database.

Any other specific inspection tasks requested in the workscope are to be commented upon. If the taskcould not be completed, a statement is required stating reasons.


The exact location of any WT readings taken are to be clearly identified, including any alternativelocations chosen and reason. If required, a suitable drawing should be provided.

Where a large number of Cygnus WT readings are taken, that cannot be suitably incorporated into theWorkpack Diary, a drawing showing the results and the location of the readings is to be submitted.

A hard copy of all PEC data results, and any associated Cygnus WT readings, are to be included inthe Results/Appendix section of the final report. This format is converted from the processed PEC datafiles, which is in an excel format. All PEC data files are to be saved within the COABIS database, andsuitably linked.



0153-001

PROCEDURE I 90 001

VALVE ASSEMBLY SPOOL PIECE (VASP) INSPECTION

CONTENTS

Para Page

1 INTRODUCTION 3

2 TASK OPTIONS 3

2.1 External 3

2.2 Internal 3



3.2

Location Confirmation 4

3.2.1 External Survey (VD-ROV) 4

3.3 Removable Covers (CN-RPL) 5

3.3.1 Removal of Central Cover - Approximate Weight in Air 2 Tonne. 5

3.3.2 Removal of End Covers - Approximate weight in air 6.5 Tonne 5

3.4 Internal Survey (VD-DIV / VD-ROV) 6

4 REPORTING 8

4.1 Final Report 8

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0153-001

PROCEDURE I 90 001

VALVE ASSEMBLY SPOOL PIECE (VASP) INSPECTION

1 INTRODUCTION

The work method is to be applied to the external and internal inspection of the Valve Assembly SpoolPiece (VASP). The work will include damage survey, scour survey, pipeline movement monitoring,leak monitoring, Cathodic Potential (CP) measurements, UT wall thickness measurements, anodesurvey, video survey and photography.

The VASP is situated at KP 446.860 on the Brent Alpha to St Fergus 36 inch Gas Pipeline,(Pipeline/COABIS Code N0201 (IGL03), IBIS Incident No. 99).

NDT methods under Procedure I 15 001 and I 15 002 will be required to inspect lifting attachmentpoints on removable covers and carry out UT inspection on 36 inch pipeline.

2 TASK OPTIONS

2.1 External





2.2 Internal

CN-RPL - Open or Close Roof Panel

VD-DIV/ROV - General Video




CP-CON - Contact Measurements

WT-DIG - UT Wall Thickness Measurements



Any number or combination of the listed work tasks, or those listed under Procedure I 15 001, may beused or called for on the workscope or during the course of the inspection to fully investigate andreport damage as found.

Should anomalies be noted, they are to be reported and acted upon as per Section 2, Chapter 6,

‘Anomaly Reporting & Criteria’, and as directed by the Shell Offshore Representative.

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3.2 Location Confirmation

Survey data, including the position of the igloo/manifold to be inspected, will be provided by the ShellSurvey department prior to commencement of operations. All survey data shall be based onInternational Spheroid, European Datum 1950 (ED50), Transverse Mercator Projection. For UK SectorCentral Meridian is 0 deg and for Dutch Sector Central Meridian is 5deg E. Reference Section 1,Chapter 2, Figure 1, for further datum shift parameters.

On arrival at the worksite, it should be established that the correct structure has been identified, by useof suitable markings on the SSIV itself, or by use of the Shell survey data provided, and/or field layoutdrawings to provide other suitable means of confirmation. The Shell Offshore Representative is to be

consulted should no markings be present, and the latter method is used to confirm that the correctstructure has been identified.

If doubt persists as to the correct identification of the igloo/manifold, then a positional fix is to be takenof the as-built fix co-ordinate position, which may not be the centre of the igloo/manifold. Should this fixdisagree with the workscope stated position by more than +/-5m, then initiate checks to resolve errors.Such checks should confirm that the vessel's positioning system has been suitably calibrated.

3.2.1 External Survey (VD-ROV)

The ROV will carry out, and fully video record, a general visual survey of the VASP installationlocation. The purpose of this survey is to record the following:

(1) An overall view of the VASP (use of SIT camera) from all sides. This survey is to check for anygross damage or debris, and to confirm the area is safe for diver intervention. Results of thissurvey to be relayed to the dive supervisor (VI-ROV).

On completion of the overall view, a more detailed survey is to be carried out in colour.

(2) All side and roof panels for any evidence of impact damage. Check all hinges, paying particularattention to the central roof panel, which will be later removed. If any concerns regarding thecentral panel, relay this to the dive supervisor.

(3) CP readings on four corner of the structure, proximity or contact. (CP-PRX)

(4) The entry and exit of the pipeline to the VASP structure for any evidence of pipeline movement

or door settlement.

(5) Scour around the base of the VASP. Note: There are specific anomaly criteria with respect toigloo/manifold scour. See Section 2, Chapter 6, Point 2.3.12. (DM-SCR).

(6) Debris (DB-CHK).

(7) General views are required of the approaches of each pipeline out to 5m from theigloo/manifold, or to the start of protection mattresses, which ever is the lesser. The survey is toconfirm the presence and integrity of any supports, protection bags/mats or point of burial.


Note: A redundant pipeline movement-monitoring device exists on the North side of the VASP.

I 90 001 Am 03 04/06Page 4 of 14



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3.3 Removable Covers (CN-RPL)

For the diver or ROV to gain access to the VASP, it will be necessary to remove one or more of thethree top covers.

CAUTION (1) The centre panel has to be removed before either of theend panels.

(2) End cover removal must only be undertaken after removalof the central cover.

3.3.1 Removal of Central Cover - Approximate Weight in Air 2 Tonne.

Prior to attaching lifting strops the 4 extension horn lifting points are to be subjected to a close visualinspection. Only after the inspection confirms no anomalies is the central cover to be removed (see Fig2). The Lifting Strop:

1 x Four Leg Sling complete with frame type link made up as follows: 3/4 inch - 6 x 19 galvanizedIWRC slings 5m long. Each leg tested to 3.25T SWL. Hard eyes both ends each leg. 6.5T SWL G2150shackles at free ends.

6 x Crosby Type G2150 bolt type anchor shackles.

Attach lifting strop and remove central cover with vessel crane or lifting bags and place cover onseabed adjacent to VASP Igloo and clear of any pipelines. Disconnect crane or deflate lift bags. SeeFig 3 for typical slinging arrangement.

WARNING: IF LIFTING BAGS ARE USED, HOLD BACK STROPS MUST BE ATTACHEDPRIOR TO INFLATION OF LIFT BAGS TO PREVENT ACCIDENTAL BLOW UP

AND POSSIBLE UNCONTROLLED ASCENT OF COVER.

3.3.2 Removal of End Covers - Approximate weight in air 6.5 Tonne

Diver to visually inspect the 4 extension horn lifting points on each cover for damage prior to attachingthe lifting strop. (Fig 2). The Lifting Strop:

1 x Four-leg sling complete with frame type link made up as follows: 3/4 inch - 6 x 19 galvanised IWRCslings 5m long. Each leg tested to 3.25T SWL. Hard eyes both ends each leg. 6.5T SWL G2150shackles at free ends. 8 x Crosby type G2150 bolt type anchor shackles.

Identify the southern end cover, which is situated over the ball valve and actuator assembly.

Disconnect the holding down strops on the Southern end cover, See Figs 4 and 5. Check that thereare no other obstructions to the lifting of the end cover.

The end cover is lifted with the two sling legs nearest the centre of the VASP having two extra Crosbytype G2150 bolt type anchor shackles on each leg. This arrangement is designed so they become 2inch to make cover sit level.

Attach lifting strop and remove southern end cover with vessel crane or lift ing bags and place cover onseabed adjacent to VASP and clear of any pipelines. Disconnect crane or deflate lift bags. See Fig 3for typical slinging arrangement. Repeat the above steps for the northern end cover.

On completion of cover removal diver is to disconnect the ends of the safety strops, coil back and stowthem out of the way. See Fig 5.

Note: ROV to monitor and video record the cover removal operations.

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3.4 Internal Survey (VD-DIV / VD-ROV)

When a diver enters the VASP Igloo, a second diver must remain at the entrance and act as tender.

On gaining entry to the interior of the VASP the diver or ROV, as access allows, will carry out and fullyvideo record, a general visual survey of the VASP installation and internal walls of the Igloo.


(1) Pipework. All pipe work for corrosion and leaks. Particular attention is to be given to the threepipe guides supports paying particular attention to any evidence of pipe movement through theguide and any corrosion.

(2) 36 inch Check Valve. Inspect the various vent connection on the body of the 36-inch checkvalve for any evidence of gas leaks (CH-VLV / CH-LKS).

Note: An injection clamp and cylinder from a previous operation have been left in place onvent connection 7C. Under no circumstances is the diver to interfere with this assembly.

(Date of installation 1984).

(3) 4 inch Ball Valve Assembly. Inspect for any evidence of gas leaks(CH-VLV / CH-LKS).

(4) 36 inch Ball Valve. Inspect for any evidence of gas leaks (CH-VLV / CH-LKS).

(5) Hoses. Inspect any hydraulic hoses, paying particular attention to the end fittings and hoseends for evidence of deterioration.

CAUTION: IN THE EVENT OF A LEAK BEING DISCOVERED, IF DEEMED SAFE TO DO SO AN INSPECTION SHOULD BE CARRIED OUT TO IDENTIFY THE LEAK SOURCE,THE RATE OF LEAKAGE AND DAMAGE ASSOCIATED WITH THE LEAK. IFUNSAFE, DIVERS ARE TO BE RECOVERED, WITH THE SURVEY CARRIED OUT

BY ROV IF POSSIBLE.

ALL LEAKS ARE TO BE TREATED AS 'C1' ANOMALIES AND IMMEDIATELYREPORTED TO THE SHELL OFFSHORE REPRESENTATIVE.

(6) ANODES. Carry out an anode inspection (VI-AW) of the anodes, which are located on thesidewall panels, under the roof panels, on the igloo/manifold sub-frame and on the pipelinemanifold(VI-AW). The inspection is to record the following:

(a) The presence and location of the anodes are to be confirmed as per as-built layoutdrawings and are to be confirmed as specified. Give an estimated average range of theanode wastage.

Not all anodes are expected to be identified. The survey is to confirm all pipeworkrelated anodes. The presence of structure anodes is to be confirmed as best apossible, confirming that there are no obvious missing or severely depleted anodes.

(b) Describe marine growth as hard or soft, giving estimated thickness and percentagecover of each anode.

(c) The integrity of the anode support (bracket, bracelet, earthing strap) is to be checked.

(d) Estimate percentage wastage on each anode using one of the following categories:

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(7) CP Readings. Proximity readings are the preferred method. Contact readings are only to betaken where a suitable proximity system is not available. Refer to the workscope for qualificationon the method to use, and if in doubt refer to the Shell Offshore Representative for advice,based on recommendations from the relevant Sponsoring Engineer (CP-PRX).

Where Reference Proximity readings are taken, an initial contact reading is required. Allsubsequent readings are to be proximity, unless doubts exist as to the electrical continuity of thelocations of the subsequent readings.

During the internal survey of the VASP, should significant areas of bare metal or corrosion benoted, CP readings are to be taken and recorded. Where these areas occur, readings to berestricted to one CP per component.

In addition, CP readings are to be taken on two vertical (including diagonals) and two horizontaltubulars.

Positions of any bare metal, tubular and pipework CP readings obtained are to be clearly shownon structural drawings.

(8) The diver is to take CP (CP-CON) readings and UT (WT-DIG) wall thickness measurements atfour locations on the underside of the 36-inch pipeline. See Fig 6 for positions. Paint coating isnot to be removed for UT Wall Thickness measurements and areas where readings are takenare to be permanently marked.

(9) On completion of all internal inspection work the top covers are to be replaced in reverse orderto removal procedure ensuring all hold down strops are correctly reinstalled (CN-RPL).

Note: ROV to monitor and video record the cover replacement operation.

(10) Prior to leaving location the ROV will carry out and fully video record, a general visual survey ofthe VASP paying particular attention to the final placement of top covers and fit up.


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4 REPORTING

4.1 Final Report



CP and UT readings obtained at the four designated locations, and measurement ‘X’ are to beincluded on the drawing fig.6.

Maximum and minimum range for all other CP readings taken are to be stated, with the readings andtheir locations clearly shown on structural drawings.

The average anode wastage range estimate for all anodes is to be included.


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KEY PLAN

SECTIONAL ELEVATION

END VIEW ELEVATION

A B C D E

AA B C D E

1

2

14.6m4.26m

2 1

( PROTECTIVE CANOPY OMITTED ) ( PROTECTIVE CANOPY OMITTED )

HINGEDPANEL

ST. FERGUS

REMOVABLE COVER PLATES( 3 PANELS )

VALVE SPINDLE 36" CHECK VALVE

HINGEDPANEL

BRENT 'A'

4" BALL VALVE

36" BALL VALVEAND ACTUATOR

Figure 1 VASP - General Arrangements

Am 01 05/05 I 90 001Page 9 of 14



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PLAN VIEW

OUTER CORNER OF

END COVER

HORN

SHACKLE

ENSURE HORN

IS NOT BENT

ABOVE THIS

LEVEL

GUIDE CONE

DIMENSION +/- 0.5O

ELEVATION VIEW

Figure 2 Removable Cover Lif ting Point - Typical

I 90 001 Am 01 05/05Page 10 of 14



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HINGED ACCESS PANELS

NOTECENTRE PANEL HAS TOBE REMOVED BEFOREEITHER END PANEL.

END COVER

END COVER

CENTRECOVER

NOTEEXTENSION HORNSWHICH PROJECT UNDERTHE CENTRE COVER.SEE DETAIL 'A'FOR TYPICAL HORN

Detail 'A'

A

Figure 3 Slinging Arrangement Central Cover - Typical

Am 01 05/05 I 90 001Page 11 of 14



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I 90 001 Am 01 05/05Page 12 of 14

CENTRE COVER

COVER

LOCATING

STROPS

EXISTING

OUTER HORN

FOR DETAIL

SEE FIGURE 6

AA

ROOF PANEL

SAFETY

STROPS

PROTECTION

APRONCOVER

LOCATING

STROPS

SECTION ELEVATION IN DIRECTION A-A

PLAN VIEW

INNER HORN

Figure 4 Plan and Section Elevation of VASP



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3 " x 3 " ANODE

COVER

1.5 " DIA. HOLE

1 " PLATE

COVER LOCATING

TO CORRESPONDING

PADEYE ON OTHER

SIDE OF VASP SECTION

SAFETY STROP

MOUSE HARD EYE

TO SHACKLE IN

THIS POSITION

5.65 " 1 ' 10 "

INSERT EXTRA SHACKLE

HERE IF REQUIRED

TOP BEAM OF

PROTECTION APRON

2.5 "

2.5 "

COVER PADEYE

1.125 " DIA. HOLE

2.5 " RAD. CENTRE PLATE EDGE

4.25 " PLATE

Figure 5 Detail of Shackle Arrangement and Padeye on Protection Apro

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Figure 6 Location of Inspection Areas

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0153-001

PROCEDURE I 90 002

PIPELINE DAMAGE INSPECTION

CONTENTS

Para Page

1 INTRODUCTION 3

2 TASKS 3




3.2 Pre-Inspect ion (VI-ROV) 3

3.3

Damage Inspection (PI-DAM) 4

3.3.1 No Bare Metal Exposed 4

3.3.2 No Metal Loss 4

3.3.3 Pipe Grooved 5

3.4 Final Survey 5

4 REPORTING 5

4.1 Final Report 5

FIGURES

Figure Page

1 Damaged Area Markings - Typical 7

2 Dimensional Survey - No Metal Damage 7

3 Dimensional Survey - of Damaged Metal 8

4 Ultrasonic Measurements on Bare Metal/Grooved Areas - Typical 8

5 Ultrasonic Measurement Positions on Groove - Typical 9

6 Blank Pipeline Datasheet 117 Example Completed Pipeline Datasheet 13

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PROCEDURE I 90 002

PIPELINE DAMAGE INSPECTION

1 INTRODUCTION

The work method is to be applied to the detailed inspection of a damaged area on a submarinepipeline caused by impact, anchor wires, anchors, trawl boards, etc. The work will include Cathodicpotential (CP) measurements, cleaning, UT wall thickness measurements, dimensional survey, videosurvey and Digital Still Images.

Inspection methods under the following procedures may be employed in conjunction with thisprocedure.

I 15 001 – Weld Inspection

I 15 002 – Ultrasonic Inspection – General

I 60 004 – Cathodic Protection Monitoring

2 TASKS

2.1 Standard Tasks


PI-DAM - Bare Metal Incident



Any number or combination of the listed work tasks, or those listed under Procedure I 15 001 andI 15 002, may be used or called for on the workscope or during the course of the inspection.




3.2 Pre-Inspect ion (VI-ROV)

Prior to starting the inspection, the ROV (or diver) is to ensure that the incident has been correctlyidentified as indicated in the workscope. Should investigation of the incident site identify no damage asdetailed in the procedure, then it should be considered that the inspection is being undertaken at anincorrect location.

If this occurs, a ten (10)-metre search either side of the reported location should be undertaken tolocate the correct damage incident. In addition, a second independent check should be carried outusing the vessel positioning system.

The workscope may identify the distance between the incident and nearest pipeline feature i.e. field

joint or anode. This distance should also be checked to confirm that the correct incident has beenlocated.

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If any doubt exists, or where in close proximity to another similar defect, the problem should bereferred to the Shell Offshore Representative for clarification.

3.3 Damage Inspection (PI-DAM)

On completion of the pre-inspection, the ROV will carry out an initial general visual inspection of the

defect area, recorded on video (VD-ROV), viewing both sides of the pipeline. This inspection is not tobe restricted to the localised area of damage, but will cover an area sufficient to highlight the area ofdamage, any items of debris, and/or any other item, which may have caused the damage.

Where field joints are present, the inspection is to show the anomaly relative to the two end field jointson the pipe section that the damage is located, and/or any other pertinent fixed reference point, i.e.anode. The survey is to reference the direction of associated installations.

The confirmed position of the incident, and any other items of note i.e. field joint, anode and debris,are to be position fixed. These fixes are to be recorded on video. Where taken by ROV the fix positionis to be displayed on the video overlay in Eastings and Northings.

At least two contact CP readings are to be taken on the incident prior to any cleaning by either ROV or

diver. Calibration data is to be noted and verified before and after each dive and before each set ofreadings. Refer to Standard Procedure I 60 004 for taking CP measurements, point 3.4.

The incident is to be cleaned either by ROV water jet, or by diver with wire brush and scraper.

If bare metal is present it must be established if there has been metal loss, i.e. grooved pipe.

The following gives the three methods of inspection to be conducted, dependant on the extent ofdamage encountered.

3.3.1 No Bare Metal Exposed

Mark the damaged area with the four cardinal clock positions with the 6 o'clock position being thedownstream side of the damage as shown in Figure 1.

Carry out a dimensional survey of the damaged area. Record the following dimensions as shown inFigure 2.

(1) Length and breadth of the damaged concrete weight coat.

(2) Length and breadth of exposed bitumen.

3.3.2 No Metal Loss

If the pipeline surface is scored but there is no visible groove(s) in the marked area, carry out the

following measurements in addition to those measurements in 3.3.1 above. Dimensions to berecorded as shown in Figure 3.

(1) Length and breadth of exposed bare metal.

(2) Length and breadth of any damaged metal. If there is more than one damaged area within theincident, record the overall dimensions of the damage.

(3) Length and breadth of damaged area(s) measured along the axis of the damage.

(4) Take wall thickness readings on the scored area. Readings should be taken at intervals of 20%of the length of the scored area (See Figure 4). For example, if the scored area is 200mm long,measured along the axis of the score, then take readings every 40mm. The frequency should be

increased if low readings are obtained. At least four further readings should be obtained onundamaged metal.

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Where dimensions have been taken by ROV, the method employed and levels of accuracy expectedof the survey, are to be fully documented in the final report.

Maximum and minimum range for all CP readings taken are to be stated.

Other references are to be made to any digital still images, drawings and Pipeline Fix Data Sheets

included in the report.

Raise an anomaly for the defect as found. Anomaly to highlight the results found, making reference tothe report. A C1 anomaly is based on a WT loss ≥ 20% WT loss, or for any other significant integrityissue. See Anomaly Criteria, Section 2, Chapter 6, Section 2.3.

All data is to be recorded on a Pipeline Datasheet, including a suitable sketch of the damaged area.

For the pipeline datasheet, WT reading locations entered are to be numbered 0 upwards. Along thelength of the pipe, 0 is to be upstream (12 o’clock). Across the breadth of the pipe, 0 is to the left (9o’clock) looking upstream.

See Figures 1 and 5, and Pipeline Datasheets Figures 6 and 7.

The Pipeline Datasheet (Figure 6) is to be completed and included in the results section of the report,along with suitable schematic dimensional drawings to include details required as indicated in Figures1 to 5.

An example of a completed Pipeline Datasheet, including defect sketch are shown in Figure 7. Additional sketch boxes, measurement boxes, LAM / Pit Gauge boxes to be added to the examplePipeline Datasheets to suit. The data does not have to be restricted to the 1 page shown.

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Figure 1 Damaged Area Markings - Typical

Figure 2 Dimensional Survey - No Metal Damage

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Figure 3 Dimensional Survey - of Damaged Metal

Figure 4 Ultrasonic Measurements on Bare Metal/Grooved Areas - Typical

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Figure 5 Ultrasonic Measurement Posit ions on Groove – Typical

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Figure 6 Blank Pipeline Timesheet

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Figure 7 Example Completed Pipeline Datasheet

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PROCEDURE I 91 001

IGLOO INSPECTION – FULMAR TEE SKID

CONTENTS

Para Page

1 INTRODUCTION 3

2 TASK OPTIONS 3

2.1 External 3

2.2 Internal 3



3.1

Inspection Qualifications 4

3.2 Location Confirmation 4

3.3 External Survey (VD-ROV) 4


4 OPTIONS 7

4.1 Wall Thickness Readings (WT-DIG) 7

5 REPORTING 7

5.1 Final Report 7

FIGURES

Figure Page

1 Fulmar Tee Skid Igloo Field Layout 8

2 Tee Skid Plan Arrangement 9

3 GA of Tee Piece Skid Frame 10

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PROCEDURE I 91 001

IGLOO INSPECTION - FULMAR TEE SKID

1 INTRODUCTION

The work method is to be applied to the external and internal inspection of the Fulmar Tee Skid Iglooon the 16 inch Fulmar AD to new SALM Base Oil Loading Pipeline. The work will include damagesurvey, scour survey, leak monitoring, anode survey and video survey.

The Fulmar Tee Skid Igloo is situated at KP 2.238 on the 16 inch Fulmar AD to new SALM Base OilLoading Pipeline, at position E631260 N626101 (Pipeline Code N0307, IBIS Incident No. 426,COABIS Code IGL19/220-001). (See Figure 1)

Inspection methods under the following procedures may be employed in conjunction with thisprocedure.

I 15 002 – Ultrasonic Inspection – General

I 60 004 – Cathodic Protection Monitoring

2 TASK OPTIONS

2.1 External


VD-ROV - General ROV




2.2 Internal







CP-PRX - Contact Measurements

2.3 Optional Tasks

The following work tasks are optional and will be explicitly called for in the Workscope, or as a result of

finding an anomaly.

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(6) Scour around the base of the structure. Note: There are specific anomaly criteria with respect toigloo scour. See Section 2, Chapter 6, Point 2.3.12. (DM-SCR).


(8) General views are required of the approaches of each pipeline out to 5m from the Tee-Skid, or

to the start of protection mattresses, which ever is the lesser. The survey is to confirm thepresence and integrity of any supports, protection bags/mats or point of burial. Comment on anypipeline anodes seen within this region.



The internal survey may be conducted by either diver or ROV.

Original steel panels have been removed and not replaced. Diver access is possible through the openpipework protection structure.

When a diver enters the igloo, a second diver must remain at the entrance and act as tender.

On gaining entry to the interior of the igloo the diver or ROV, as access allows, will carry out and fullyvideo record, a general visual survey of the Tee Skid Igloo installation and internal framework of theigloo. The purpose of this survey is to record the following:

(1) Pipework . All pipe work for corrosion and leaks. Particular attention is to be given to the pipeguides and clamps with any evidence of pipe movement to be reported. Pipework schematicsare shown on Figures 2 & 3.

(2) Valves. Each of the four 16 inch and two 2 inch valves, as shown on Figure 3, are to be visuallyinspected. Any leaks or evidence of leaks are to be reported.

Where visible, all valve positions are to be noted on video. However, these are not required to

be recorded in the job Completion Report.

(3) Flanges . Each of the twelve flanges are to be visually inspected. Any leaks or evidence of leaksis to be reported. All blind flanges are to be similarly checked.

CAUTION: IN THE EVENT OF A LEAK BEING DISCOVERED, DIVERS SHOULD BE

WITHDRAWN FROM THE AREA AND AN ROV INSPECTION SHOULD BE

CARRIED OUT TO IDENTIFY THE LEAK SOURCE, THE RATE OF LEAKAGE

AND DAMAGE ASSOCIATED WITH THE LEAK. ALL LEAKS ARE TO BE

TREATED AS 'C1' ANOMALIES AND IMMEDIATELY REPORTED TO THE

SHELL OFFSHORE REPRESENTATIVE.

(4) Igloo Framework. Inspect the protection structure for evidence of damage and corrosion.Inspect the igloo to Tee Skid securing clamps for any evidence of movement and security.

(5) Anodes. Carry out an inspection of the anodes (VI-AW) that are located on the igloo subframeand on the Tee Skid. The inspection is to record the following:

(a) The presence and location of the anodes are to be confirmed as per as-built layoutdrawings, and are to be confirmed as specified. Give an estimated average range of theanode wastage.

Not all anodes are expected to be identified. The survey is to confirm all pipework

related anodes. The presence of structure anodes is to be confirmed as best a possible,confirming that there are no obvious missing or severely depleted anodes.

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(b) Describe marine growth as hard or soft, giving estimated thickness and percentage coverof each anode.








(6) CP Readings. Proximity readings (CP-PRX) are the preferred method. Contact readings areonly to be taken where a suitable proximity system is not available. Refer to the workscope forqualification on the method to use, and if in doubt refer to the Shell Offshore Representative foradvice, based on recommendations from the relevant Sponsoring Engineer.

Where Reference Proximity readings are taken, an initial contact reading is required. Allsubsequent readings are to be proximity, unless doubts exist as to the electrical continuity ofthe locations of the subsequent readings.

During the internal survey of the Tee-Skid, should significant areas of bare metal or corrosionbe noted, CP readings are to be taken and recorded. Where these areas occur, readings to berestricted to one CP per component.

Where no areas of bare metal are evident, or where the inspection is to be conducted by ROV,one CP reading is required on a typical area of major pipework (preferably a flange) and avalve. Locations of these readings are to be recorded, and used for repeat readings in futureyears.

In addition, CP readings are to be taken on two vertical (including diagonals) and two horizontaltubulars. With respect to igloo inspection by ROV, where the internal framework is the same asthe external framework, these readings are not required, as they have been covered by theCP’s taken as part of the external survey.

Positions of bare metal, pipework and framework CP readings obtained are to be clearly shownon structural drawings.

(7) Prior to leaving location the ROV will carry out, and fully video record, a general visual survey ofthe igloo, confirming that all diver equipment has been removed.

Digital Still Images (PH-DIG) are to be taken of any anomalies or other areas of interest. These may


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4 OPTIONS

4.1 Wall Thickness Readings (WT-DIG)

Wall thickness (WT) readings may be requested on specific areas of pipework to check for internalcorrosion/erosion. The location, extent and areas of readings to be taken will be specified in the

workscope.

Method for taking WT readings are as per the standard procedure I-15-002, Point 3.3.

5 REPORTING

5.1 Final Report


All anomalies are to be referenced, with a general statement made concerning the types and extent ofanomalies identified. Any C1 anomalies are to be commented on more specifically. Other references

are to be made to any digital still images and drawings.




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Figure 2 Tee Skid Plan Arrangement

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Figure 3 GA of Tee Piece Skid Frame



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PROCEDURE I 91 002

SUBSEA INTERVENTION VALVE (SSIV) INSPECTIONNORTHERN BUSINESS UNIT

CONTENTS

Para. Page

1 INTRODUCTION 3

2 TASK OPTIONS 3

2.1 External 3

2.2 Internal 3





3.3

External Survey (Reference Figs 2, 3 & 4) 4

3.4 Hinged Access Panel ‘D’ - Approximate Weight in Air 3360 kg (CN-RPL) 5


3.5.1 Brent A SSIV Igloo 6

3.5.2 Cormorant A SSIV Igloo 8

3.5.3 North Cormorant SSIV Igloo 10

4 OPTIONS 12


5 REPORTING 12

5.1 Final Report 12

FIGURES

No Page

1 SSIV Field Location 13

2 General Layout of Brent A SSIV Igloo 14

3 General Layout of Cormorant A SSIV Igloo 15

4 General Layout of North Cormorant SSIV Igloo 16

5 Hinged Access Panel - General Arrangements 17

6 Brent A SSIV Igloo - Piping Schematic and Valves 18

7 Cormorant A SSIV Igloo - Piping Schematic and Valves 19

8 North Cormorant SSIV Igloo - Piping Schematic and Valves 20

9

SSIV Assembly Anode Locations – Typical 21 10 Subsea Control Skid – General Arrangements 22

11 Subsea Control Skid – General Arrangements 23

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PROCEDURE I 91 002

SUBSEA INTERVENTION VALVE (SSIV) INSPECTIONNORTHERN BUSINESS UNITS

1 INTRODUCTION

The work method is to be applied to the external and internal inspection of Subsea InterventionValves (SSIV). The work will include damage survey; scour survey, pipeline movement monitoring,leak monitoring, Cathodic potential (CP) measurements, anode survey and video survey.

The Brent A SSIV is situated at KP 41.176 on the 16 inch Cormorant A to Brent A (Western Leg,WELGAS) gas pipeline, (Pipeline/COABIS Code N0601 (IGL09), IBIS Incident No. 13) at positionE591893 N6767949.

The Cormorant A SSIV is situated at KP 0.404 on the 16 inch Cormorant A to Brent A (Western Leg,WELGAS) gas pipeline, (Pipeline/COABIS Code N0601 (IGL10), IBIS Incident No. 14) at positionE557834 N6774448.

The North Cormorant SSIV is situated at KP 0.225 on the 10-inch North Cormorant to Western Leggas pipeline, (Pipeline/COABIS Code N0602 (IGL01), IBIS Incident No. 5) at positionE561938 N6790157.

NDT methods under Procedure I 15 001 may be employed in conjunction with this procedure.

2 TASK OPTIONS

2.1 External






2.2 Internal




VI-AW - - Anode Wastage Measurement




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2.3 Optional Tasks

The following work tasks are optional and will be explicitly called for in the Workscope, or as a resultof finding an anomaly.



Any number or combination of the listed work tasks, or those listed under Procedure I 15 002 andI 90 002, may be used or called for on the workscope or during the course of the inspection.





3.2 External Survey (VD-ROV)

Survey data, including the position of the igloo/manifold to be inspected, will be provided by the ShellSurvey department prior to commencement of operations. All survey data shall be based onInternational Spheroid, European Datum 1950 (ED50), Transverse Mercator Projection. For UKSector Central Meridian is 0 deg and for Dutch Sector Central Meridian is 5deg E. Reference Section1, Chapter 2, Figure 1, for further datum shift parameters.

On arrival at the worksite, it should be established that the correct structure has been identified, by

use of suitable markings on the SSIV itself, or by use of the Shell survey data provided, and/or fieldlayout drawings to provide other suitable means of confirmation. The Shell Offshore Representative isto be consulted should no markings be present, and the latter method is used to confirm that thecorrect structure has been identified.

If doubt persists as to the correct identification of the igloo/manifold, then a positional fix is to be takenof the as-built fix co-ordinate position, which may not be the centre of the igloo/manifold. Should thisfix disagree with the workscope stated position by more than +/-5m, then initiate checks to resolveerrors. Such checks should confirm that the vessel's positioning system has been suitably calibrated.

3.3 External Survey (Reference Figs 2, 3 & 4)

The ROV will carry out, and fully video record, a general visual survey of the igloo installation location.


(1) An overall view of the Igloo/manifold (use of SIT camera) from all sides. This survey is to checkfor any gross damage or debris, and to confirm the area is safe for diver intervention. Results ofthis survey to be relayed to the dive supervisor. (VI-ROV)


(2) Structure for any evidence of impact damage. Check for leaks.

(3) Loose or displaced panels paying particular attention to the seating of panels at the roofinterface. Check all hinges.


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(5) Anode condition if visible.

(6) The entry and exit of the pipelines and umbilical to the structure, for any evidence of movementor door settlement.

(7) Check the external umbilical anchor points (Figs2, 3 & 4).

(8) Scour around the base of the structure. Note: There are specific anomaly criteria with respectto igloo/manifold scour. See Section 2, Chapter 6, Point 2.3.12.

(9) Debris.



3.4 Hinged Access Panel ‘D’ - Approximate Weight in Air 3360 kg (CN-RPL)

It is possible for divers to enter all three igloos, and possibly small ROV’s, through the umbilicalaccess port. If however at the discretion of the divers, dive supervisor or ROV supervisor that thispractice is unsafe it will be necessary for the hinged access door panel on the roof of the igloo to beopened. Typical door positions as shown on Fig 5.

WARNING: PRIOR TO ATTEMPTING TO OPEN THE HINGED ACCESS PANEL DOOR, ACLOSE VISUAL AND ELECTROMAGNETIC INSPECTION OF ALL PADEYES ONTHE DOOR AND AS NECESSARY FOR TIRFOR AND TIE BACK ATTACHMENTIS TO BE CARRIED OUT. SHOULD THE INSPECTION REVEAL ANYANOMALIES OR DAMAGE THEN THE PADEYE IS NOT TO BE USED. VISUALLYINSPECT BOTH HINGE ARRANGEMENTS FOR SECURITY, PAYING

PARTICULAR ATTENTION TO THE ‘U’ BOLT FASTENINGS. RE-TIGHTEN ALLBOLTS AS NECESSARY. SHOULD THERE BE EVIDENCE OF DAMAGE TO THEHINGE ARRANGEMENT, CARRY OUT A CLOSE VISUAL ANDELECTROMAGNETIC INSPECTION.

On completion of the padeye and hinge inspection the diver is to open the hinged access door panelusing the following method:

(1) Install two Tirfor (T516) between the padeyes on the hinged panel (opposite side to the hinges)and padeyes on panel C (refer to Fig 5).

(2) Using 2000 kg webbing strops, choked around hinged panel frame members, attach two 500 kg

lifting bags on the hinged panel (refer to Fig 5). Inflate the bags slowly until the panel opens.

(3) When the hinged panel is open and vertical, tighten the Tirfors to pull panel past the verticaland secure. Slowly deflate bags and lower door to lay flat on top of igloo panel C.

NOTE: ROV to monitor and video record the door opening operation.



NOTE: Divers and ROV to take care of hydraulic hoses when manoeuvring inside the igloo, asdamage has been caused in the past, resulting in shutting in of the SSIV.

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3.5.1 Brent A SSIV Igloo

(Pipeline/COABIS Code N0601 (IGL09), IBIS Incident No. 13)

In the past diver access has been gained to the igloo through the Control Umbilical opening, on thenorth side of the igloo.

On gaining entry to the interior of the igloo the diver or ROV, as access allows, will carry out and fullyvideo record, a general visual survey of the manifold installation and internal walls of the igloo. Thepurpose of this survey is to record the following:

(1) PIPEWORK. All pipe work for corrosion and leaks. Particular attention is to be given to the pipeguides and clamps with any evidence of pipe movement to be reported. Pipework schematic isshown on Fig 6.

(2) VALVES. All valves (16 off, See fig.6) are to be visually inspected. Any leaks or evidence ofleaks is to be reported (CH-VLV). Where visible, all valve positions are to be noted on video.These however are not required to be recorded in the job Completion Report.

(3) ACCUMULATOR MODULES. Each of the three accumulator modules as shown on Figs 10and 11 are to be visually inspected. Any leaks or evidence of leaks is to be reported. Check forcontinuity straps.

(4) CONTROL MODULE. The Control Module as shown on Figs 10 and 11 is to be visuallyinspected. Any leaks or evidence of leaks is to be reported. Check for continuity straps.

(5) HYDRAULIC DISTRIBUTION MANIFOLDS. Each of the three hydraulic distribution manifoldsas shown on Fig 11 are to be visually inspected. Any leaks or evidence of leaks are to bereported. Check connection points, condition of hoses i.e. blistering and cracking and forgeneral deterioration. Check for continuity straps.

(6) UMBILICAL TERMINATION MODULE. The Umbilical Termination Module as shown in Fig 10

is to be visually inspected. Any leaks or evidence of leaks is to be reported. The module’ssupport cradle is to be checked for security, as is the umbilical support ramp, bend restrictorand attachments. Check for continuity straps.

(7) HYDRAULIC HOSES. All hydraulic hoses are to be inspected, paying particular attention to theend fittings and hose ends for evidence of deterioration. These have failed in the past.

(8) FLANGES. Each of the flanges as shown in Fig 6 are to be visually inspected. Any leaks orevidence of leaks is to be reported.

CAUTION: IN THE EVENT OF A LEAK BEING DISCOVERED, IF DEEMED SAFE TO DO SOAN INSPECTION SHOULD BE CARRIED OUT TO IDENTIFY THE LEAK SOURCE,

THE RATE OF LEAKAGE AND DAMAGE ASSOCIATED WITH THE LEAK. IFUNSAFE, DIVERS ARE TO BE RECOVERED, WITH THE SURVEY CARRIED OUTBY ROV IF POSSIBLE.


(9) ANODES. Carry out an anode inspection (VI-AW) of the anodes, which are located on thesidewall panels, under the roof panels, on the igloo/manifold sub-frame and on the pipelinemanifold (VI-AW). The inspection is to record the following:

(a) The presence and location of the anodes are to be confirmed as per as-built layoutdrawings and are to be confirmed as specified. Give an estimated average range of the

anode wastage.

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Not all anodes are expected to be identified. The survey is to confirm all pipework relatedanodes. The presence of structure anodes is to be confirmed as best a possible, confirmingthat there are no obvious missing or severely depleted anodes.









(10) CP READINGS. Proximity readings are the preferred method. Contact readings are only to betaken where a suitable proximity system is not available. Refer to the workscope forqualification on the method to use, and if in doubt refer to the Shell Offshore Representative for

advice, based on recommendations from the relevant Sponsoring Engineer (CP-PRX).


During the internal survey of the igloo/manifold, should significant areas of bare metal orcorrosion be noted, CP readings are to be taken and recorded. Where these areas occur,readings to be restricted to one CP per component.

Where no areas of bare metal are evident, or where the inspection is to be conducted by ROV,one CP reading is required on a typical area of major pipework (preferably a flange) and avalve. Locations of these readings are to be recorded, and used for repeat readings in future

years.

In addition, CP readings are to be taken on two vertical (including diagonals) and two horizontaltubulars. With respect to manifold inspection by ROV, where the internal framework is the sameas the external framework, these readings are not required, as they have been covered by theCP’s taken as part of the external survey.

Positions of bare metal, tubular and pipework CP readings obtained are to be clearly shown onstructural drawings.

(11) On completion of all internal inspection work the hinged access panel is to be closed in reverseorder to opening procedure. Ensure all diving umbilicals and ROV tether cable are clear of thepanel before closing (CN-RPL).

NOTE: ROV to monitor and video record the panel closing operation.

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(12) Prior to leaving location the ROV will carry out, and fully video record, a general visual surveyof the igloo, paying particular attention to the final placement of top panels and fit up.

Digital Still Images (PH-DIG) are to be taken of any anomalies or other areas of interest. Thesemay be supplemented by suitable drawings to show the location, size and details of the item ofinterest.

3.5.2 Cormorant A SSIV Igloo


In the past diver access has been gained to the igloo through the Control Umbilical opening, on thewest side of the igloo.


(1) PIPEWORK. All pipe work for corrosion and leaks. Particular attention is to be given to the pipe

guides and clamps with any evidence of pipe movement to be reported. Pipework schematic isshown on Fig 7.




(5) HYDRAULIC DISTRIBUTION MANIFOLDS. Each of the three hydraulic distribution manifoldsas shown on Fig 11 are to be visually inspected. Any leaks or evidence of leaks are to bereported. Check connection points, condition of hoses i.e. blistering and cracking and forgeneral deterioration. Check for continuity straps.

(6) UMBILICAL TERMINATION MODULE. The Umbilical Termination Module as shown in Fig 10is to be visually inspected. Any leaks or evidence of leaks is to be reported. The module’ssupport cradle is to be checked for security, as is the umbilical support ramp, bend restrictorand attachments. Check for continuity straps.



CAUTION: IN THE EVENT OF A LEAK BEING DISCOVERED, IF DEEMED SAFE TO DO SOAN INSPECTION SHOULD BE CARRIED OUT TO IDENTIFY THE LEAK SOURCE,THE RATE OF LEAKAGE AND DAMAGE ASSOCIATED WITH THE LEAK. IFUNSAFE, DIVERS ARE TO BE RECOVERED, WITH THE SURVEY CARRIED OUTBY ROV IF POSSIBLE.


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(a) The presence and location of the anodes are to be confirmed as per as-built layoutdrawings and are to be confirmed as specified. Give an estimated average range of the

anode wastage.

(b) Not all anodes are expected to be identified. The survey is to confirm all pipeworkrelated anodes. The presence of structure anodes is to be confirmed as best a possible,confirming that there are no obvious missing or severely depleted anodes.

(c) Describe marine growth as hard or soft, giving estimated thickness and percentage coverof each anode.

(d) The integrity of the anode support (bracket, bracelet, earthing strap) is to be checked.

(e) Estimate percentage wastage on each anode using one of the following categories:






(10) CP READINGS. Proximity readings are the preferred method. Contact readings are only to betaken where a suitable proximity system is not available. Refer to the workscope forqualification on the method to use, and if in doubt refer to the Shell Offshore Representative foradvice, based on recommendations from the relevant Sponsoring Engineer (CP-PRX).




In addition, CP readings are to be taken on two vertical (including diagonals) and two horizontaltubulars. With respect to manifold inspection by ROV, where the internal framework is the sameas the external framework, these readings are not required, as they have been covered by the

CP’s taken as part of the external survey.

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Digital Still Images (PH-DIG) are to be taken of any anomalies or other areas of interest. Thesemay be supplemented by suitable drawings to show the location, size and details of the item ofinterest.

3.5.3 North Cormorant SSIV Igloo


In the past diver access has been gained to the igloo through the Control Umbilical opening, on thenorth side of the igloo.


(1) PIPEWORK. All pipe work for corrosion and leaks. Particular attention is to be given to the pipeguides and clamps with any evidence of pipe movement to be reported. Pipework schematic isshown on Fig 8.




(5) HYDRAULIC DISTRIBUTION MANIFOLDS. Each of the three hydraulic distribution manifoldsas shown on Fig 11 are to be visually inspected. Any leaks or evidence of leaks are to be

reported. Check connection points, condition of hoses i.e. blistering and cracking and forgeneral deterioration. Check for continuity straps.

(6) UMBILICAL TERMINATION MODULE. The Umbilical Termination Module as shown in Fig 10is to be visually inspected. Any leaks or evidence of leaks is to be reported. The module’ssupport cradle is to be checked for security, as is the umbilical support ramp, bend restrictorand attachments. Check for continuity straps.



CAUTION: IN THE EVENT OF A LEAK BEING DISCOVERED, IF DEEMED SAFE TO DO SOAN INSPECTION SHOULD BE CARRIED OUT TO IDENTIFY THE LEAK SOURCE,

I 91 002 Am 01 05/05Page 10 of 23



0153-001

THE RATE OF LEAKAGE AND DAMAGE ASSOCIATED WITH THE LEAK. IFUNSAFE, DIVERS ARE TO BE RECOVERED, WITH THE SURVEY CARRIED OUTBY ROV IF POSSIBLE.




Not all anodes are expected to be identified. The survey is to confirm all pipeworkrelated anodes. The presence of structure anodes is to be confirmed as best a possible,confirming that there are no obvious missing or severely depleted anodes.





6-20% LOSS - ANODE IN GOOD CONDITION,

CORNERS ROUNDED, SLIGHT PITTING.




(10) CP READINGS. Proximity readings are the preferred method. Contact readings are only to be

taken where a suitable proximity system is not available. Refer to the workscope forqualification on the method to use, and if in doubt refer to the Shell Offshore Representative foradvice, based on recommendations from the relevant Sponsoring Engineer (CP-PRX).


If no bare metal areas are present, take one set of readings on both sides of a flange, and on atypical valve.

In addition, CP readings are to be taken on two vertical (including diagonals) and two horizontaltubulars. With respect to manifold inspection by ROV, where the internal framework is the same

as the external framework, these readings are not required, as they have been covered by theCP’s taken as part of the external survey.

Am 01 05/05 I 91 002Page 11 of 23



0153-001

Positions of bare metal and tubular CP readings obtained are to be clearly shown on structuraldrawings.





4 OPTIONS


Wall thickness (WT) readings may be requested on specific areas of pipework to check for internalcorrosion/erosion. The location, extent and areas of readings to be taken will be specified in theworkscope.

Method for taking WT readings are as per the standard procedure I-15-002.

5 REPORTING

5.1 Final Report






I 91 002 Am 01 05/05Page 12 of 23



0153-001

HEATHER

PROTECTION COVER

E561446

N6769400

WELGAS TEEIGLOO No.2

(8inch AND 10inch)

CORMORANT A

NORTH CORMORANT

10inch GAS LINE

BRENT A

WELGAS TEE

IGLOO No.1

NW HUTTON

NORTH

NINIAN

KEY:

WESTERN LEG GAS 16inch LINE

SPLITTER BOXIGLOO

SSIV IGLOOE591923N6767927

SSIV IGLOO

SSIV IGLOO

NORTH CENTRAL

(STRATHSPEY)

STRATHSPEYTIE-IN IGLOO

Figure 1 SSIV Field Location

Am 01 05/05 I 91 002Page 13 of 23



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9

1

2

1

9 6 7 8 9

1

2

1

9 5 4 3

B 1

B 2

A 2

A 1

A D A

C

A

A

A

A

U M B I L I C A L

A N C H O R P O I N T

T O B R E N T A

1 6 I N C H G A S P I P E L I N E

1 2 I N C H G A

S P I P E L I N E

F R O M S T R A T H S P E Y

T I E - I N I G L O

O

F R O M C O R M O R A

N T A

Figure 2 General Layout of Brent A SSIV Igloo

I 91 002 Am 01 05/05Page 14 of 23



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9

1

2

1

9 6 7 8 9

1

2

1

9 5 4 3

B 1

B 2

A 2

A 1

A D A

C

A

A

A

A

U M B I L I C A L

A N C H O R P O I N T

F R O M C O R M O R A

N T A

T O B R E N T A


Figure 3 General Layout of Cormorant A SSIV Igloo

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9

1

2

1

9 6 7 8 9

1

2

1

9 5 4 3

B 1

B 2

A 2

A 1

A D A

C

A

A

A

A

U M

B I L I C A L

A N C

H O R P O I N T

T O W E L G A S T E E

I G L O O N o 2


F R O M N O R T H C O R M O R A N T

Figure 4 General Layout of North Cormorant SSIV Igloo

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Figure 5 Hinged Access Panel - General Arrangements

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Figure 6 Brent A SSIV Igloo - Piping Schematic and Valves

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Figure 7 Cormorant A SSIV Igloo - Piping Schematic and Valves

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Figure 8 North Cormorant SSIV Igloo - Piping Schematic and Valves

I 91 002 Am 01 05/05Page 20 of 23



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PLAN OF SIDE PANELS(ANODE TYPE A)

A A A

A A A

BCD

ANODE TYPE A

ANODE TYPE B

120

220

150

ANODESQUANTITIES

TYPE A 44 OFFTYPE B 3 OFF

TYPE C 5 OFF

1640

1850

1620

VALVE SKID & SPOOL SKID

(ANODE TYPE C)2 NO. ARRANGEMENTS THUS

SSIV CONTROL SKID(ANODE TYPE C)

SUBSEA SUPPORTFRAME

(ANODE TYPE A)

PROTECTION HOUSING ROOF - PANELS(ANODE TYPES A & B)

PROTECTION HOUSING ROOF SUPPORT FRAME

(ANODE TYPE A)

1

2

1

2

BABA

1

2

1

2

B---

B---

A---

A---

B---

SECTION

(ANODE TYPE A)

A---

SECTION

(ANODE TYPE A)

ANODE TYPE C

Figure 9 SSIV Assembly Anode Locations – Typical

Am 01 05/05 I 91 002Page 21 of 23



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PLAN VIEW

SUBSEA

CONTROL

MODULE

ACCUM-

ULATOR

MODULENo 1

ACCUM-ULATOR

MODULE

No 3

ACCUM-ULATOR

MODULE

No 2

UMBILICALSUBSEA

TERMINATION

UMBILICAL

UMBILICALTERMINATION

TERMINATION

SUPPORTCRADLE

TIE-BACK BAR

BEND

RESTRICTOR

PADEYE

CONTROLUMBILICALSUPPORT RAMP

OUTER EDGEOF SIDE PANEL

ANCHORTECHPILE

UMBILICALTIEBACK

5

4

3A

B

A

1

2

A---A---

A---A---

B

PART ROOF PLAN SHOWINGUMBILICAL ANCHOR POINT

A BUMBILICAL SUBSEATERMINATIONCONTROLSKID

KEY PLAN

NOTE :FOR DETAILS OFCONTROL PANELS No's1, 2, 3 REFER TO FIG 11

(SIDE PANELS REMOVED)A---

SECTION

B

Figure 10 Subsea Control Skid – General Arrangements

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Am 01 05/05 I 91 002Page 23 of 23

OPEN CLOSE

ACTUATOR

ACC.

1

SCM.

ACC.

3

ACC.2

UST

06

PANEL 3

PANEL 1

PANEL (2B)

KEY PLANSUBSEA CONTROL SKID

RETURNFUTURE

SUPPLY

FUTURE

X OVER

SCM

DIRECT

SCM

BLEED

SCM

DIRECT

SUPPLYSPARE

PANEL 1 PANEL 3

FROM PANEL 1

RETURN

ACC 2

SUPPLY

VENT

FROM

PANEL 1

VENT

SUPPLYRETURN

RETURN

ACC 3

SUPPLY

VENT

VENT

SUPPLYRETURN

VENT

SPARE

SUPPLY

ACC 1

SPARE SUPPLY

PANEL 2(A)PANEL 2(B)

PANEL (2A)

Figure 11 Subsea Control Skid – General Arrangements



0153-001

PROCEDURE I 91 003

IGLOO INSPECTION – WELGAS NUMBER 1 AND 2

CONTENTS

Para Page

1 INTRODUCTION 3

2 TASK OPTIONS 3


2.1.1 External 3

2.1.2 Internal 3


3

OPERATING PROCEDURE AND SPECIFICATION 4



3.3 External Inspection (VD-ROV / VD-DIV) 4

3.4 Roof Access Doors (CN-RPL) 5

3.5 Internal Inspection (VD-DIV / VD-ROV) 6

4 REPORTING 8

4.1 Final Report 8

FIGURES

Figure Page

1 Igloo Field Location 9

2 WELGAS Tee Igloo No 2 (NCHIG) - General Layout 10

3 WELGAS Tee Igloo No 1 (NHUIG) - General Layout 11

4 External Anode Positions (both Igloos) 12

5 Location of External Valve and Control Panels 13

6 Typical Control Box Layout 14

7 WELGAS Igloo No 2 (NCHIG) Modif ied CBIE, CB2E Actuator /Control Box Jumper 15

8 Typical Arrangement for Valve Actuation of the WELGAS Igloo No 2 (NCHIG) ValvesUsing Diver Deployed Cross Over Panel 16

9 Igloo Door Positions and Lifting Points - Typical 17

10

Lifting Point Hole Dimensions 18

11 Lift ing Point General Arrangement 19

12 Rigging for Door Opening - Typical 20

13 WELGAS Igloo No 1 (NHUIG) – Pipework Schematic and Valve Status 21

14 WELGAS Igloo No 2 (NCHIG) – Pipework Schematic and Valve Status 22

15 Location of Jacks and CP Readings (both Igloos) 23

16 Location of CP Readings (both Igloos) 24

17 Location of Wall Thickness Readings (both Igloos) 25

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I 91 003 Am 03 04/06Page 2 of 25



0153-001

PROCEDURE I 91 003

IGLOO INSPECTION - WELGAS NUMBER 1 AND 2

1 INTRODUCTION

The work method is to be applied to the external and internal inspection of the two igloos on the 16inch Western Leg Gas Pipeline. The work will include damage survey, scour survey, pipelinemovement monitoring, leak monitoring, cathodic potential measurements, wall thickness readings,anode survey, video survey and photography.

Welgas igloo, number 1, is situated at KP 24.02 on the 16 inch Western Leg Gas Pipeline (UPISIncident No 798) at position E575699 N6763761. (Pipeline Code N0601, IBIS Incident No. 798,COABIS Code NHUIG, IGL11 / 220-001). (See figure 1).

Welgas igloo, number 2, is situated at KP7.171 on the 16 inch Western Leg Gas Pipeline (UPIS

Incident No 1034) at position E561417 N6769351. (Pipeline Code N0601, IBIS Incident No. 1034,COABIS Code NCHIG, IGL12 / 220-001). (See figure 1).

NDT methods under Procedures I 15 001 and I 15 002 are to be employed in conjunction with thisprocedure.

2 TASK OPTIONS

2.1 Standard Tasks

2.1.1 External


VD-ROV/DIV - General Video

DM-SCR - Scour Inspection



CP-PRX - Cathodic Potential Measurements


2.1.2 Internal





CP-PRX/CON - Cathodic Potential Measurements

WT-DIG - Ultrasonic Wall Thickness - Digital

Am 03 04/06 I 91 003Page 3 of 25



0153-001


MG-GEN - Marine Growth Inspection

2.2 Optional Tasks

The following work tasks are optional and will be explicitly called for in the Workscopes, or as a resultof finding an anomaly.


Any number of combination of the listed work tasks, or those listed under Procedure I 15 001 andI 15 002, may be used or called for on the workscope or during the course of the inspection.






Inspection data, including the position of the igloo/manifold to be inspected, will be provided by theShell Inspection department prior to commencement of operations. All inspection data shall be basedon International Spheroid, European Datum 1950 (ED50), Transverse Mercator Projection. For the UKSector, Central Meridian is 0 degrees East. Refer to Section 1, Chapter 2, Figure 1 for further datumshift parameters.

On arrival at the worksite, it should be established that the correct structure has been identified, by useof suitable markings on the igloo, or by use of the Shell inspection data provided, and/or field layoutdrawings to provide other suitable means of confirmation. The Shell Offshore Representative is to beconsulted should no markings be present, and the latter method is used to confirm that the correctstructure has been identified.

If doubt persists as to the correct identification of the igloo/manifold, then a positional fix is to be takenof the as-built fix co-ordinate position, which may not be the centre of the igloo/manifold. Should this fixdisagree with the workscope stated position by more than +/-5m, then initiate checks to resolve errors.Such checks should confirm that the vessel's positioning system has been suitably calibrated.

3.3 External Inspection (VD-ROV / VD-DIV)

The ROV will carry out, and fully video record, a general visual survey of the igloo installation location.The purpose of this survey is to record the following:

(1) An overall view of the igloo (use of SIT camera) from all sides. This inspection is to check forany gross damage or debris, and to confirm the area is safe for diver intervention. Results ofthis inspection to be relayed to the dive supervisor (VI-ROV).

On completion of the overall view, a more detailed inspection is to be carried out in colour.

(2) All side and roof panels for any evidence of impact damage. Check all hinges, paying particularattention to the central roof panel which will be later removed. If any concerns regarding thecentral panel, relay this to the dive supervisor.

(3) Report on external anode wastage levels, as shown on Figure 4. (VI-AW).

I 91 003 Am 03 04/06Page 4 of 25







0153-001

(e) Estimate percentage wastage on each anode using one of the following categories:






(5) CP Readings. Proximity readings are the preferred method. Contact readings are only to betaken where a suitable proximity system is not available. Refer to the workscope for qualificationon the method to use, and if in doubt refer to the Shell Offshore Representative for advice,based on recommendations from the relevant Sponsoring Engineer (CP-PRX).


During the internal inspection of the igloo/manifold, should significant areas of bare metal orcorrosion be noted, CP readings are to be taken and recorded. Where these areas occur,

readings to be restricted to one CP per component.

In addition, CP readings are to be taken on two vertical (including diagonals) and two horizontaltubulars.

Positions of any bare metal, tubular and pipework CP readings obtained are to be clearly shownon structural drawings.

(6) Contact CP readings are also to be taken on the six clamp support screw jacks (Figure 15) andon valve flanges (Figure 16). Data Sheets are provided within the COABIS database for theseresults. (CP-CON).

(7) The diver is to check that the six clamp support screw jacks are not loose, and report anyadjustment to be carried out. Location of jacks are as shown on Figure 15. Comment on anypipe clamps which show signs of corrosion. Wire brush any areas where build up of rust wouldprevent assessment of clamp condition. On completion of inspection and/or adjustment, carryout a video inspection of each clamp support screw jack from all sides to clearly show theircondition.

(8) Ultrasonic wall thickness readings are to be taken at eight locations at both WELGAS 1 and 2,as shown on Figure 17. The areas have had the bitumen coating removed to allow probeaccess and metal contact. Data Sheets are provided within the COABIS database for theseresults. (WT-DIG)

(9) Complete the internal inspection of the igloo structure and walls.

Am 03 04/06 I 91 003Page 7 of 25



0153-001

(10) If access was gained through the roof access doors, on completion of all internal inspectionwork the doors are to be closed in reverse order to opening procedure. Ensure all divingumbilicals and ROV tether are clear of the door before closing. (CN-RPL).

NOTE: ROV to monitor and video record the door closing operation.

(11) Prior to leaving location the ROV will carry out, and fully video record, a general visualinspection of the igloo, paying particular attention to the final placement of top covers and fit up.


4 REPORTING

4.1 Final Report



Record the CP and WT readings as required Figures 15, 16 & 17. These are to be completed andincluded with the final report. Templates for which are contained within the COABIS database.



Record the position of all valves where identified.


I 91 003 Am 03 04/06Page 8 of 25



0153-001

Figure 1 Igloo Field Location

Am 03 04/06 I 91 003Page 9 of 25



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Figure 2 WELGAS Tee Igloo No 2 (NCHIG) - General Layout

I 91 003 Am 03 04/06Page 10 of 25



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Figure 3 WELGAS Tee Igloo No 1 (NHUIG) - General Layout

Am 03 04/06 I 91 003Page 11 of 25





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Figure 5 Location of External Valve and Control Panels

Am 03 04/06 I 91 003Page 13 of 25



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Figure 6 Typical Control Box Layout

I 91 003 Am 03 04/06Page 14 of 25



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Figure 7 WELGAS Igloo No 2 (NCHIG) Modified CBIE, CB2E Actuator/Contro l Box Jumper Arrangement

Am 03 04/06 I 91 003Page 15 of 25



0153-001

Figure 8 Typical Arrangement for Valve Actuation of the WELGAS Igloo No 2 (NCHIG)Valves Using Diver Deployed Cross Over Panel

I 91 003 Am 03 04/06Page 16 of 25



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Figure 9 Igloo Door Positions and Lifting Points - Typical

Am 03 04/06 I 91 003Page 17 of 25



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Figure 10 Lifting Point Hole Dimensions

I 91 003 Am 03 04/06Page 18 of 25



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Figure 11 Lift ing Point General Arrangement

Am 03 04/06 I 91 003Page 19 of 25



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Figure 12 Rigging for Door Opening - Typical

I 91 003 Am 03 04/06Page 20 of 25



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Figure 13 WELGAS Igloo No 1 (NHUIG) – Pipework Schematic and Valve Status

Am 03 04/06 I 91 003Page 21 of 25



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Figure 14 WELGAS Igloo No 2 (NCHIG) – Pipework Schematic and Valve Status

I 91 003 Am 03 04/06Page 22 of 25



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Figure 15 Location of Jacks and CP Readings (both Igloos)

Am 03 04/06 I 91 003Page 23 of 25



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Figure 16 Location of CP Readings (both Igloos)

I 91 003 Am 03 04/06Page 24 of 25



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Am 03 04/06 I 91 003Page 25 of 25

Figure 17 Location of Wall Thickness Readings (both Igloos)



0153-001

PROCEDURE I 91 004

IGLOO INSPECTION – 20 INCH FULMAR A TO ST FERGUS GAS PIPELINE

CONTENTS

Para Page

1 INTRODUCTION 3

2 TASK OPTIONS 3


2.1.1 External 3

2.1.2 Internal 4


3

OPERATING PROCEDURE AND SPECIFICATION 4

3.1 Inspection Qualification 4



3.4 Diver Access Doors and Roof Panel Doors (CN-RPL) 5

3.4.1 Diver Access Door - Approximate Weight in Air 500 KG 6

3.4.2 Roof Panels - Approximate Weight in Air 4100 KG 6

3.5 Internal Survey (VD-ROV / VD-DIV) 6

3.5.1 Kit tiwake/Nelson Receiver Tee (KRT) Igloo (Pipeline Code N0202) 7

3.5.2 Gannet Diverter Igloo (Pipeline Code N0202) 9

3.5.3 Deep Gas Diverter Igloo (Pipeline N0202) 11

3.5.4 Emergency Shutdown (ESD) Valve Assembly Igloo (Pipeline N0202) 13

3.5.5 Alternative Gannet Diverter Igloo (Pipeline N0204) 15

3.5.6

Gannet Subsea Isolation Valve (SSIV) Igloo (Pipeline N0204) 17

3.5.7 Anasuria/Gannet Diverter Tie-in Igloo (Pipeline N0205) 19

4 OPTIONS 21


5 REPORTING 21

5.1 Final Report 21

FIGURES

Figure Page

1 20 inch Fulmar Gas Pipeline Igloo Field Location 22

2 Kit tiwake/Nelson Receiver Tee Igloo Site Location 23

3 Gannet Diverter, Alternative Diverter & Diverter Tie-in Igloo Site Layout 24

4 Gannet SSIV Igloo Site Layout 25

5 Deep Gas Diverter Igloo Site Layout 26

6 Fulmar ESDV Igloo Site Layout 27

7 General Layout of Kit tiwake Receiver Tee Igloo 28

8 General Layout of Gannet Diverter Igloo 29

9

General Layout of Deep Gas Diverter Igloo 30

10 General Layout of ESD Valve Assembly Igloo 31

Am 03 04/06 I 91 004Page 1 of 44



0153-001

11 General Layout of Alternative Gannet Diverter Igloo 32

12 General Layout of Gannet SSIV Igloo 33

13 Anasuria/Gannet Diverter Tie-in Igloo 34

14 Lif ting Point General Arrangement - Typical 35

15 Lifting Point Hole Dimensions - Typical 36

16

Kit tiwake/Nelson Receiver Tee Igloo - Pipework Schematic and Valve Status 37

17 Gannet Diverter Igloo - Pipework Schematic and Valve Status 39

18 Deep Gas Diverter Igloo - Pipework Schematic and Valve Status 40

19 ESD Valve Assembly Igloo - Pipework Schematic and Valves Status 41

20 Al ternative Gannet Diverter Igloo - Pipework Schemat ic and Valve Status 42

21 Gannet SSIV Igloo - Pipework Schematic and Valves Status 43

22 Anasuria/Gannet Diverter Tie-in Igloo - Pipework Schematic and Valve Status 44

I 91 004 Am 03 04/06Page 2 of 44



0153-001

PROCEDURE I 91 004

IGLOO INSPECTION - 20 INCH FULMAR A TO ST FERGUS GAS PIPELINE

1 INTRODUCTION

The work method is to be applied to the external and internal inspection of the igloos listed below,which are associated with the 20 inch Fulmar A to the St.Fergus Gas Pipeline, N0202 (See Figure 1).The work will include damage, debris, scour and anode wastage surveys, leak monitoring andCathodic Potential (CP) measurements. These surveys are to be recorded on video.

The following igloos covered under this procedure are:

Pipeline N0202: 20 inch Fulmar Alpha to St Fergus Gas Pipeline.

The Kittiwake/Nelson Receiver Tee (KRT) igloo is situated at KP 140.315 at position

E529698721 N6367901N6367882 (IBIS Incident No. 3093, COABIS Code - IGL07 / 220-004). (Seefigure 2)

The Gannet Diverter igloo is situated at KP 181.880 at positionE558539 N6338251 (IBIS Incident No. 5069, COABIS Code - IGL06 / 220-003). (See figure 3)

The Deep Gas Diverter igloo is situated at KP 250.890 at positionE605066 N6288311 (IBIS Incident No. 4952, COABIS Code - IGL05 / 220-002). (See figure 5)

The Emergency Shutdown (ESD) Valve Assembly igloo is situated at KP 288.080 at positionE632225 N6264240 (IBIS Incident No. 4188, COABIS Code - IGL04 / 220-001). (See figure 6)

Pipeline N0204: 20 inch Gannet Alpha to Fulmar Alpha Gas Pipeline.

The Al ternative Gannet Diverter ig loo is situated at KP 1.906 at positionE558502 N6338215 (IBIS Incident No. 73, COABIS Code - IGL14 / 220-002). (See figure 3)

The Gannet SSIV igloo is situated at KP 0.400 at positionE560045 N6338545 (IBIS Incident No. 27, COABIS Code - IGL13 / 220-001). (See figure 4)

Pipeline N0205: 8 inch FPSO Anasuria to Fulmar Alpha Gas Pipeline.

The Anasuria/Gannet Diverter Tie-in Igloo is situated at KP 12.753 at positionE558476 N6338240 (IBIS Incident No. 02, COABIS Code N0205 / 220-001). (See figure 3)

NOTE: The Triton Gas Export Pipeline PLEM (Figure 3) and Deep Gas Diverter Pigging Skid(Figure 5), are not required for inspection under this procedure.

NDT methods under Procedure I 15 001 may be employed in conjunction with this procedure.

2 TASK OPTIONS

2.1 Standard Tasks


2.1.1 External


Am 03 04/06 I 91 004Page 3 of 44



0153-001





2.1.2 Internal


VD-DIV/ROV - General ROV Video


CH-VLV - Valve Position Checks





2.2 Optional Tasks




Any number or combination of the listed work tasks, or those listed under Procedure I 15 001, may beused or called for on the workscope or during the course of the inspection.






Survey data, including the position of the igloo/manifold to be inspected, will be provided by the ShellSurvey department prior to commencement of operations. All survey data shall be based onInternational Spheroid, European Datum 1950 (ED50), Transverse Mercator Projection. For UK SectorCentral Meridian is 0 degrees East. Reference Section 1, Chapter 2, Figure 1, for further datum shiftparameters.

On ROV arrival at the worksite, it should be established that the correct igloo/manifold has been

identified, by use of suitable markings on the igloo/manifold itself, or by use of the Shell survey dataprovided, and/or field layout drawings to provide other suitable means of confirmation. The Shell

I 91 004 Am 03 04/06Page 4 of 44



0153-001

Offshore Representative is to be consulted should no markings be present, and the latter method isused to confirm that the correct igloo/manifold has been identified.

If doubt persists as to the correct identification of the igloo/manifold, then a positional fix is to be takenof the as-built fix co-ordinate position, which may not be the centre of the igloo/manifold. Should this fixdisagree with the workscope stated position by more than +/-5m, then initiate checks to resolve errors.

Such checks should confirm that the vessel's positioning system has been suitably calibrated.



The ROV will carry out, and fully video record, a general visual survey of the igloo/manifold installationlocation. The purpose of this survey is to record the following:

(1) Confirm igloo/manifold identification if present.




(4) Loose or displaced panels paying particular attention to the seating of panels. Check all hinges.



(7) Scour around the base of the structure. Note: There are specific anomaly criteria with respect toigloo/manifold scour. See Section 2, Chapter 6, Point 2.3.12.

(8) Debris.



3.4 Diver Access Doors and Roof Panel Doors (CN-RPL)

It may be possible for divers and possibly small ROV’s, to enter the igloos through the pipelineentrance/exit ports. If however at the discretion of the divers, dive supervisor or ROV supervisor thatthis practice is unsafe, it will be necessary to gain access to any of the seven igloos via one of thediver access or door panels on the roof of the igloos to be opened. Door positions are shown inFigures. 7 to 13.

NOTE: Where access has in the past been gained without cause to remove an access panel ordoor, this is stated at the start of the relevant internal inspection instructions below.

For the Alternate Gannet Diverter Igloo and Gannet SSIV, panels have been removed fordiver access.

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0153-001

WARNING: PRIOR TO ATTEMPTING TO OPEN ANY OF THE DIVER ACCESS OR ROOFPANEL DOORS, A CLOSE VISUAL AND ELECTROMAGNETIC INSPECTION OF ALL PADEYES ON THE DOORS AND AS NECESSARY FOR TIRFOR AND TIEBACK ATTACHMENT IS TO BE CARRIED OUT. SHOULD THE INSPECTIONREVEAL ANY ANOMALIES OR DAMAGE THEN THE PADEYE IS NOT TO BEUSED. REFER TO ALTERNATIVE LIFTING ARRANGEMENTS, FIGS 9 AND 10.

3.4.1 Diver Access Door - Approximate Weight in Air 500 KG

WARNING: PRIOR TO INFLATION OF LIFT BAG, HOLD BACK STROPS MUST BE ATTACHED TO PREVENT ACCIDENTAL BLOW UP AND POSSIBLEUNCONTROLLED ASCENT OF COVER.

On completion of the padeye inspection the diver is to open the diver access door using the followingmethod:

(1) The Lifting Strop. 1 x Four Leg Sling complete with 4T SWL Master Link assembly made up asfollows: 12mm dia. 6x36 galvanized IWRC slings 2.2m long. Each leg tested to 1T SWL. Hardeyes both ends each leg. 3.25T SWL Safety Anchor Shackles at free ends,

(2) Attach lifting strop to padeyes and using a 500kg lifting bag remove the diver access door andplace cover on igloo roof clear of opening. Deflate lift bag.

3.4.2 Roof Panels - Approximate Weight in Air 4100 KG

Should it be necessary to open roof panels for access the following procedure is to be carried out:

(1) Install a Tifor (T516) between one of the padeyes on the roof panel (opposite side to the hinges)and a padeye on the igloo top. Leave the Tirfor loose.

(2) Install two 1000 kg lifting bags on the roof panel padeyes. Inflate the bags slowly until the dooropens.

(3) When the roof panel is open and vertical, tighten the Tirfor to pull panel past the vertical andsecure. Slowly deflate bag and lower door to lay flat on top of igloo.

NOTE: ROV to moni tor and video record the door opening operation.

3.5 Internal Survey (VD-ROV / VD-DIV)


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3.5.1 Kitt iwake/Nelson Receiver Tee (KRT) Igloo (Pipeline Code N0202)

NOTE: Diver access has in the past been gained via a roof access hatch. See Figure 7.

On gaining entry to the interior of the igloo the diver or ROV, as access allows, will carry out, and fullyvideo record, a general visual survey of the manifold installation and internal walls of the igloo. Thepurpose of this survey is to record the following:

CAUTION: IN THE EVENT OF A LEAK BEING DISCOVERED, DIVERS SHOULD BEWITHDRAWN FROM THE AREA AND AN ROV INSPECTION SHOULD BECARRIED OUT TO IDENTIFY THE LEAK SOURCE, THE RATE OF LEAKAGE ANDDAMAGE ASSOCIATED WITH THE LEAK. ALL LEAKS ARE TO BE TREATED AS'C1' ANOMALIES AND IMMEDIATELY REPORTED TO THE SHELL OFFSHOREREPRESENTATIVE.

(1) Pipework . All pipework for corrosion and leaks. Particular attention is to be given to the pipeguides and clamps, with any evidence of pipe movement to be reported. The pipeworkschematic is shown on Figure 16.

(2) Valves. Each of the 39 valves as shown on Figure 16 are to be visually inspected. Any leaks orevidence of leaks are to be reported (CH-VLV). Where visible, the status (Open or Closed) of allvalve positions is to be noted on video. These however are not required to be recorded in theJob Completion Report.

(3) Blind Flanges. The flanges at the end of the valve manifolds are to be inspected for anyevidence of gas leaks.

(4) Anodes. Carry out an anode inspection (VI-AW) of the anodes which are located on the sidewall panels, under the roof panels, on the igloo sub-frame and on the pipeline manifold. Theinspection is to record the following:


Refer to Procedure I 60 004 – Cathodic Protection Monitoring, in particular section 4.1.2.









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(5) Proximity readings are the preferred method. Contact readings are only to be taken where asuitable proximity system is not available. Refer to the workscope for qualification on themethod to use, and if in doubt refer to the Shell Offshore Representative for advice, based onrecommendations from the relevant Sponsoring Engineer (CP-PRX).

During the internal survey of the igloo/manifold, should significant areas of bare metal or

corrosion be noted, CP readings are to be taken and recorded. Where these areas occur,readings to be restricted to one CP per component.

In addition, CP readings are to be taken on two vertical (including diagonals) and two horizontaltubulars. With respect to manifold inspection by ROV, where the internal framework is the sameas the external framework, these readings are not required, as they have been covered by theCPs taken as part of the external survey.

Positions of bare metal and tubular CP readings obtained are to be clearly shown on structuraldrawings.

(6) On completion of all internal inspection work the panels are to be closed in reverse order toopening procedures. Ensure all diving umbilicals and ROV tether cable are clear of the door

before closing (CN-RPL).

NOTE: ROV to moni tor and video record any panel closing operation.

(7) Prior to leaving location the ROV will carry out, and fully video record, a general visual survey ofthe igloo, paying particular attention to the final placement of top covers and fit up.


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3.5.2 Gannet Diverter Igloo (Pipeline Code N0202)

NOTE: Diver access has in the past been gained via a roof access hatch. There is no accessthrough pipeline entrance/exits. See Figure 8.


CAUTION: IN THE EVENT OF A LEAK BEING DISCOVERED, DIVERS SHOULD BEWITHDRAWN FROM THE AREA AND AN ROV INSPECTION SHOULD BECARRIED OUT TO IDENTIFY THE LEAK SOURCE, THE RATE OF LEAKAGE ANDDAMAGE ASSOCIATED WITH THE LEAK. ALL LEAKS ARE TO BE TREATED AS'C1' ANOMALIES AND IMMEDIATELY REPORTED TO THE SHELL OFFSHOREOPERATIONS REPRESENTATIVE.

(1) Pipework . All pipe work for corrosion and leaks. Particular attention is to be given to the pipeguides and clamps, with any evidence of pipe movement to be reported. The pipeworkschematic is shown on Fig 17.

(2) Valves. Each of the 16 valves as shown on Fig 17 are to be visually inspected. Any leaks orevidence of leaks are to be reported (CH-VLV). Where visible, the status (Open or Closed) of allvalve positions are to be noted on video. These however are not required to be recorded in theJob Completion Report.


(4) Anodes. Carry out an anode inspection (VI-AW) of the anodes which are located on the sidewall panels, under the roof panels, on the igloo sub-frame and on the pipeline manifold.The inspection is to record the following:



(b) Describe marine growth as hard or soft, giving estimated thickness and percentage cover ofeach anode.








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corrosion be noted, CP readings are to be taken and recorded. Where these areas occur,


In addition, CP readings are to be taken on two vertical (including diagonals) and two horizontal

tubulars. With respect to manifold inspection by ROV, where the internal framework is the same

as the external framework, these readings are not required, as they have been covered by the


Positions of bare metal and tubular CP readings obtained are to be clearly shown on structural

drawings.

(6) On completion of all internal inspection work the panels are to be closed in reverse order to

opening procedures. Ensure all diving umbilicals and ROV tether cable are clear of the doorbefore closing (CN-RPL).

NOTE: ROV to moni tor and video record any panel clos ing operation.



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3.5.3 Deep Gas Diverter Igloo (Pipeline N0202)

NOTE: Diver access has in the past been gained via a roof access hatch. See Figure 9.



(1) Pipework . All pipework for corrosion and leaks. Particular attention is to be given to the pipeguides and clamps, with any evidence of pipe movement to be reported. The pipeworkschematic is shown on Fig 18.

(2) Valves. Each of the 16 valves as shown on Fig 18 are to be visually inspected. Any leaks orevidence of leaks are to be reported (CH-VLV). Where visible, the status (Open or Closed) ofall valve positions are to be noted on video. These however are not required to be recorded inthe Job Completion Report.



(a) The presence and location of the anodes are to be confirmed as per as-built layout

drawings and are to be confirmed as specified. Give an estimated average range of theanode wastage.








>50% LOSS - ANODE IN VERY POOR CONDITION.

METAL FROM SUPPORT BRACKETSHOWING. EXTENSIVE PITTING.


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drawings.






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3.5.4 Emergency Shutdown (ESD) Valve Assembly Igloo (Pipeline N0202)

NOTE: Diver access has in the past been gained via the Southern pipeline entrance. Access hasalso been gained by removal of the Northern roof access panel. See Figure 10.




(2) Valves. Each of the 8 valves as shown on Fig 19 are to be visually inspected. Any leaks orevidence of leaks are to be reported (CH-VLV). Where visible, the status (Open or Closed) of allvalve positions are to be noted on video. These however are not required to be recorded in the job Completion Report.













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CPs taken as part of the external survey.


drawings.






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drawings.






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3.5.6 Gannet Subsea Isolation Valve (SSIV) Igloo (Pipeline N0204)

NOTE: Access can be gained to this igloo via a removed panel ‘K’ at the East end. See Figure 12.

On gaining entry to the interior of the igloo the diver or ROV, as access allows, will carry out and fullyvideo record, a general visual survey of the manifold installation and internal walls of the igloo. The

purpose of this survey is to record the following:



(2) Valves. The valve as shown on Fig 21 is to be visually inspected. Any leaks or evidence ofleaks are to be reported. If visible, the status (Open or Closed) of the valve position is to benoted on video. This however is not required to be recorded in the job Completion Report.

(3) Hydraulics. All subsea control box-interfaces and controls from the umbilical termination,accumulator bank and EIV actuator, along with hydraulic accumulator, electro/hydrauliccables/tubing are to be inspected and checked for leakage, damage, corrosion and signs ofmovement. Check connection points, condition of hoses i.e. blistering and cracking and forgeneral deterioration. Check any continuity straps.

(4) Umbilical Termination Unit. The unit is to be inspected for damage and any sign ofmovement. Check any continuity straps.

(5) Anodes. Carry out an anode inspection (VI-AW) of the anodes which are located on the sidewall panels, under the roof panels, on the igloo sub-frame and on the pipeline manifold.

The inspection is to record the following:











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drawings.






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3.5.7 Anasuria/Gannet Diverter Tie-in Igloo (Pipeline N0205)

NOTE: Diver access has in the past been gained via the Northern roof panel. See Figure 13.




(2) Valves. Each of the 24 valves as shown on Fig 22 are to be visually inspected. Any leaks orevidence of leaks are to be reported. Where visible, the status (Open or Closed) of all valvepositions are to be noted on video. These however are not required to be recorded in the jobCompletion Report.


(4) Non Return Valve. The non return valve (TDCV-01) as shown in Fig 22 is to be visuallyinspected for any evidence of gas leaks.

(5) Anodes. Carry out an anode inspection (VI-AW) of the anodes which are located on the side

wall panels, under the roof panels, on the igloo sub-frame and on the pipeline manifold.The inspection is to record the following:

(a) The presence and location of the anodes are to be confirmed as per as built layout drawingsand are to be confirmed as specified. Give an estimated average range of the anodewastage.




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CPs taken as part of the external survey.


drawings.

(7) On completion of all internal inspection work the panels are to be closed in reverse order toopening procedures. Ensure all diving umbilicals and ROV tether cable are clear of the doorbefore closing (CN-RPL).


(8) Prior to leaving location the ROV will carry out, and fully video record, a general visual survey of

the igloo, paying particular attention to the final placement of top covers and fit up.


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4 OPTIONS


Wall thickness (WT) readings may be requested on specific areas of pipework to check for internalcorrosion/erosion. The location, extent and areas of readings to be taken will be specified in theworkscope.


5 REPORTING

5.1 Final Report

The Job Completion Report is to précis the results of the inspection, and any subsequent actions asper the points of interest listed above. Reference Section 2, Chapter 1, Section 3.1.5.






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Figure 1 20 inch Fulmar Gas Pipeline Igloo Field Location

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Figure 2 Kit tiwake/Nelson Receiver Tee Igloo Site Location

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Figure 3 Gannet Diverter, Alternative Diverter & Diverter Tie-in Igloo Site Layout

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Figure 4 Gannet SSIV Igloo Site Layout

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Figure 5 Deep Gas Diverter Igloo Site Layout

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Figure 6 Fulmar ESDV Igloo Site Layout

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Figure 7 General Layout of Kit tiwake Receiver Tee Igloo

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Figure 8 General Layout of Gannet Diverter Igloo

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Figure 9 General Layout of Deep Gas Diverter Igloo

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Figure 10 General Layout of ESD Valve Assembly Igloo

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Figure 11 General Layout of Alternative Gannet Diverter Igloo

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Figure 12 General Layout of Gannet SSIV Igloo

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Figure 13 Anasuria/Gannet Diverter Tie-in Igloo

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Figure 14 Lift ing Point General Arrangement - Typical

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Figure 15 Lifting Point Hole Dimensions - Typical

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Figure 16 Kittiwake/Nelson Receiver Tee Igloo - Pipework Schematic and Valve Status

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Figure 17 Gannet Diverter Igloo - Pipework Schematic and Valve Status

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Figure 18 Deep Gas Diverter Igloo - Pipework Schematic and Valve Status

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Figure 19 ESD Valve Assembly Igloo - Pipework Schematic and Valves Status

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Figure 20 Alternative Gannet Diverter Igloo - Pipework Schematic and Valve Status

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Figure 21 Gannet SSIV Igloo - Pipework Schematic and Valves Status

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I 91 004Page 44

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I 91 004Page 44

Figure 22 Anasur ia/Gannet Diverter Tie-in Igloo - Pipework Schematic and Valve StatusFigure 22 Anasur ia/Gannet Diverter Tie-in Igloo - Pipework Schematic and Valve Status

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PROCEDURE I 91 005

IGLOO INSPECTION - SUBSEA UMBILICAL SPLITTER BOX BRENT ALPHA

1 INTRODUCTION

The work method is to be applied to the external and internal inspection of the Brent Alpha SubseaUmbilical Splitter Box Igloo. The work will include damage survey, scour survey, umbilical movementmonitoring, leak monitoring, Cathodic Potential (CP) measurements, anode survey and video survey.

The arrangement of the Splitter Box protection structure allows for easy internal access by ROV. Assuch this procedure assumes that the inspection will be carried out by ROV only, however should it benecessary then the inspection can be carried out by diver.

The Brent Alpha Subsea Umbilical Splitter Box Igloo is situated at KP 0.0 on the control umbilical forthe Brent A SSIV (Pipeline/COABIS Codes - N0830/IGL08), at position E592060 N6768087 (See Fig01).

2 TASK OPTIONS

2.1 External



CP-PRX - Cathodic Potential Proximity Measurements



2.2 Internal






Should additional activities be carried out or incidents noted, suitable work tasks and task codes maybe added to cover works.



Note: Refer to figures below and to the Igloos and Subsea Facilities UMDB (0144-001),Section 5 for drawings and component numbering details relevant to the SubseaUmbilical Splitter Box.

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Survey data, including the position of the Subsea Umbilical Splitter Box, will be provided by the ShellSurvey department prior to commencement of operations. All survey data shall be based onInternational Spheroid, European Datum 1950 (ED50), Transverse Mercator Projection. For UK SectorCentral Meridian is 0 degrees East. Reference Section 1, Chapter 2, Figure 1, for further datum shiftparameters.

On ROV arrival at the worksite, it should be established that the correct igloo has been identified, byuse of suitable markings on the igloo itself, or by use of the Shell survey data provided, and/or fieldlayout drawings to provide other suitable means of confirmation. The Shell Offshore Representative isto be consulted should no markings be present, and the latter method is used to confirm that thecorrect igloo has been identified.

If doubt persists as to the correct identification of the igloo, then a positional fix is to be taken of the as-built fix co-ordinate position, which may not be the centre of the igloo. Should this fix disagree with theworkscope stated position by more than +/-5m, then initiate checks to resolve errors. Such checksshould confirm that the vessel's positioning system has been suitably calibrated.


3.3 External Survey (VI-GVI)

The ROV will carry out, and fully video record, a general visual inspection of the splitter box iglooprotection structure location (See Fig. 2). The purpose of this inspection is to record the following:

(1) Confirm igloo identification if present.

(2) An overall view of the igloo (use of SIT camera) from all sides. This inspection is to check forany gross damage or debris, and to confirm the area is safe for further intervention (VI-ROV).Results of this inspection are to be relayed to the diver supervisor as required.



(4) Security of the roof panel.

(5) The entry and exit of the umbilicals to the structure for any evidence of movement.

(6) Scour around the base of the structure (DM-SCR). Note: There are specific anomaly criteriawith respect to igloo scour. See Section 2, Chapter 6, Point 2.3.12.

(7) CP readings on four corners of the structure and the roof panel, proximity or contact (CP-PRX).

(8) Debris (DB-CHK). Structure and adjacent seabed.

(9) General views are required of the approaches of each umbilical out to 5m from the igloo, or tothe start of protection mattresses, which ever is the lesser. The inspection is to confirm the

presence and integrity of any supports, protection bags/mats or point of burial.

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0153-001

Digital Still Images are to be taken of any anomalies or other areas of interest. These may besupplemented by suitable drawings to show the location, size and details of the item of interest.

3.3.1 Internal Survey (VI-GVI)

The igloo is of an open design with only a roof panel for protection of the Subsea Umbilical Splitter

Box, therefore it is not necessary to remove any panels for diver or ROV to gain access. Refer to Fig 2for igloo general arrangements.

On gaining entry to the interior of the igloo the diver or ROV, as access allows, will carry out and fullyvideo record, a general visual inspection of the Subsea Umbilical Splitter Box and igloo subframe (SeeFigs. 2, 3 and 4). The purpose of this inspection is to record the following:

CAUTION: In the event of a leak being discovered, divers should be withdrawn from thearea and an ROV inspection should be carried out to identify the leak source,the rate of leakage and any damage associated with the leak. All leaks are to betreated as ‘C1’ anomalies and immediately reported to the Shell OffshoreRepresentative.

(1) Subsea Umbilical Splitter Box. The splitter box as shown on Fig 4 is to be visually inspected. Any leaks or evidence of leaks is to be reported.

(2) Umbilical Terminations. The three umbilical termination blocks are to be visually inspected. Any leaks or evidence of leaks are to be reported. Check connection points, condition of hosesi.e. blistering and cracking and for general deterioration.

(3) Anodes (VI-AW). Carry out an anode inspection of the anodes which are located under the roofpanel, on the igloo subframe and on the splitter box frame assembly, (Refer to Figs 2, 3 and 4).The inspection is to record the following:











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0153-001

(4) CP Readings (CP-PRX/CON). Proximity readings are the preferred method. Contact readingsare only to be taken where a suitable proximity system is not available. Refer to the workscopefor qualification on the method to use, and if in doubt refer to the Shell Offshore Representativefor advice, based on recommendations from the relevant Sponsoring Engineer.

Where Reference Proximity readings are taken, an initial contact reading is required. All

subsequent readings are to be proximity, unless doubts exist as to the electrical continuity of thelocations of the subsequent readings.

A CP reading is required of the Splitter Box itself (Figs. 2 and 4).

During the internal inspection of the igloo, should significant areas of bare metal or corrosion benoted, CP readings are to be taken and recorded. Where these areas occur, readings to berestricted to one CP per component.

Where no areas of bare metal are evident, one CP reading is required on a typical area of majorpipework (preferably a flange) and on the splitter box base. Locations of these readings are tobe recorded and used for repeat readings in future years.

In addition, CP readings are to be taken on two vertical (including diagonals) and two horizontaltubulars. With respect to igloo inspection by ROV, where the internal framework is the same asthe external framework, these readings are not required, as they have been covered by the CPstaken as part of the external inspection.

Positions where readings are obtained, including bare metal and tubular CPs are to be clearlyshown on structural drawings.

(5) If diver intervention has occurred, prior to leaving location the ROV will carry out, and fully videorecord, a general visual inspection of the igloo and subsea umbilical splitter box to show that nodiver tools/rigging has been left.


3.4 Final Report

The Job Completion Report is to précis the results of the inspection, and any subsequent actions asper the points of interest listed above. Reference Section 2, Chapter 7.


Maximum and minimum range for all other CP readings taken are to be stated, with the readings and

their locations clearly shown on structural drawings.



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N

BRENT 'A'

592250E592000E

6768250N

6768000N

6767750N

BRENT 'A' J-TUBE

UMBILICAL

SUBSEA UMBILICALSPLITTER BOX IGLOO

E592060N6768087

B R E N T ' A

' U M B I L I C A

L

BRENT 'A'SSIV

3 6 " G A S T O S T F E R G U S

591750E

BRENT 'A' /BP UMBILICAL

20" GAS FROM MAGNUS (BP)

1 6 " T O B R E N

T S P A

R

2 8 " G A

S T

B R E N T F

L A R E

1 6 " G

A S F R O M C

O R M O R A N T ' A '

1 6 " G

A S F R O M N I N I A N C E N

T R A L ( S

T A T H S P E Y )


O

Figure 1 Subsea Umbilical Splitter Box Igloo Field Location

Am 04 04/08 I 91 005Page 5 of 8



0153-001

B R E N

T ' A ' J -

T U B E

U M B I L

I C A L

B R E N

T ' A ' U

M B I L I C

A L

B R E N

T ' A ' / B

P U M B

I L I C A

L

1

7

3

6

2

2

4

ANODE DETAIL

001 - 002 - 009 TO 014SEE FIG 3

ANODE DETAIL003 TO 008SEE FIG 3

002

001

006

003

004

007

008

005

009

010

BASE

M30 BOLTS C/W No SPACERSWASHERS & 1 No NUT

FRAME

COVER RETAINING PIN

RETAINING P C/W 2 No SCREWS

COVER

SPLITTER BOX

5

L

011012

013

014

1

2

3

4

5

6

7

Figure 2 Umbilical Junction Protection Frame - General Arrangement

I 91 005 Am 04 04/08Page 6 of 8



0153-001

ANODE DETAIL001 - 002 - 009 - 010

ANODE DETAIL003 TO 008

1580 (MODIFIED ANODE) 009 & 0101370 (MODIFIED ANODE) 001 & 002

235

1775

230

Figure 3 Anode Dimensions

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0153-001

I 91 005 Am 04 04/08Page 8 of 8

PLAN VIEW

FRONT VIEW

SIDE VIEW

ANODE (TYP)

BRENT 'A'UMBILICAL

BRENT 'A'/BPUMBILICAL

BRENT 'A'J-TUBEUMBILICAL

Figure 4 Splitter Box



0153-001

PROCEDURE I 91 007

IGLOO / MANIFOLD INSPECTION - GENERAL

CONTENTS

Para. Page

1 INTRODUCTION 3

2 TASK OPTIONS 3


2.1.1 External 3

2.1.2 Internal 3





3.3

Internal Survey (VD-ROV / VD-DIV) 5

4 OPTIONS 7


5 REPORTING 7

5.1 Final Report 7

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0153-001

PROCEDURE I 91 007

IGLOO / MANIFOLD INSPECTION - GENERAL

1 INTRODUCTION

The work method is to be applied to the external and internal inspection of an igloo/manifold, and ofsubmarine pipelines and umbilicals, which converge at an igloo/manifold. The work will includedamage survey, Cathodic Potential measurements, and anode survey; scour survey and generalvideo survey.

Intervention under Procedure I 90 002 may be employed in conjunction with this procedure.

NDT methods under Procedure I 15 001 and I 15 002 may be employed in conjunction with thisprocedure.

2 TASK OPTIONS

2.1 Standard Tasks


2.1.1 External





CP-PRX - Proximity CP Readings

2.1.2 Internal






CP-PRX - Proximity CP Readings

CH-LKS - Check For Leaks

CH-VLV - Valve Status Checks

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2.2 Optional Tasks

The following work tasks are optional and will be explicitly called for in the Workscope, or as a result offinding an anomaly.



Any number or combination of the listed work tasks, or those listed under Procedures I 15 001,I 15 002 and I 90 002, may be used or called for on the workscope or during the course of theinspection.






Survey data, including the position of the igloo/manifold to be inspected, will be provided by the ShellSurvey department prior to commencement of operations. All survey data shall be based onInternational Spheroid, European Datum 1950 (ED50), Transverse Mercator Projection. For UK SectorCentral Meridian is 0 deg and for Dutch Sector Central Meridian is 5deg E. Reference Section 1,Chapter 2, Figure 1, for further datum shift parameters.

On arrival at the worksite, it should be established that the correct igloo/manifold has been identified,by use of suitable markings on the igloo/manifold itself, or by use of the Shell survey data provided,and/or field layout drawings to provide other suitable means of confirmation. The Shell OffshoreRepresentative is to be consulted should no markings be present, and the latter method is used toconfirm that the correct igloo/manifold has been identified.

If doubt persists as to the correct identification of the igloo/manifold, then a positional fix is to be takenof the as-built fix co-ordinate position, which may not be the centre of the igloo/manifold. Should thisfix disagree with the workscope stated position by more than +/-5m, then initiate checks to resolveerrors. Such checks should confirm that the vessel's positioning system has been suitably calibrated.

If required a spin check should be carried out to verify the USBL positioning system. If the spread ofthe position data is more than the accuracy of the positioning systems, (i.e. DGPS 1-3m & USBL 1%

of water depth) checks should be initiated to resolve errors. Prior to this, a CTD profile of the full watercolumn should be observed and the relevant data entered into the USBL system.

The ROV will carry out, and fully video record, a general visual survey of the igloo/manifold installationlocation. The purpose of this survey is to record the following:

(1) Confirm igloo/manifold identification if present.




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(4) Loose or displaced panels paying particular attention to the seating of panels at the roofinterface. Check all hinges.


(6) Anode condition if visible.


(8) Scour around the base of the structure. Note: There are specific anomaly criteria with respect toigloo/manifold scour. See Section 2, Chapter 6, Point 2.3.12.

(9) Debris.



3.3 Internal Survey (VD-ROV / VD-DIV)

WARNING: PRIOR TO ATTEMPTING TO OPEN ANY ACCESS DOORS OR PANELS A CLOSEVISUAL AND/OR ELECTROMAGNETIC INSPECTION OF ALL PADEYES ON THEDOORS AND PANELS, AS NECESSARY FOR TIRFOR AND TIE BACKATTACHMENT, IS TO BE CARRIED OUT. SHOULD THE INSPECTION REVEALANY ANOMALIES OR DAMAGE THEN THE PADEYE IS NOT TO BE USED.VISUALLY INSPECT ANY HINGE ARRANGEMENTS FOR SECURITY, RE-TIGHTEN ALL BOLTS AS NECESSARY. SHOULD THERE BE EVIDENCE OFDAMAGE TO THE HINGE ARRANGEMENT, CARRY OUT A CLOSE VISUAL

AND/OR ELECTROMAGNETIC INSPECTION. REPORT ALL ANOMALIES NOTEDTO THE SHELL OFFSHORE REPRESENTATIVE. SPECIFIC ENTRYPROCEDURES WILL BE ISSUED BY THE RESPONSIBLE STRUCTURALENGINEER PRIOR TO COMMENCEMENT OF WORKS.

When a diver enters an igloo/manifold, a second diver must remain at the entrance and act as tender.

On gaining entry to the interior of the igloo/manifold, consisting of in part or all, the following items, thediver or ROV, as access allows, will carry out and fully video record, a general visual survey of themanifold installation and internal framework of the igloo/manifold. The purpose of this survey is torecord the following, where the relevant components listed below exist:

CAUTION: In the event of a leak being discovered, divers should be withdrawn from thearea and an ROV inspection should be carried out to identify the leak source,the rate of leakage and damage associated with the leak. All leaks are to betreated as 'C1' anomalies and immediately reported to the Shell OffshoreRepresentative.

(1) PIPEWORK. All pipe work for corrosion and leaks. Particular attention is to be given to the pipeguides and clamps with any evidence of pipe movement to be reported.

(2) VALVES. All valves are to be visually inspected. Any leaks or evidence of leaks is to bereported (CH-VLV). Where visible, all valve positions are to be noted on video. These howeverare not required to be recorded in the job Completion Report.

(3) ACCUMULATOR MODULES. All accumulator modules are to be visually inspected. Any leaksor evidence of leaks is to be reported. Check continuity Straps.

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(4) CONTROL MODULE. All Control Modules are to be visually inspected. Any leaks or evidence isto be reported. Check continuity Straps.

(5) HOSES. Check connection points, condition of hoses i.e. blistering and cracking and for generaldeterioration.

(6) HYDRAULIC DISTRIBUTION MANIFOLDS. All hydraulic distribution manifolds are to bevisually inspected. Any leaks or evidence of leaks are to be reported.

(7) UMBILICAL TERMINATION MODULE/ASSEMBLY. All Umbilical Termination Modules/ Assemblies (UTM / UTA / BUTA) are to be visually inspected. Any leaks or evidence of leaksare to be reported. Where necessary the module's support cradle is to be checked for security,as is the umbilical support ramp, bend restrictor and attachments.

(8) FLANGES. All flanges are to be visually inspected. Any leaks or evidence of leaks are to bereported.

(9) Check for the presence and integrity of all continuity Straps. These are usually to be found atclamps, and appurtenances such as modules, UTM/UTA/BUTA’s. Anomalies are only to be

generated should it be obvious that the straps are missing from as designed, or if there areCathodic Potential concerns.

(10) Anodes. Carry out an anode inspection (VI-AW) of the anodes, which are located on thesidewall panels, under the roof panels, on the igloo/manifold sub-frame and on the pipelinemanifold (VI-AW). The inspection is to record the following:


(b) Refer to Procedure I 60 004 – Cathodic Protection Monitoring, in particular section 4.1.2.

(c) Describe marine growth as hard or soft, giving estimated thickness and percentage coverof each anode.

(d) The integrity of the anode support (bracket, bracelet, earthing strap) is to be checked.

(e) (Estimate percentage wastage on each anode using one of the following categories:






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tubulars. With respect to manifold inspection by ROV, where the internal framework is the sameas the external framework, these readings are not required, as they have been covered by theCP’s taken as part of the external survey.


(12) On completion of all internal inspection work the doors are to be closed in reverse order toopening procedures. Ensure all diving umbilicals and ROV tether cable are clear of the doorbefore closing (CN-RPL).


(13) Prior to leaving location the ROV will carry out, and fully video record, a general visual survey ofthe igloo/manifold, paying particular attention to the final placement of top covers and fit up.


4 OPTIONS


Wall thickness (WT) readings may be requested on specific areas of pipework to check for internalcorrosion/erosion. The location, extent and areas of readings to be taken will be specified in the

workscope.


5 REPORTING

5.1 Final Report


All anomalies are to be referenced, with a general statement made concerning the types and extent ofanomalies identified. Any C1 anomalies are to be commented on more specifically. Other references

are to be made to any digital still images and drawings.

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Sketches are required, either scanned, AcadLT or other proprietary drawing format, of any major

defects or debris that cannot be suitably documented by anomaly report and digital images alone.



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PROCEDURE I 91 008

IGLOO INSPECTION - BRENT SPAR MANIFOLD - ROV

1 INTRODUCTION

The work method is to be applied to the external and internal inspection of the Brent Spar manifoldprotection cover igloo and the original Brent Spar base, manifold and pipework. The work will includedamage survey, scour survey, leak monitoring, Cathodic Potential (CP) measurements, anode surveyand general video survey.

The arrangement of the Brent Spar Manifold allows for easy internal access by ROV. As such thisprocedure assumes that the inspection will be carried out by ROV only, however should it benecessary then the inspection can be carried out by diver.

The Brent Spar Igloo (Pipeline/COABIS Codes - N0301/IGL719) is situated at KP2.910, being the joining point of the 16 inch Oil Pipelines from Brent A (N0301) and Brent B (N0302) at position E590047 N 6770105 (See Fig 1).

NOTE: These lines are now used as a Drains Export from Brent Alpha to Brent Bravo. Assuch the pipeline is at low pressure and contains predominantly water, which maycontain traces of oil.

2 TASK OPTIONS

2.1 External






2.2 Internal



CH-VLV - Valve Status Checks






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NOTE: Refer to figures below and to the Igloos and Subsea Facilities UMDB (0144-001),Section 10 for drawings and component numbering details relevant to the Brent SparManifold.




Survey data, including the position of the Brent Spar manifold, will be provided by the Shell Surveydepartment prior to commencement of operations. All survey data shall be based on InternationalSpheroid, European Datum 1950 (ED50), Transverse Mercator Projection. For UK Sector CentralMeridian is 0 degrees East. Reference Section 1, Chapter 2, Figure 1, for further datum shiftparameters.

On ROV arrival at the worksite, it should be established that the correct manifold has been identified,by use of suitable markings on the manifold itself, or by use of the Shell survey data provided, and/orfield layout drawings to provide other suitable means of confirmation. The Shell OffshoreRepresentative is to be consulted should no markings be present, and the latter method is used toconfirm that the correct manifold has been identified.

If doubt persists as to the correct identification of the manifold, then a positional fix is to be taken of the

as-built fix co-ordinate position, which may not be the centre of the manifold. Should this fix disagree

with the workscope stated position by more than +/-5m, then initiate checks to resolve errors. Such

checks should confirm that the vessel's positioning system has been suitably calibrated.

If required a spin check should be carried out to verify the USBL positioning system. If the spread of

the position data is more than the accuracy of the positioning systems (i.e. DGPS 1-3m & USBL 1% ofwater depth) checks should be initiated to resolve errors. Prior to this, a CTD profile of the full watercolumn should be observed and the relevant data entered into the USBL system.


The ROV will carry out, and fully video record, a general visual inspection of the manifold iglooprotection structure location (See Fig.2). The purpose of this inspection is to record the following:


(2) An overall view of the igloo (use of SIT camera) from all sides. This inspection is to check forany gross damage or debris, and to confirm the area is safe for further intervention (VI-ROV).



(4) Loose or displaced panels paying particular attention of the seating of panels at the roofinterface.

(5) The entry and exit of the pipelines to the structure, for any evidence of pipeline movement orpanel settlement.


(7) Location and condition of any concrete covers, submats or grout bag supports.

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(8) CP readings on four corners of the structure, proximity or contact, and of the roof and four sidepanels. (CP-PRX).


(10) General views are required of the approaches of each pipeline out to 5m from the igloo, or to

the start of protection mattresses, which ever is the lesser. The inspection is to confirm thepresence and integrity of any supports, protection bags/mats or point of burial.


3.4 Internal Survey (VI-GVI)

The igloo structure has been fabricated to allow easy access for ROV intervention and therefore willnot necessitate diver assistance with opening access panels.

On gaining entry to the interior of the igloo the ROV will carry out and fully video record, a generalvisual inspection of the original Spar manifold and internal walls of the protection igloo (See Figs 3 and

4). The purpose of this inspection is to record the following:

CAUTION: In the event of a leak being discovered, the ROV is to identify the leak source,the rate of leakage and any damage associated with the leak. All leaks are to betreated as ‘C1’ anomalies and immediately reported to the Shell OffshoreRepresentative.

(1) Pipework. All pipework for corrosion and leaks. Particular attention is to be given to the pipeguides with any evidence of pipe movement to be reported. Pipework schematic is shown onFig. 3.

(2) Valves (CH-VLV). Each of the 6 external valves (Fig. 3) are to be visually inspected. Any leaksor evidence of leaks is to be reported. Where visible, all valve positions are to be noted onvideo. These however are not required to be recorded in the Job Completion report.

(3) Blind Flange. The flanges on the 2 x 16” and 4 x 4” valves are to be inspected for anyevidence of oil leaks.

(4) Anodes (VI-AW). An inspection of all anodes located on the original spar manifold cover andon protection cover igloo frame work is to be carried out (Fig.4). The inspection is to record thefollowing:






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A CP reading is required of the pipework cover (Fig.3).

Where no areas of bare metal are evident, one CP reading is required on a typical area of majorpipework (preferably a flange) and a valve. Locations of these readings are to be recorded andused for repeat readings in future years.

In addition, CP readings are to be taken on two vertical (including diagonals) and two horizontaltubulars. With respect to igloo inspection by ROV, where the internal framework is the same asthe external framework, these readings are not required, as they have been covered by the CPstaken as part of the external inspection.

Positions where readings are obtained, including bare metal and tubular CPs are to be clearlyshown on structural drawings.



3.5 Final Report






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Figure 1 Brent Spar Manifold Igloo Field Location

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E

A S T F A C E

P A N E L

S O U T H F A C E

P A N E L

N O R T H F A C E

P A N E L

W E S T F A C E

P A N E L

M A N I F O L D

C O V E R

R O O F

P A N E L

F R O M

B R E N T

B R A V O

1 6 " O I L L I N E

F R O M B R E N T

A L P H A

N

B 1

B 2

A 2

A 1

W E S T F A C E

P A N E L

1 6 " O I L L I N E

Figure 2 General Layout of Brent Spar Manifold Igloo

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N

V A L V E

N o .

V A L V E D E S C R I P T I O N

V A L V E

T Y P E

N O R M A L O P E R A T I N G

S T A T U S

A S

F O U N D S T A T U S

V - A

1 6 " B A L L V A L V E

C A M E R O

O P E

V - B

1 6 " B A L L V A L V E

C A M E R O

O P E

V - C

1 6 " B A L L V A L V E

C A M E R O N / S H A F E

R A C T U A T O R

C L O S E

V - D

1 6 " B A L L V A L V E

C A M E R O N / S H A F E

R A C T U A T O R

C L O S E

V - E

4 " 3 0 0 # B A L L V A L V E

C L O S E

V - F

4 " 3 0 0 # B A L L V A L V E

C L O S E

V A L V E E

B L I N D

F L A N G E S

V A L V E B

F R O M

B R E N T A L P H A

V A L V E F

V A L V E D

B L I N D

F L A N G E S

V A L V E C V

A L V E A

V A L V E G

V A L V E H

F R O M

B R E N T B R A V O

B L I N D

F L A N G

E S

C O V E R C U T A W A Y

F O R C L A R I T Y

V - G

4 " 3 0 0 # B A L L V A L V E

C L O S E

V - H

4 " 3 0 0 # B A L L V A L V E

C L O S E

Figure 3 Brent Spar Manifold - Pipework Schematic and Valve Status

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I 91 008 Am 04 04/08Page 8 of 8

B 1

A 1

B

2

A

2

E A S T F A C E

P A N E L

S O U T H F A C E

P A N E L

N O R T H F A C E

P A N E L

W E S T F A C E

P A N E L

M A N I F O L D

C O V E R

B

P L A N O N R O O F S U P P O R T F R A M E

P L A N O N P R O T E C T I O N C O V E R

S E C T I O N A L O N G G R I D L I N E 1

( L O O K I N G W E S T )

S E C T I O N A L O N G G R I D L I N E 2

( L O O K I N G E A S T )

S E C T I O N A L O N G G R I D L I N E A

( L O O K I N G S O U T H )

S E C T I O N A L O N G G R I D L I N E B

( L O O K I N G N O R T H )

A N O D E O N U N D E R S I D E

O F M E M B E R

1

2

A

1

2

2

1

B

A B

A

Figure 4 Brent Spar Manifold Igloo - Anode Locations



0153-001

PROCEDURE I 91 009

IGLOO INSPECTION – OSPREY TO DUNLIN A

FLOWLINE BUNDLE CARRIER PIPE

1 INTRODUCTION

The work method is to be applied to the external and internal inspection of the towheads, intermediatetowhead and trailheads on the 31.5”/38” Osprey to Dunlin A flowline bundle carrier pipe (N0904). Thework will include damage inspection, scour inspection, leak monitoring, Cathodic Potentialmeasurements, anode inspection and video inspection.

Midpoint Trailhead No 3 is situated at KP3.330 on the 38inch Osprey to Dunlin A flowline bundlecarrier pipe No 1 (COABIS Code and IBIS Incident No 246) at position E583966 N6797398.

Production Towhead No 4 is situated at KP6.192 on the 31.5/38 inch Osprey to Dunlin A flowlinebundle carrier pipe No 1 (COABIS Code and IBIS Incident No 476), to the west of the Ospreyproduction cluster, at position E582779 N6799984.

Water Injection Towhead No 5 is situated at KP6.559 on the 31.5 inch Osprey to Dunlin A flowlinebundle carrier pipe No 1 (COABIS Code and IBIS Incident No 511), to the west of the Osprey WaterInjection cluster, at position E582779 N6800342.

Trailhead No 6 at Dunlin Alpha is situated at KP0.049 on the 38 inch Osprey to Dunlin A flowlinebundle carrier pipe No 2 (COABIS Code and IBIS Incident No 1) at position E585573 N6794559.

Midpoint Towhead No 7 is situated at KP3.290 on the 38 inch Osprey to Dunlin A flowline bundlecarrier pipe No 2 (COABIS Code and IBIS Incident No 244) at position E583972 N6797357.

Reference Figure Number 1 for Trailhead and Towhead Locations.

NOTE: Due to their configuration, all of the above towheads/trailheads may be inspected by ROV.

Towheads 4 and 5 are open structures, which allow for internal ROV inspection. There may howeverbe a requirement for closer diver inspection, including wall thickness readings.

Trailhead 6 is also an open structure, which allows for ROV inspection, but with restricted internalviews due to its size. Diver internal inspection is preferred.

Towheads 3 and 7 are enclosed structures, and are typically restricted to ROV external inspection.Internal specific points of interest are pipework and flanges only. These items would not warrantinternal inspection of their own accord. Diver internal inspection would only be required for pipework

WT readings. Diver access panels have been cut into the roof of these protection structures, butprevious interventions have proposed that these hatches be enlarged prior to future diver intervention.

NDT methods under Procedures 15 002 may be employed in conjunction with this procedure.

2 TASK OPTIONS

2.1 Standard Tasks


2.2 External


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CP-PRX - Cathodic Potential Proximity Measurements

DM-SCR - Scour Inspection


2.3 Internal






MG-GEN - Marine Growth Inspection


2.4 Optional Tasks



Should anomalies be noted, they are to be reported and acted upon as per Section 2, Chapter 6,

‘Anomaly Reporting & Criteria’, and as directed by the Shell Offshore Representative.


NOTE: Refer to figures below and to the Igloos and Subsea Facilities UMDB (0144-001),Section 16 for drawings and component numbering details relevant to the OspreyTowheads.

For Towheads 4 and 5 also refer to the Osprey/Merlin Subsea Facilities UMDB(5014-001), Part 2 for drawings and component numbering.




Survey data, including the position of the igloo to be inspected, will be provided by the Shell Surveydepartment prior to commencement of operations. All survey data shall be based on InternationalSpheroid, European Datum 1950 (ED50), Transverse Mercator Projection. For UK Sector CentralMeridian is 0 degrees East. Reference Section 1, Chapter 2, Figure 1, for further datum shiftparameters.

On ROV arrival at the worksite, it should be established that the correct igloo has been identified, byuse of suitable markings on the igloo itself, or by use of the Shell survey data provided, and/or fieldlayout drawings to provide other suitable means of confirmation. The Shell Offshore Representative is

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to be consulted should no markings be present, and the latter method is used to confirm that thecorrect igloo has been identified.

If doubt persists as to the correct identification of the igloo, then a positional fix is to be taken of the as-built fix co-ordinate position, which may not be the centre of the igloo. Should this fix disagree with theworkscope stated position by more than +/-5m, then initiate checks to resolve errors. Such checks

should confirm that the vessel's positioning system has been suitably calibrated.


3.3 External Inspection (VI-GVI)

The ROV will carry out, and fully video record, a general visual inspection at the workscope specified

towhead or trailhead location. The purpose of this inspection is to record the following:


(2) An overall view of the igloo (use of SIT camera) from all sides. This inspection is to check forany gross damage or debris, and to confirm the area is safe for further intervention (VI-ROV). Iffurther diver intervention is planned, results of this inspection are to be relayed to the diversupervisor as required.



(4) Loose or displaced panels paying particular attention to the seating of panels. Check all hinges.

NOTE: Trailhead 3: In 2006 displaced panels to the South end were replaced with one panel.

This panel and the East and West sides were extensively protected by mattresses(See Fig. 2).

Towhead 7: In 2006 displaced panels to the North end were replaced with one panel,as was the SW panel No.6. Protection mattresses were also installed (See Fig. 3).

(5) CP readings on four corners of the structure, proximity or contact (CP-PRX).

(6) The entry and exit of the pipelines, Coflexip lines and umbilical to the structures, for anyevidence of movement or door settlement.



(9) General views are required of the approaches of each pipeline out to 5m from the igloo, or tothe start of protection mattresses, which ever is the lesser. The survey is to confirm thepresence and integrity of any supports, protection bags/mats or point of burial.


3.4 Internal Inspection (VI-GVI)

When a diver enters the structure, a second diver must remain at the entrance and act as tender.

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3.4.1 Trailhead No 3 (Incident No. 246)

The buoyancy tanks have been removed from this trailhead and a protective structure fitted over thestructure and as a result access inside the igloo is severely restricted (See Fig. 4).

Internal inspection should normally not be specified for this trailhead due to restricted access

problems. However if internal inspection is specified in the workscope, this would require diverintervention, and the following applies.

A panel, 700mm x 600mm, has been cut in the roof panel to allow diver access. This panel can beremoved by diver without the aid of lift bags (CN-RPL). The panel has previously been secured by Ty-Wraps. However, previous attempts to enter through this panel was dismissed as too restrictive andthe suggestion made that this hole be enlarged. An assessment as to whether safe to enter, needs tobe made on site.

It may be that an alternative to access through the roof panel is to remove some of the protectionpanels and mattresses. In 2006 displaced panels to the South end were replaced with one panel. Thispanel and the East and West sides were extensively protected by mattresses (See Fig. 2). Themethod for removing panels and mattresses will be specified in the workscope.

On gaining entry to the interior of the structure the diver will carry out and fully video record, a generalvisual inspection of the pipework installation and internal framework of the structure. The purpose ofthis inspection is to record the following:


(1) PIPEWORK. All pipe work for corrosion and leaks. Particular attention is to be given to the pipesupports with any evidence of pipe movement to be reported.

(2) FLANGES. Each of the flanges is to be visually inspected. Any leaks or evidence of leaks are tobe reported.

(3) Anodes (VI-AW). Carry out an inspection of any anodes which may be located on the side wallpanels and under the roof panels of the protection structure (See Fig. 9). The inspection is torecord the following:


Refer to Procedure I 60 004 – Cathodic Protection Monitoring, in particular section 4.1.2




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Where no areas of bare metal are evident, one CP reading is required on a typical area of majorpipework (preferably a flange) and on the towhead structure. Locations of these readings are to

be recorded and used for repeat readings in future years.

Positions where readings are obtained, including bare metal and tubular CP’s are to be clearlyshown on structural drawings.



3.4.2 Intermediate Towhead No 4 (Incident No. 476)

Intermediate towhead No 4 is an open structure with no protection covers fitted and still has itsbuoyancy structures attached. There is relatively unrestricted access to all the components inside thisstructure (See Fig. 5).

On gaining entry to the interior of the structure the diver or ROV, as access allows, will carry out andfully video record, a general visual inspection of the pipework installation and internal walls of thestructure. The purpose of this inspection is to record the following:



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A CP reading is required of each of the major internal components PJB, UETAP and UTA.


Where no areas of bare metal are evident, one CP reading is required on a typical area of majorpipework (preferably a flange) and on the towhead base. Locations of these readings are to berecorded and used for repeat readings in future years.




3.4.3 Towhead No 5 (Incident No. 511)

Towhead No 5 is an open structure with no protection covers fitted and still has its buoyancystructures attached. There is relatively unrestricted access to all the components inside this structure(See Fig. 6).

On gaining entry to the interior of the structure the diver or ROV, as access allows, will carry out andfully video record, a general visual inspection of the pipework installation and internal framework of thestructure. The purpose of this inspection is to record the following:



(2) FLANGES. Each of the flanges is to be visually inspected. Any leaks or evidence of leaks is tobe reported.

(3) WATER INJECTION JUNCTION BOX (WIJB). The WIJB is to be visually inspected. Any leaks,evidence of leaks or any damage is to be reported.

(4) UMBILICAL EXTENSION TERMINATION ASSEMBLY WATER INJECTION (UETAW). TheUETAW is to be visually inspected. Any leaks or evidence of leaks is to be reported. Themodule’s attachment to the water injection guidebase is to be checked for security as is theumbilical attachment to the module and its seal at the 31.5” flowline bundle carrier pipe.

(5) HUB CONNECTOR. Check the hub connectors between the WIJB and UETAW to check on itsintegrity and for leaks.

(6) UMBILICAL. Check the umbilical between the bundle and UETAW, for integrity and for leaks.

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(7) Anodes (VI-AW). Carry out an anode inspection of the 4 anodes located on two sides of thebase supporting the WIJB and UETAW (See Figure 6) and on the remainder of the structure.The inspection is to record the following:

(a) The presence and location of the anodes are to be confirmed as per as-built layoutdrawings, and are to be confirmed as specified. Give an estimated average range of the

anode wastage.













A CP reading is required of each of the major internal components WIJB and UETAW.






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3.4.4 Trailhead No 6 (Incident No. 1)

Trailhead No 6 is an open structure with no protection covers fitted and still has its buoyancystructures attached (See Fig. 7).

Views of the internal components are restricted to those obtained from outside by ROV. Divers will

have better access for more detailed inspection.

On gaining entry to the interior of the structure the diver or ROV, as access allows, will carry out andfully video record, a general visual inspection of the pipework installation and internal walls of thestructure. The purpose of this inspection is to record the following:


(1) PIPEWORK. All pipe work for corrosion and leaks. Particular attention is to be given to the pipesupports with any evidence of pipe movement to be reported. Pipework schematic is shown inFigure 7.

(2) FLANGES: Each of the flanges is to be visually inspected. Any leaks or evidence of leaks is tobe reported.

(3) Anodes (VI-AW). Carry out an anode inspection of the structure. The inspection is to record thefollowing:






0-5% LOSS - ANODE AS NEW, WITH CORNERS WELL

DEFINED AND NO PITTING.






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3.4.5 Towhead No 7 (Incident No. 244)

The buoyancy tanks have been removed from this trailhead and a protective structure fitted over thestructure and as a result access inside the igloo is severely restricted (See Fig. 8).

Internal inspection should normally not be specified for this trailhead due to restricted accessproblems. However if internal inspection is specified in the workscope, this would require diverintervention, and the following applies.

A panel, 700mm x 600mm, has been cut in the roof panel to allow diver access. This panel can beremoved by diver without the aid of lift bags (CN-RPL). The panel has previously been secured by Ty-Wraps. However, previous attempts to enter through this panel was dismissed as too restrictive andthe suggestion made that this hole be enlarged. An assessment as to whether safe to enter, needs tobe made on site.

It may be that an alternative to access through the roof panel is to remove some of the protectionpanels and mattresses. In 2006 displaced panels to the North end were replaced with one panel, aswas the SW panel No.6. Protection mattresses were also installed (See Fig. 3). The method forremoving panels and mattresses will be specified in the workscope.

On gaining entry to the interior of the structure the diver will carry out and fully video record, a generalvisual inspection of the pipework installation and internal framework of the structure. The purpose ofthis inspection is to record the following:


(1) PIPEWORK. All pipe work for corrosion and leaks. Particular attention is to be given to the pipe

supports with any evidence of pipe movement to be reported.

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(2) FLANGES. Each of the flanges is to be visually inspected. Any leaks or evidence of leaks is tobe reported.

(3) Anodes (VI-AW). Carry out an inspection of any anodes which may be located on the side wallpanels and under the roof panels of the protection structure (See Fig. 10). The inspection is torecord the following:














Where no areas of bare metal are evident, one CP reading is required on a typical area of majorpipework (preferably a flange) and on the towhead structure. Locations of these readings are tobe recorded and used for repeat readings in future years.




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3.4.6 Final Report







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Figure 1 Osprey General Arrangement



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Figure 2 General Layout of Trailhead No 3 Igloo

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Figure 3 General Layout of Towhead No 7 Igloo

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Figure 4 Trailhead Number 3 – Pipework Schematic

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Figure 5 Intermediate Towhead Number 4 – Pipework Schematic

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Figure 6 Towhead Number 5 – Pipework Schematic

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Figure 7 Trailhead Number 6 – Pipework Schematic

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Figure 8 Towhead Number 7 – Pipework Schematic

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Figure 9 Trailhead Number 3 – Anode Distribution

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Figure 10 Towhead Number 7 – Anode Distribution



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PROCEDURE I 93 001

PIPELINE PROTECTION FRAME INSPECTION

1 INTRODUCTION

The work is to be applied to the external and internal inspection of the Gas Pipeline Protection Frameon the 10 inch North Cormorant to Western Leg Gas Pipeline and the associated pipeline flange. TheProtection Frame was installed to protect a repaired flange on this line. The work will include damagesurvey, Cathodic Potential (CP) measurements, anode survey and video survey.

The pipeline protection frame is situated at KP 22.132 on the 10 inch North Cormorant to Western LegGas Pipeline (Pipeline/COABIS - Code N0602/IGL02 (IBIS Incident No 30005)) at position E561443N6769378.

2 TASK OPTIONS

2.1 External






2.2 Internal











Note: Refer to figures below and to the Igloos and Subsea Facilities UMDB (0144-001),Section 2 for drawings and component numbering details relevant to the Western LegProtection Frame.

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Survey data, including the position of the Protection Frame, will be provided by the Shell Surveydepartment prior to commencement of operations. All survey data shall be based on InternationalSpheroid, European Datum 1950 (ED50), Transverse Mercator Projection. For UK Sector CentralMeridian is 0 degrees East. Reference Section 1, Chapter 2, Figure 1, for further datum shiftparameters.

On ROV arrival at the worksite, it should be established that the correct igloo has been identified, byuse of suitable markings on the igloo itself, or by use of the Shell survey data provided, and/or fieldlayout drawings to provide other suitable means of confirmation. The Shell Offshore Representative isto be consulted should no markings be present, and the latter method is used to confirm that thecorrect igloo has been identified.

If doubt persists as to the correct identification of the igloo, then a positional fix is to be taken of the as-built fix co-ordinate position, which may not be the centre of the igloo. Should this fix disagree with the

workscope stated position by more than +/-5m, then initiate checks to resolve errors. Such checks




The ROV will carry out, and fully video record, a general visual survey of the pipeline ProtectionFrame. The purpose of this survey is to record the following:


(2) An overall view of the igloo (use of SIT camera) from all sides. This inspection is to check forany gross damage or debris, and to confirm the area is safe for further intervention (VI-ROV).Results of this inspection are to be relayed to the diver supervisor.


(3) Structure and Expamet (Concrete side/seabed panels) for any evidence of impact damage.Check for leaks.

(4) Pile attachment hold down points.

(5) The entry and exit of the pipeline to the Protection Frame for evidence of pipeline movement orcover settlement.

(6) Scour around the base of the Protection Frame (DM-SCR). Note: There are specific anomalycriteria with respect to igloo scour. See Section 2, Chapter 6, Point 2.3.12.

(7) CP readings on four corners of the two Protection Frames, and a typical access panel/door foreach frame, proximity or contact (CP-PRX).


I 93 001 Am 04 04/08Page 2 of 7



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(9) General views are required of the approaches of the pipelines out to 5m from the igloo, or to thestart of protection mattresses, which ever is the lesser. The inspection is to confirm thepresence and integrity of any supports, protection bags/mats or point of burial.


3.4 Access Hatches and Doors (CN-RPL)

WARNING: PRIOR TO ATTEMPTING TO OPEN ANY OF THE FOUR DOORS OR TWELVEHATCHES A CLOSE VISUAL INSPECTION OF ALL LIFTING POINTS IS TO BECARRIED OUT. SHOULD THE INSPECTION REVEAL ANY ANOMALIES ORDAMAGE THEN AN ALTERNATIVE LIFTING POINT IS TO BE USED.

For the ROV and diver to gain access to the Protection Frame, it will be necessary for one of thetwelve hatches or four doors to be opened. Hatch and door positions are shown on Fig 2. Oncompletion of the lifting point inspection the diver is to open the access doors or hatches.

In the past access has been gained through hatch W7, which is open, or hatch E4 which could be

removed by diver without the aid of rigging or lift bags. Alternatively, the doors or hatches are to beremoved using either of the methods described below.

3.4.1 Access Door E1, E8, W1 and W8

(1) Install a 250kg lift bag to the door. Use necessary hold back, inversion and dump lines. Inflatebag slowly until door opens.

(2) When door is open, secure to Protection Frame with 1 inch diameter polypropylene rope toprevent door accidentally closing. At the start of each dive, the lift bag is to be checked and re-inflated as necessary.

3.4.2 Access Hatch E2-E7 and W2-W7

(1) Install a 100kg lift bag to the upper section of the hatch. Use necessary hold back, inversionand dump lines. Inflate bag slowly until hatch opens.

(2) When hatch is open, secure to Protection Frame with 1 inch diameter polypropylene rope toprevent hatch accidentally closing.

(3) Repeat (1) and (2) for lower hatch. At the start of each dive, the lift bags are to be checked andre-inflated as necessary.

NOTE: ROV to monitor and video record the door opening operation (VI-ROV).


When a diver enters the Protection Frame, a second diver must remain at the entrance and act astender.

On gaining entry to the interior of the Protection Frame, the diver or ROV, as access allows, will carryout and fully video record, a general visual survey of the pipeline, flange and internal walls of theProtection Frame. The purpose of this survey is to record the following:

CAUTION: In the event of a leak being discovered, divers should be withdrawn from thearea and an ROV inspection should be carried out to identify the leak source,the rate of leakage and any damage associated with the leak. All leaks are to betreated as 'C1' anomalies and immediately reported to the Shell Offshore

Representative.

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(1) Pipework. Pipework for corrosion and leaks. Check pipeline is fully supported by grout bagsupports.

(2) Flange. The repaired flange for evidence of gas leaks.

(3) Anodes (VI-AW). Carry out an anode inspection on the anodes which are located on the side

wall panels and under the roof panels. The inspection is to record the following:

(a) The presence and location of the anodes are to be identified, and any indication ofmissing anodes to be reported. Give an estimated average range of the anode wastage.











Where Reference Proximity readings are taken, an initial contact reading is required. Allsubsequent readings are to be proximity, unless doubts exist as to the electrical continuity of the

locations of the subsequent readings.

During the internal inspection of the protection cover internal wall and piles, should significantareas of bare metal or corrosion be noted cathodic potential readings are to be recorded.Where these areas occur, readings to be restricted to one CP per component.

Where no areas of bare metal are evident, one CP reading is required on a typical area of majorpipework (preferably a flange) and on the protection structure. Locations of these readings areto be recorded and used for repeat readings in future years.


(5) Close Hatch (CN-RPL). On completion of all internal inspection work the doors and hatchesare to be closed in reverse order to opening procedure. Ensure all diving umbilicals and ROVtether are clear of the door or hatch before closing.

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Hatch W7 is to be left open.

NOTE: ROV to monitor and video record the door or hatch closing operation.

(6) The ROV will carry out, and fully video record, a general visual survey of the Protection Frame,paying particular attention to the final placement of doors and hatches and fit up.


3.6 Final Report






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THER

PROTECTION COVER

E561446N6769400

WELGAS TEEIGLOO No.2

(8inch AND 10inch)

CORMORANT A

NORTH CORMORANT

10inch GAS LINE

BRENT AWELGAS TEEIGLOO No.1

NW HUTTON

NORTHNINIAN

SPLITTER BOXIGLOOSSIV IGLOOSSIV IGLOO

SSIV IGLOO


NORTH CENTRAL

(STRATHSPEY)

HEA

Figure 1 Pipeline Protection Frame Field Location

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Am 04 04/08 I 93 001Page 7 of 7

W 8

W 7

W 6

W 5

W 4

W 3

W 2

W 1

E 8

E 7

E 6

E 5

E 4

E 3

E 2

E 1

F R A M E N O .

2

F R A M E N O .

1

T O N O R T H

C O R M O R A N T

P L A N O

N P R O T E C T I O N

1 0 i n c h G A S L I N E

W E L G A S

T E E

I G L O O N

o .

2

P I L E S

V I E W L

O O K I N G E A S T

S E C T I O N L O O K I N G N O R T H

N O T E : W 7 H A T C H

L E F T O P E N F O R A C C E S S

Figure 2 General Arrangement of Pipeline Protection Frame



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PROCEDURE I 98 001

CONCRETE PROTECTION COVERS AND PBSJ INSPECTION

1 INTRODUCTION

The work method is to be applied to the external and internal inspection of concrete protection coversand the inspection of the Pressure Balanced Safety Joint (PBSJ) and tie-in flanges within the concreteprotection covers. The work will include damage survey, scour survey, pipeline movement monitoring,leak monitoring, Cathodic Potential (CP) measurements and video survey.

PBSJ's are installed at the Northern and Southern ends of the two 8” oil pipelines, N 0705 and N 0706,KP 0.080 and 6.800, 0.180 and 6.917 respectively and at the Northern and Southern ends of the TFLlines, N 0703/N 0704, KP 0.115 and 6.763, between the Underwater Manifold Centre (UMC) and theCormorant A Platform. N0703 and N0704 are twinned, with the PBSJ’s for each line within the sameprotection cover. The positions and IBIS incident (anomaly) numbers of these PBSJ’s are as follows(as reported from the 2005 pipeline inspection):

NOTE: The TFL lines are at present redundant.

N0703/N0704 – Cormorant ‘A’ to UMC 3” TFL (Both PBSJ’s are reported under N0703)

Incident No. K.P. Depth Description Co-ordinates

IN551 0.115 149m PBSJ at CA End E 557976 N 6774907

IN234 3.422 154m Mid Line Tie-In CA End E 558598 N 6778153

IN232 3.457 155m Mid Line Tie-In UMC End E 558610 N 6778186

IN635 6.763 153m PBSJ at UMC End E 559685 N 6781312

N0705 – Cormorant ‘A’ to UMC 8” OFL East






N0706 – Cormorant ‘A’ to UMC 8” OFL West






The coordinates are as observed from the 2005 ROV inspection, and will have a nominal tolerance ofapproximately +/- 5m.



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I 98 001 Am 04 04/08Page 2 of 12

2 TASK OPTIONS

2.1 External





2.2 Internal





CP-PRX/CON - Contact Cathodic Potential Measurements


Any number or combination of the listed work tasks, or those listed under Procedure I 15 001, may beused or called for on the workscope or during the course of the inspection.




NOTE: Refer to figures below and to the Igloos and Subsea Facilities UMDB (0144-001),Sections 11, 12 and 13 for drawings and component numbering details relevant to theCovers and PBSJ’s.




Survey data, including the position of the covers and PBSJ’s, will be provided by the Shell Survey

department prior to commencement of operations. All survey data shall be based on InternationalSpheroid, European Datum 1950 (ED50), Transverse Mercator Projection. For UK Sector CentralMeridian is 0 degrees East. Reference Section 1, Chapter 2, Figure 1, for further datum shiftparameters.

On ROV arrival at the worksite, it should be established that the correct cover has been identified, byuse of suitable markings on the cover itself, or by use of the Shell survey data provided, and/or fieldlayout drawings to provide other suitable means of confirmation. The Shell Offshore Representative isto be consulted should no markings be present, and the latter method is used to confirm that thecorrect cover has been identified.



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Am 04 04/08 I 98 001Page 3 of 12

If doubt persists as to the correct identification of the cover, then a positional fix is to be taken of the

as-built fix co-ordinate position, which may not be the centre of the cover. Should this fix disagree with

the workscope stated position by more than +/-5m, then initiate checks to resolve errors. Such checks


If required a spin check should be carried out to verify the USBL positioning system. If the spread of

the position data is more than the accuracy of the positioning systems, (i.e. DGPS 1-3m & USBL 1% ofwater depth) checks should be initiated to resolve errors. Prior to this, a CTD profile of the full watercolumn should be observed and the relevant data entered into the USBL system.


The ROV will carry out, and fully video record, a general visual survey of the concrete protection coverlocation. The purpose of this survey is to record the following:

(1) Confirm cover identification if present.

(2) An overall view of the cover (use of SIT camera) from all sides. This inspection is to check forany gross damage or debris, and to confirm the area is safe for further intervention (VI-ROV).Results of this inspection are to be relayed to the diver supervisor.


(3) Concrete covers for any evidence of impact damage, loose gravel or rocks.

NOTE: The description of any concrete damage or any anomalies discovered should bereported using standard terminology in accordance with the Department of Energy,Offshore Technical Reports entitled 'Classification and Identification of TypicalBlemishes Visible on the Surface of Concrete Underwater' - OTH 84 206 andOTH 87 261.

(4) Lifting bars and 'U' shaped link bars on concrete covers for damage and corrosion.

(5) The entry and exit of the pipeline to the concrete covers for evidence of pipeline movement or

covers touching the pipelines.

(6) Scour around concrete cover skirts (DM-SCR).


(8) General views are required of the approaches of the pipelines out to 5m from the cover, or to thestart of protection mattresses/rock dump, which ever is the lesser. The inspection is to confirmthe presence and integrity of any supports, protection bags/mats or point of burial.


3.4 Access Doors (CN-RPL)

WARNING: PRIOR TO ATTEMPTING TO OPEN THE ACCESS DOOR A CLOSE VISUAL ANDELECTROMAGNETIC INSPECTION OF THE LIFTING BAR AND HINGE PINS ONTHE ACCESS DOOR AND THE LIFTING PADEYES ON CONCRETE COVER (C2),TIRFOR ATTACHMENT POINTS, IS TO BE CARRIED OUT. SHOULD THEINSPECTION REVEAL ANY ANOMALIES OR DAMAGE THEN THE ATTACHMENTPOINT IS NOT TO BE USED, BUT IS TO BE REPLACED WITH A 'U' BOLTLIFTING ARRANGEMENT. REFERENCE FIGS 4 AND 5.

For the ROV and diver to gain access to the concrete covers it will be necessary for the access dooron the end closure unit to be opened. Door position and detail are shown on Figs 2, 3 & 4.



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I 98 001 Am 04 04/08Page 4 of 12

(1) On completion of the inspection the diver is to open the access door using the following method:

(a) Install a Tirfor (T508) between the lifting bar on the door and a padeye on the concretecover. Leave the Tirfors loose.

(b) Install one 250 kg lift bag on the door lifting bar. Inflate the bag slowly until the door opens.

(c) When the door is open and vertical, tighten the Tirfor to pull door past the vertical andsecure. Slowly deflate bag and lower door to lay flat on top of concrete cover.

NOTE: ROV to monitor and video record the door opening operation.


When a diver enters the concrete cover, a second diver must remain at the entrance and act astender.

On gaining entry to the interior of the concrete cover the diver or ROV, as access allows, will carry outand fully video record, a general visual survey of the PBSJ installation, or the mid-point Tie-In flanges,and internal walls of the concrete covers. The purpose of this survey is to record the following:

CAUTION: In the event of a leak being discovered, divers should be withdrawn from thearea and an ROV inspection should be carried out to identify the leak source, therate of leakage and any damage associated with the leak. All leaks are to betreated as 'C1' anomalies and immediately reported to the Shell OffshoreRepresentative.

(1) Pipework. Pipework for corrosion and leaks. Particular attention is to be given to the flangedconnections of the PBSJ, or the mid-point Tie-In flanges for signs of leaks. Leaks may bedetected by looking for deposits of hydrocarbons on the flanges and on the surrounding fittings,refer to Fig 6 for typical arrangement.

(2) Measure the distance between the PBSJ flanges. Refer to Fig 7 for typical values recorded.

(3) Indications of pipe movement.

(4) Internal damage to the concrete covers.



A CP reading is required on each PBSJ arrangement (Fig. 6).

During the internal inspection of the cover, should significant areas of bare metal or corrosion benoted, CP readings are to be taken and recorded. Where these areas occur, readings to berestricted to one CP per component.

Where no areas of bare metal are evident, one CP reading is required on a typical area of majorpipework (preferably a flange). Locations of these readings are to be recorded and used forrepeat readings in future years.




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(6) Close Hatch (CN-RPL). On completion of all internal inspection work the door is to be closed inreverse order to opening procedure. Ensure all diving umbilicals and ROV tether are clear of thedoor before closing.


(7) The ROV will carry out, and fully video record, a general visual survey of the concrete covers,

paying particular attention to the final placement of the door and fit up.


3.6 Final Report




Sketches are required, either scanned, AcadLT or other proprietary drawing format, of any major

defects or debris that cannot be suitably documented by anomaly report and digital images alone.



Am 04 04/08

Figure 1 Pressure Balanced Safety Joint (PBSJ) Field Location



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A

B

V I E W O

N A R R O W B

V I E W O

N A R R O W

A

X

X

S E C T I O N X - X

D I V E R A C C E S S D O O R

( S E E F I G . 3 )

Figure 2 General Layout of Concrete Protection Covers and PBSJ Pipework

Am 04 04/08 I 98 001Page 7 of 12



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1 0 m m 1 5 m m

1 6 5 m m

1 3 0 m m

6 5 0

m m

4 0 m m

8 0 m m

1 2 m m T H I C K G A L V A N I S E D

M I L D S T E E L P L A T E

2 0 0 m m L O N G E Y E - B O L T S

C A S T I N T O C O N C R E T E

S E C T I O N A - A

A A

8 0 m m

1 3 0 m m

M 2 0 B A R

M 2 0 M

I L D S T E E L B A R , 2 0 0 m m

L O N G

W E L D E D T O 1 2 T H I C K

M I L D S T E E L P L A T E U S I N G 6

T H I C K

C O N T I N U O U S F I L L E T

W E L D

1 5 m m

1 3 2 9 m m

Figure 3 Access Door Arrangement and Details

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7 5 m m

A

A

7 5 m m 7 5 m m

2 5 m m D I A . T Y P .

E D G E S G R O U N D

P L A N

V I E W O

N ' A - A '

3 7 m m

4 5 o

1 0 m m T H I C K

C O V E R

P L A T E

1 0 m m

Figure 4 Lifting Point Hole Dimensions

Am 04 04/08 I 98 001Page 9 of 12



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5mm

80mm

7 0 m m

R 4 0 m m

EXISTING DOOR

2 OFF M20 NUT

AND WASHERPEEN OVER

EDGES GROUND TO

ALLOW EYE TO LOWER

20mm DIA. BAR

FORMED TO U

10mm

140mm ( x 60mm )

Figure 5 Lifting Point General Arrangement

I 98 001 Am 04 04/08Page 10 of 12



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E N D F I T T I N

G 3 "

1 0 0 0 0 P S I

B R E A K A W A Y J O I N T

E N D F I T T I N G 3 "

5 0 0 m m 6

7 5 m

m

6 7 5 m m

5 0 0 m m

1 3 8 4 m m

2 7 3 4 m m

2 7 6 m m

Figure 6 Pressure Balanced Safety Joint (PBSJ) Typical Arrangement

Am 04 04/08 I 98 001Page 11 of 12



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1 5 m m

1 5 m m

1 5 m m

4 8 0 m

m

8 8 m m

1 1 3 0 m m

4 7 0 m m

1 3 m m

C O F L E X

P I P E L I N E

W E L L H E A D

8 8 m m

9 5 4 m m

Figure 7 PBSJ and Flange Measurements - Typical



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APPENDIX 1

REFERENCES

BS EN ISO 9934-1/2/3:2001/2002 Identical,

ISO 9934-1/2/3:2000/2002Identical

Non-destructive testing. Magnetic particle testing. General principle

(amendment AMD 14960)

EN ISO 3059:2001 Identical,

ISO 3059:2001 Identical

Non-destructive testing. Penetrant testing and magnetic particle testing. Viewing

conditions

EN ISO 9934-2:2002 Identical,

ISO 9934-2:2002 Identical

Non-destructive testing. Magnetic particle testing. Detection media

BS EN 60051-1:1999 Identical,

IEC 60051-1:1997 Identical

Direct acting indicating analogue electrical measuring instruments and their

accessories. Definitions and general requirements common to all parts

BS 667: 2005

(Replaces BS 667: 1996)

Illuminance meters. Requirements and test methods

BS 4331 Pt 1 2 3 Methods for assessing performance and 1972 1974 1978 characteristics of

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Documents

Standard Procedures for Underwater Engineering Operations