BRZ-GX-O-PL-0503 Pipeline Installation Procedure R1 2

HHI STD FORMAT: BRZ-GX-P-O-PL-0503 PL1 & PL3 PIPELINE INSTALLATION PROCEDURE

Agreement No. BAR-OFF-EPC-02

HHI Internal Project Ref. No.Q916

RasGas Company Limited

BARZAN OFFSHORE PROJECT

PL1 & PL3 PIPELINE INSTALLATION PROCEDURE

Document Classification : II

1 18.June.12 Approval for Construction 108 J.E.JUNG J.H.KIM K.S.SIM

0 29.May.2012 Approval for Construction 108 J.E.JUNG J.H.KIM K.S.SIM

C 04.May.2012 Issued for Approval 121 J.E.JUNG J.H.KIM K.S.SIM

B 08.Feb.2012 Issued for Approval 107 J.E.JUNG J.H.KIM K.S.SIMRev. Date Description Pages Prepared Checked Approved

PROJ FAC. Document Type Discipline SequenceNumber Modifier

RevisionCode

BRZ GX 0 PL 0503 J.E. JUNG 1

DOCUMENT TITLE


DOCUMENT Number

BRZ-GX-O-PL-0503 PROJ FAC. PAGE

2 of 48 REVISION

1 BRZ GX


Revision History

Revision Number Date Section(s) Page(s) Brief Description of Change

Author of Change

A 15.Nov.2011 All - Issued for Inter Discipline Check J.E.JUNG

B 08.Feb.2012 All 107 Issued for Approval J.E.JUNG

C 04.May2012 All 121 Issued for Approval J.E.JUNG

0 29.May.12 All Approval for Construction J.E.JUNG

1 18.June.12 All Approval for Construction J.E.JUNG

COMMENT SHEET

TRANSMITTAL No: BRZ-T-HURU-PL-0249BARZAN OFFSHORE PROJECT Name Date

AB 6-Jun-12BRZ-GX-O-PL-0503, REV 0 JEE 9-Jun-12II DPS

MSW 11-Jun-12SR No. HHI Response Close Out WR

Section Description Initial AWC

1Rev. C SN#7

2.1

Tee co-ordinates and KPs are still incorrect! The co-ordinates given are for the flange, not the tee.

AB

NotedAdded Tie-in and Spool to Tie-in coordination according toBRZ-W21IP-D-PL-0510 and BRZ-W23IP-D-PL-0510

MWS

2 5.4 - Table

Table has become confused. Drawing 0557 does notrelate to Tee32, tee co-ordinates and KP areincorrect.

AB

NotedAdded Tie-in and Spool to Tie-in coordination according toBRZ-W21IP-D-PL-0510 and BRZ-W23IP-D-PL-0510

3Rev. C SN#11

2.1

Comment has not been addressed in the latestrevision of the Field data Book - However, Companywill address this issue via comments to the Field DataBook.

AB

Noted. Will include Filed data book next revision

4Rev. C SN#13

4.5

Comment has not been addressed - the anodeattachment procedure will need to be re-qualified torepresent attachment to the 4.5/3.5-inch MEGpipelines. The existing coating contractor AB

NotedSubmitted BRZ-GX-O-PL-0795 Rev.B Thermit weldingprocedure for MEG pipelines on June 8.2012. perparedby supplier and coating contractor

Review Confirmation

DOC. NUMBER :DOC. CLASS :

PROJECT TITLE :DOC DESCRIPTION :

RG Comments

PL1 & PL3 Pipeline Installation Procedure

CRS (BRZ-GX-O-PL-0503)_R0.xls Page 1 of 1

4.5 p p g gqualification is not suitable since it was conducteddon the 32-inch line pipe.

by supplier and coating contractor.

5 General No comments JEE6 General No comments MSW

CODE: 2

Prepared By Andy Brady Prepared By

Signature Signature

Discipline Pipeline Engineer DisciplineDate 16-Jun-12 18-Jun-12 Date

RasGas HHI

CRS (BRZ-GX-O-PL-0503)_R0.xls Page 1 of 1

COMMENT SHEET

TRANSMITTAL No: BRZ-T-HURU-PL-0249BARZAN OFFSHORE PROJECT Reference No: GM/60016/BARZAN/0565 Name Date

AB BRZ-GX-O-PL-0503 ,Rev 0 JEEI DPS

WRAWC

SR No. HHI Response Close Out MWS 6-Jun-12Section Description Initial

1 2.5

Please include revision number for referenceddocuments for clarity. The approved anchor handlingprocedures states Hs=1.5m and 25kn wind speed aslimiting environment. Please update table to reflectthis.

AJNoted and amended according to approved anchorhandling procedure(BRZ-GX-O-PL-0516)

2 3 5 3

Please include full vessel names for thetransportation tugs. There is both a Miclyn Pearl anda PB Pearl, but no Pearly. Please clarify.

The Miclyn Power is specified to be used as atransportation vessel and is clubbed along with theother towing vessels. The Miclyn Power has not beenapporved for towing operations only as supportvessel. Please amend.

J

1. Miclyn Pearl , and PB pearl are correct Full name but do not have Pearly.2 Noted and amended

GM Comment

PL-1 PL-3 Pipeline Installation Procedure

Review Confirmation

DOC. NUMBER :DOC. CLASS :

PROJECT TITLE :DOC DESCRIPTION :

GM-60016-BARZAN-0565 (BRZ-GX-O-PL-0503 Rev 0) - PL1 PL3 Pipeline Installation Procedure.xls Page 1 of 1

2 3.5.3. a am n .

Please note that Miclyn 285 is still to be inspectedand approved.

Futher, Zakheer Fugro is shown as a supply vessel,however Global Maritime has not inspected andapproved this vessel, and it is no to be used for thisproject until it has been approved by GlobalMaritime. Please remove reference to the Zakheer

AJ 2. Noted and amended3. Miclyn 285 inspected on June 14. 2012 as perschedule.4. Removed Zakheer Fugrot

CODE: 2 - Approved with Comments

Prepared By Capt.Ajai Pillai Prepared By

Signature Signature

Discipline MWS DisciplineDate 6-Jun-12 18-Jun-12 Date

Global Maritime HHI

GM-60016-BARZAN-0565 (BRZ-GX-O-PL-0503 Rev 0) - PL1 PL3 Pipeline Installation Procedure.xls Page 1 of 1

DOCUMENT TITLE


DOCUMENT Number


3 of 48 REVISION

1 BRZ GX


Table of Contents 1.0 INTRODUCTION ...................................................................................................................................... 5

1.1 GENERAL ...................................................................................................................................... 5

1.2 FIELD LAYOUT .............................................................................................................................. 6

1.3 PURPOSE OF DOCUMENT .......................................................................................................... 7

1.4 DEFINITIONS AND ABBREVIATIONS .......................................................................................... 9

1.5 REFERENCES ............................................................................................................................. 10

2.0 GENERAL INFORMATION ................................................................................................................... 12

2.1 KEY FACILITIES LOCATIONS .................................................................................................... 12

2.2 MATERIAL DATA ......................................................................................................................... 13

2.3 PIPELINE DATA ........................................................................................................................... 14

2.4 ENVIRONMENTAL DATA ............................................................................................................ 18

2.5 WEATHER LIMITATION ............................................................................................................... 18

2.6 ALIGNMENT ................................................................................................................................ 18

3.0 OFFSHORE MANAGEMENT ................................................................................................................ 19

3.1 PMT ORGANOGRAM .................................................................................................................. 19

3.2 HD-423 ORGANIZATION............................................................................................................. 19

3.3 INSTALLATION SCHEDULE ....................................................................................................... 19

3.4 RESPONSIBILITIES .................................................................................................................... 20

3.5 MARINE SPREAD ....................................................................................................................... 23

4.0 GENERAL PIPE LAYING PROCEDURE .............................................................................................. 25

4.1 BARGE LAYOUT ......................................................................................................................... 25

4.2 MATERIAL TRANSFER & PREPARATION WORK ..................................................................... 26

4.3 WELDING & FILED JOINT COATING ......................................................................................... 29

4.4 BUNDLE WORK FOR PIGGY BACK LINES ............................................................................... 32

4.5 CATHODIC PROTECTION CABLE FOR PIGGYBACK LINES ................................................... 32

5.0 PL1 & PL3 PIPELAYING PROCEDURE ............................................................................................... 34

5.1 INITIATION ................................................................................................................................... 34

5.2 PIPELAYING ................................................................................................................................ 34

5.3 PIGGYBACK PIPELINE INSTALLATION PROCEDURE ............................................................ 36

5.4 LAYING WITH BAR- TEE OR FLANGE JOINT ........................................................................... 38

6.0 CONTINGENCY PROCEDURE ............................................................................................................. 39

DOCUMENT TITLE


DOCUMENT Number


4 of 48 REVISION

1 BRZ GX


6.1 ABANDONMENT ......................................................................................................................... 39

6.2 RECOVERY ................................................................................................................................. 40

7.0 APPENDIX ............................................................................................................................................. 43

7.1 APPENDIX.A: SPECIFICATION OF VESSELS........................................................................... 43

7.2 APPENDIX.B: DRAWINGS .......................................................................................................... 44

7.3 APPENDIX.C: LAYING EQUIPMENTS ....................................................................................... 48

DOCUMENT TITLE


DOCUMENT Number


5 of 48 REVISION

1 BRZ GX


1.0 INTRODUCTION

1.1 GENERAL

COMPANY intends to execute engineering, procurement, and construction (EPC) for Barzan Offshore

Topside and Pipelines facilities to develop natural gas reserves within the North Field located offshore

Qatar in the Arabian Gulf. The Project includes a natural offshore production system with conventional

wellhead platforms, intrafield pipelines, MEG pipelines, and power and fiber-optic subsea cables, as well

as export to the Barzan onshore Gas Plant located at RLC in Qatar.

The Barzan Offshore Project FACILITIES include three (3) offshore wellhead platforms designated BRZ-

WHP1, BRZ-WHP2, and BRZ-WHP3. Production from BRZ-WHP1 flows through a 32-inch diameter

Export Pipeline to shore. Production from BRZ-WHP3 flows through a second 32-inch diameter Export

Pipeline to shore. Production from BRZ-WHP2 can flow into either of the two (2) 32-inch diameter export

pipelines from BRZ-WHP1 or BRZ-WHP3 to shore.

Two (2) 24-inch diameter intrafield pipelines from BRZ-WHP2 connect to the two (2) 32-inch diameter

export pipelines at subsea tees located approximately 500 m from BRZ-WHP2.

Hydrate management is achieved by injecting mono-ethyleneglycol (MEG) into the production headers

on the wellhead platforms. MEG will be pumped through a 4.5-inch diameter pipeline from onshore to a

MEG supply header on BRZ-WHP2. MEG is then distributed through a 3.5-inch branch line from BRZ-

WHP2 to BRZ-WHP1 and through a 3.5inch branch line from BRZ-WHP2 to BRZ-WHP3 for injection

into the respective export pipelines as required. Figure 1.2 shows the general layout of the MEG pipeline

system.

DOCUMENT TITLE


DOCUMENT Number


6 of 48 REVISION

1 BRZ GX


1.2 FIELD LAYOUT

Figure 1.1 Barzan Offshore Facilites

DOCUMENT TITLE


DOCUMENT Number


7 of 48 REVISION

1 BRZ GX


Figure 1.2 General Layout of MEG and Piggy back Pipelines

1.3 PURPOSE OF DOCUMENT

The purpose of this procedure is to describe how the pipeline installation works to be conducted.

This procedure shows the execution plan of the pipeline works, the laying equipments and laying method

for PL1 & PL3 pipelines to ensure that the pipeline installation work sequence and typical laying method

associated with equipments are proper and efficient to this project.

The detail calculation and engineering is included in Pipeline Field Data Book (BRZ-GX-O-PL-0507)

which will be submitted separately.

PIPELAY BRZ-PL1 & PL3 Laying Analysis at Shore-Pull position of HD-423

BRZ-PL1 with Piggy back MEG line

BRZ-PL3 with Piggy back MEG line

TEE: TIE-IN TEE 12 & TIE-IN TEE 23

PL

PL

PL

PL

PL

DOCUMENT TITLE


DOCUMENT Number


8 of 48 REVISION

1 BRZ GX


Figure 1.3 Pipeline for BRZ-PL1 and BRZ-PL3 Export Pipelines

DOCUMENT TITLE


DOCUMENT Number


9 of 48 REVISION

1 BRZ GX


1.4 DEFINITIONS AND ABBREVIATIONS

Organisations API: American Petroleum Institute

DNV: Det Norske Veritas

HHI: Hyundai Heavy Industries Co. Ltd

RasGas: RasGas Company Limited

Facility Designations BRZ-WHP1 Barzan Offshore Project Wellhead Platform 1

BRZ-WHP2 Barzan Offshore Project Wellhead Platform 2

BRZ-WHP3 Barzan Offshore Project Wellhead Platform 3

Technical Terms CD Chart Datum

C.C Concrete Coating

CRA Corrosion-Resistant Alloy

FBE Fusion-Bonded Epoxy

HAT Highest Astronomical Tide

HDPF High Density Polyurethane Foam

Hmax Maximum Wave Height

Hs Significant Wave Height

ID Internal Diameter

IP Intersection Point

KP Kilometric Point

LAT Lowest Astronomical Tide

LTE Land Termination End

MEG Mono-Ethylene Glycol

MSL Mean Sea Level

MTO Material Take Off

N/A Not Applicable

OD Outside Diameter

RAO Response Amplitude Operator

SMYS Specified Minimum Yield Strength

SWL Specified Minimum Yield Strength

Tmax Maximum Time Period

Tp Spectral Peak Time Period

Tz Zero Crossing Period

WD Water Depth

DOCUMENT TITLE


DOCUMENT Number


10 of 48 REVISION

1 BRZ GX


WT Wall Thickness

1.5 REFERENCES

1.5.1 INTERNATIONAL CODES AND STANDARDS

DNV OS-F101 Submarine Pipeline Systems - 2010 API SPEC 5L Specification for Line Pipe

1.5.2 COMPANY DOCUMENTS

BRZ-EPL-16-B-PL6 Specification for Fusion Bonded Epoxy (FBE) External Corrosion Coating BRZ-EPL-16-B-65 Specification for Concrete Weight Coating for Linepipe BRZ-EPL-16-B-63 Specification for Pipeline and Riser Anodes BRZ-EPL-16-B-68 Specification for Field Joint Coating BRZ-EPL-16-B-34 Specification for Subsea Flanges, Bolts, Nuts and Gaskets BRZ-EPL-16-B-32 Specification for Subsea Piping Fittings BRZ-EPL-16-B-35 Specification for Subsea Barred Tee BRZ-EPL-16-B-95 Specification for Piggyback Saddle and Straps BRZ-EPL-16-B-96 Specification for Stockpiling and Handling Materials BRZ-EPL-16-B-79 Specification for Pre-Engineering Survey BRZ-EPL-16-B-80 Specification for Survey Operations (Pipeline Facilities) BRZ-EPS-16-B-05 Specification for Submarine Pipeline Installation BRZ-EPL-16-B-72 Specification for Welding of Carbon Steel Linepipe BRZ-EPL-16-B-87 Specification for Anchor Handling BRZ-EPL-16-B-90 Specification for Shore Approach BRZ-EPL-16-B-91 Specification for Trenching, Dredging and Backfilling Work BRZ-EPL-16-B-75 Specification for Pipeline Radiography and Other Non-Destructive Testing

(NDT) Services MARINE

BRZ-EPS-30-B-01 General Requirements for Marine Operations BRZ-EPS-30-B-02 Marine Transportation BRZ-EPS-30-B-03 Inshore and Offshore Lifting form Floating Vessels BRZ-EPS-30-B-04 Inspection and Audit of Marine Vessels BRZ-EPS-30-B-41 Diving Operations

1.5.3 REFERENCE PROCEDURE

BRZ-GX-O-PL-0501 Mooring Analysis Report For HD-423 BRZ-GX-O-PL-0507 PL1&PL3 Pipeline Field Data Book BRZ-GX-O-PL-0516 Anchor Handling Procedure

DOCUMENT TITLE


DOCUMENT Number


11 of 48 REVISION

1 BRZ GX


BRZ-GX-O-PL-0517 Anchor Pattern BRZ-GX-O-PL-0518 Anchor Pattern for crossing and trigger BRZ-GX-O-PL-0522 PL1 & PL3 Shore Approach Procedure BRZ-GX-O-PL-0523 Pipeline Crossing Installation Procedure BRZ-GX-O-PL-0667 Miscellaneous items Transportation BRZ-GX-O-PL-0619~628 Related Diving Procedure BRZ-GX-O-PL-0636 Procedure for Field Joint Coating and Infilling work BRZ-GX-O-PL-0756 Barge Positioning Services HD-423 BRZ-GX-O-PL-0757 ROV Touchdown monitoring Services BRZ-GX-O-PL-0774 Foam Infill to Field Joints BRZ-GX-O-PL-0775 ITP for FBE + HDPU BRZ-GX-O-PL-0776 HSE Plan(Survey) BRZ-GX-V-PIPE-P506_756 Quality Procedure for Fusion Bonded Epoxy Coating BRZ-GX-O-PL-0650 Welding procedure specification for Structural Installation BRZ-GX-O-PL-0651 Pre -welding procedure specification for Pipelines BRZ-GX-O-PL-0652 Welder Qualification Procedure BRZ-GX-O-PL-0654 Radiographic Inspection Procedure for Pipeline BRZ-GX-O-PL-0655 Execution plan for pipeline AUT system qualification BRZ-GX-O-PL-0659 Welding consumable control procedure BRZ-GX-O-PL-0660 Welding consumable batch test reports BRZ-GX-O-PL-0661 Procedure for Controlling of arc strikes BRZ-GX-O-PL-0663 Marine Operation Manual BRZ-GX-P-PL-0778 Manual Ultrasonic Inspection Procedure for Pipeline BRZ-GX-P-PL-0779 Magnetic Particle Inspection Procedure for Pipeline BRZ-GX-P-PL-0780 Dye Penetration Inspection Procedure for Pipeline BRZ-GX-O-PL-0668 pWPS for 32inch mainline BRZ-GX-O-PL-0731 pWPS for 32/24inch CRA line BRZ-GX-O-PL-0732 pWPS for MEG pipeline BRZ-GX-O-PL-0733 pWPS for 32inch mainline repair BRZ-GX-O-PL-0734 pWPS for 32/24inch CRA line BRZ-GX-O-PL-0735 pWPS for MEG pipeline repair BRZ-GX-V-PIPE-P506-758 Quality procedure for Anode Installation rev 1 BRZ-GX-V-PIPE-P510-801 Installation Manual Piggy Back Clamping System BRZ-GX-V-PIPE-P506-851 WPS & WPQR for Anode BRZ-GX-V-PIPE-P513-001 Pipeline Flange Drawing & Calculation BRZ-GX-V-PIPE-P510-001 Product Drawing (Piggyback saddle and Straps) BRZ-GX-V-PIPE-P510-801 Installation Manual (Piggyback saddle and Straps)

DOCUMENT TITLE


DOCUMENT Number


12 of 48 REVISION

1 BRZ GX


2.0 GENERAL INFORMATION

2.1 KEY FACILITIES LOCATIONS

1) Offshore Wellhead Platform Co-ordinates and WD Platform Easting (m) Northing (m) Heading () WD, LAT (m)

BRZ-WHP1 at Slot 7 585,932.49 2,940,361.34 338.1 51.9 BRZ-WHP2 at Slot 7 589,691.63 2,925,023.27 337.9 48.3 BRZ-WHP3 at Slot 7 593,824.08 2,916,955.10 337.8 42.3

2) Pipeline Reference Point

Location Easting (m) Northing (m) KP WD, LAT (m) TEE TIE-IN(BRZ-PL12) 589,379.18 2,925,453.18 16.671 48.0

SPOOL TIE-IN(BRZ-PL12) 589,382.28 2,925,454.03 16.677 48.0 TEE TIE-IN(BRZ-PL32 589,222.60 2,924,755.05 9.394 47.0

SPOOL TIE-IN(BRZ-PL32 589,225.13 2,924,753.07 9.390 47.0 BRZ-WYE1 (Dummy) Refer to Drawing BRZ-GX-O-PL-0555 Rev.1 BRZ-WYE3 (Dummyl) Refer to Drawing BRZ-GX-O-PL-0557 Rev.1

LTE at BRZ-PL1 551,567.74 2,869,713.13 88.734 +2.0 LTE at BRZ-PL3 551,571.27 2,869,711.25 81.309 +2.0

For the layout details, refer to drawing No. BRZ-GX-D-PL-0551, 0555&0557 and BRZ-W21IP-D-PL-

0510 andBRZ-W23IP-D-PL-0510 .

DOCUMENT TITLE


DOCUMENT Number


13 of 48 REVISION

1 BRZ GX


2.2 MATERIAL DATA

1) PL1 & PL3 Lines Description Units Parameters

Pipeline Name - BRZ-PL1 BRZ-PL3 Details - 32 Export Pipeline to Onshore Plant Flow Direction - BRZ-WHP1 to Onshore Plant

BRZ-WHP3 to Onshore Plant

Pipeline Internal Diameter mm 768.4 Service - Sour Material Grade - API 5L X65 (NACE) External Corrosion Coating Pipeline & Spool - 0.685mm FBE - Field Joint Coating Pipeline & Spool - FBE (field applied) - Field Joint Infill Material - PUF

2) Material Properties

Description Unit Parameter

Density of Steel kg/m3 7850

Density of FBE kg/m3 1400

Concrete Weight Coating

Density kg/m3 3044

Cutback mm 430 (32 Export Pipelines)

DOCUMENT TITLE


DOCUMENT Number


14 of 48 REVISION

1 BRZ GX


2.3 PIPELINE DATA

1) PL1 & Piggyback Lines Parameter Unit Description

BRZ-PL1 Pipeline Internal Corrosion Allowance mm 3.0 External Corrosion Coating - 0.685mm FBE

Field Joint Coating - FBE (Field Applied) Maximum Product Density kg/m3 365.8

BRZ-PL1 Piggyback Piggyback Pipeline - BRZ-MP21 (KP 0.0 KP 16.671) BRZ-MP2 (KP 16.671 KP 88.734)

Pipe Outer Diameter mm 88.9 114.3 Pipe Wall Thickness mm 7.6 7.6

Internal Corrosion Allowance mm 3.0 External Corrosion Coating - 0.4mm FBE

Field Joint Coating - FBE (Field Applied) Maximum Product Density kg/m3 1118

Note: The entire export pipeline shall have constant internal diameter.

DOCUMENT TITLE


DOCUMENT Number


15 of 48 REVISION

1 BRZ GX


PL1 Pipeline table

DOCUMENT TITLE


DOCUMENT Number


16 of 48 REVISION

1 BRZ GX


2) PL3 & Piggyback Lines Parameter Unit Description

BRZ-PL3 Pipeline Internal Corrosion Allowance mm 3.0 External Corrosion Coating - 0.685mm FBE

Field Joint Coating - FBE (Field Applied) Maximum Product Density kg/m3 365.8

BRZ-PL3 Piggyback (from KP 1.0 KP 9.394) Piggyback Pipeline - BRZ-MP23

Pipe Outer Diameter mm 88.9 Pipe Wall Thickness mm 7.6

Internal Corrosion Allowance mm 3.0 External Corrosion Coating - 0.4mm FBE

Field Joint Coating - FBE (Field Applied) Maximum Product Density (2) kg/m3 1118 Note: The entire export pipeline shall have constant internal diameter.

PL3 Pipeline table

DOCUMENT TITLE


DOCUMENT Number


17 of 48 REVISION

1 BRZ GX


3) Allowable Span Length (from BRZ-GX-T-PL-0010, Pipeline Free Span Analysis Report) Pipeline Maximum Allowable Free Span Summary for BRZ-PL1 Export Pipeline

KP Piggyback Pipeline

Recommended Minimum Allowable Free Span (m)

From To Installation Flooded Hydrotest Operating

0.000 0.500 BRZ-MP21

(3.5)

58.5 56.0 53.0 51.0

0.500 13.101 53.0 50.5 45.0 42.5

13.101 16.671 47.0 45.5 41.5 39.0

16.671 19.835

BRZ-MP2 (4.5)

46.0 45.0 41.5 39.0

19.835 30.926 46.0 45.0 41.5 37.5

30.926 39.786 47.0 45.0 42.0 38.0

39.786 53.262 40.5 40.0 35.0 31.5

53.262 73.239 40.5 40.0 34.0 31.5

73.239 80.101 37.0 37.0 29.5 26.5

80.101 86.434 37.0 36.5 28.5 21.0

86.434 87.030 37.0 36.5 26.5 20.0

Pipeline Maximum Allowable Free Span Summary for BRZ-PL3 Export Pipeline KP Piggyback

Pipeline Recommended Minimum Allowable Free Span (m)

From To Installation Flooded Hydrotest Operating

.000 0.500 BRZ-MP23 (3.5)

56.0 54.0 51.0 46.5

0.500 9.394 50.0 48.0 43.5 41.5

9.394 12.455

N.A

46.0 45.0 41.0 39.0

12.455 23.499 46.0 45.0 41.0 37.0

23.499 32.384 47.0 46.0 42.0 38.5

32.384 45.852 41.0 40.5 35.5 32.5

45.852 65.814 41.0 40.5 34.5 32.0

65.814 72.694 37.5 37.0 32.0 30.0

72.694 79.011 37.5 37.0 28.5 21.5

79.011 79.598 37.5 37.0 27.0 21.0

4) Crossing Information For the detail crossing information & procedure, refer to BRZ-GX-O-PL-0523 Pipeline Support Installation

Procedure

DOCUMENT TITLE


DOCUMENT Number


18 of 48 REVISION

1 BRZ GX


2.4 ENVIRONMENTAL DATA

For the detail refer to BRZ-GX-O-PL-0001 Subsea Pipeline, Riser and Cable Design Basis.

2.5 WEATHER LIMITATION

1) Anchor Handling Limitation

For the detail, refer to Doc. No. BRZ-GX-O-PL-0516 Anchor handling procedure.

2) Laying Working Limitation

For the detail, refer to Doc. No. BRZ-GX-O-PL-0501 mooring analysis report for pipeline installation

(HD-423)

2.6 ALIGNMENT

The pipeline final on-bottom position shall be located within 10m (33ft) of the approved route centreline and within 1m at Pipeline/Cable crossing location and within 1m at buckle trigger locations.

Anchor Handling Tug

Wave (Hs) Surface Wind

m knots

1.5 25.0

DOCUMENT TITLE


DOCUMENT Number


19 of 48 REVISION

1 BRZ GX


3.0 OFFSHORE MANAGEMENT

3.1 PMT ORGANOGRAM

The Project Organization will be submitted by Project PMT separately.

3.2 HD-423 ORGANIZATION

The HD-423 Organization will be submitted by Project PMT separately

3.3 INSTALLATION SCHEDULE

The Detail Installation Schedule will be submitted by Project PMT separately

DOCUMENT TITLE


DOCUMENT Number


20 of 48 REVISION

1 BRZ GX


3.4 RESPONSIBILITIES

The responsibility of key operational personnel in anchor handling operations is as below.

1) Superintendent

Superintendent shall be responsible for all offshore activities including spread) movement while interfacing any clash in the schedule.

Overall HSE&S, quality, and installation progress for the project relevant to production and construction.

Ensuring that all construction activities comply with the project specific requirements and/or international codes and standards under his supervision.

Liaising with the project management team for project execution and planning and with company representatives with respect to all offshore activities.

Delegating and assigning work to barge staff. Safe offshore operation of construction barge(s) Communicating and coordinate with the port authority and offshore field manager to ensure

Barge/ship/boats comply with international safety and maritime standards/requirements.

2) Assistant Superintendent

The SHE&S performance of those employees and subcontractors reporting to him. Ensure that all employees and subcontractors possess the necessary experience and training to

safely and successfully complete the work to be performed.

The management of the lay barge, the execution of the work in accordance with approved procedures, and the health and safety of all offshore based personnel.

To promote Statement of Safety and Accident Prevention policy and make clear to employees and subcontractors that they are responsible for their health and safety and that of their colleagues.

To ensure that operations are conducted with proper regard to protecting the environment. To assign SHE&S tasks and targets to barge supervisory employees. To insist on prompt accident and near-miss reporting and subcontractor employees and ensure

follow-up and dissemination of relevant information.

To investigate accidents and near misses. To conduct a review of sub-contractor SHE&S performance. To constantly review the barges SHE&S performance and provide feedback to barge supervisory

and subcontractor supervisory employees.

3) Barge Foreman

Planning, organization, and supervision of all construction activities on his shift to ensure that construction complies with SHE&S and project specific requirements.

Supported and assisted by all departments in order to expedite construction activities.

DOCUMENT TITLE


DOCUMENT Number


21 of 48 REVISION

1 BRZ GX


Coordinate with barge below and above deck crews for scheduling assistance and support between all parties.

Participation in TBTs, JSAs and other safety programs.

4) SHE&S Supervisor

SHE&S Supervisor shall be responsible for ensuring and monitoring Safety input for the planning,

organization, and supervision of all barge activities. Besides activities conducted on barge, SHE&S

Supervisor shall ensure all support vessels and other work sites comply with Safety, Health,

Environmental and Security requirements. SHE&S shall liaise with all personal on board, PMT, and

OWNER Representatives in order to meet the SHE&S requirements.

5) Field Engineer

Field Engineer shall be responsible for project planning, engineering, coordinating and ensuring all

construction activities are in compliance with project specific contract and technical requirement. Field

engineer shall supervise and liaise with all departments on the barge in order to maintain construction

activities in line with project requirements. Field engineer shall be responsible for monitoring the work

and providing engineering support for all deviations and modifications occurring during project execution.

Any change to approved procedures or drawings will be per the approved MOC procedure.

6) Chief Engineer

Chief engineer shall be responsible for the maintenance of all barge and support equipment for

construction activities. Chief engineer shall plan and organize all below deck and above desk equipment

maintenance activities for supporting construction activities. Chief Engineer shall ensure that all

equipment is ready and able to perform the various activities required for construction work.

7) Deck Engineer

Deck Engineer shall be responsible for organizing, planning and maintaining all major construction

equipment i.e. tensioners, A&R winch, anchor winches, welding and pipe handling equipment, etc. Deck

engineer shall ensure that construction equipment is in a proper condition for construction activities.

Deck Engineer shall coordinate with the construction crew above deck to ensure that all equipment is

suitable for construction requirements.

8) Anchor Foreman

Anchor foreman shall be responsible for planning, maintaining and preparing all materials, tools, and

equipment relevant to the barge mooring system. Anchor foreman shall liaise with AHT captain, deck

foreman, field engineer, deck engineer, survey party chief and support anchor handling tugs for all barge

mooring activities. The anchor foreman reports to the superintendent for construction activities with

regard to maritime safety and operations. Before anchor line crosses over any existing subsea

structure(s)/ pipelines, Anchor foreman shall inform to AHT captain to next anchor handling operation.

DOCUMENT TITLE


DOCUMENT Number


22 of 48 REVISION

1 BRZ GX


When anchor line crosses over any existing subsea structure(s)/ pipelines, Anchor foreman shall strictly

pay keen attention during course installation to keep the minimum 10ton anchor tension. If tension is

below 10ton, Notify to client.

9) Survey Party Chief

Survey party chief shall be responsible for;

Day-to-day running of the survey activities as well as being the coordinating point for all ROV activities.

Before anchor line crosses over any existing subsea structure(s)/ pipelines, Surveyor and Anchor

Foreman shall inform the AHT Captain prior to the anchor handling operation.

Surveyor shall strictly pay keen to the location of the AHT, tracking its position as the AHT approaches

the target anchor location and ensuring the final position of the anchor is as planned.

10) QA/QC Supervisor

QA/QC Supervisor oversees the planning, organization, supervision of multi-disciplined QC and NDT

personnel during offshore installation. QA/QC Supervisor shall liaise with the Project Management Team

and conduct daily audits of QC and NDT related activities. QA/QC Supervisor shall liaise with Barge

Superintendent, inspection team, Project Management Team and OWNER/Consultant personnel to

deliver the required quality to the contract.

11) Anchor Operator

Two (2) operators for each 12-hour shift. One operator monitors the bow anchors and one operator monitors the stern anchors.

Anchor operator shall be responsible for keeping anchor tension and monitoring anchor dragging and control vessel movement.

Before anchor operation, Anchor Operators inform/reports to Anchor Foreman and tug Captain with regard to maritime safety and operations and next anchor location.

When anchor line crosses over any existing subsea structure(s)/ pipelines, Anchor Operator shall strictly pay keen attention during course installation to keep the minimum 10ton anchor tension.

Responsible for monitoring and recording the anchor tension. The anchor tension is continuously monitored by checking the anchor tension readouts at the Anchor Operator station in the barge

control room. Anchor tension is recorded at 10min intervals. In case, the tension falls below the

minimum required tension, immediate action will be taken to restore the required tension. The

tension and the time of the event will be logged specifically.

DOCUMENT TITLE


DOCUMENT Number


23 of 48 REVISION

1 BRZ GX


3.5 MARINE SPREAD

3.5.1 HD-423 LAYBARGE DETAILS

Name of Vessel HD-423

Dimension of Vessel 121.9 m x 38.4m x 16.6m

Operation Draft 8.5 m

Positioning Equipment

Winches 10 x Manitowoc-700

Line Pull 68 Tons

Wire Size x Length 65 mm x1830 m

Anchors 10 x 15 Tons

Type

Delta Flipper(15 Ton) - Normal

Gravity(75 Ton) Shore Pull Area( until 3 km)

Stevshark( 9 ton) Sand Area

Auxiliary Equipment

Main Generator/Engine 5 x 600 kW Emergency Generator/Engine 1 x 250 kW

Compressor Main 3. x 300 CFM Emergency 1 x 500 CFM Water Maker 120 /Day

Pipelay Equipment

Tensioner 3 x 150 Kips

A/R Winch 1 x 400 Kips

Work Stations

2 x Bevelling Station 1 x Lineup Station 6 x Welding Stations (Main x5, Piggyback x1) 2 x NDT Station (Main x1, Piggyback x1) 2 x Field Joint Station (Main x1, Piggyback x1) 1 x Piggyback Clamping Station

Davit Crane 4 x 50 Tons, 1 x 20Tons

3.5.2 AHT SPREADS

Name of Vessel SUSANNA (AHT-1) SHARIEF (AHT-2)

Length of Overall 49.5m 48m

Breath Moulded 13.6m 13.2m

Depth Moulded 6.4m 5.2m

Max.Draft 5.59m 4.2m

Bollard Pull 110 ton 65.6 ton

Main Engine 8000 BHP 2575BHPx2

DOCUMENT TITLE


DOCUMENT Number


24 of 48 REVISION

1 BRZ GX


3.5.3 TRANSPORTATION SPREADS

Item Purpose Name of Vessel

1 Transportation Spreads Barge(MICLYN 283, 285,286 & 287)

Tug : Miclyn Jade, Pearl, PB Peal, AOS star

2 Material Barge AOS 104

3 Supply Boat Miclyn Power

C OF 32"

HHI STD FOR

4.0 GEN

4.1 BAR

No.8

No.9pig

EXPORT PIPELINE

DOCUM

INST

RMAT: BRZ-G

NERAL PIP

RGE LAYOU

8 Station (Field

9 Station (Bundggyback)

MENT TITLE

PL1 & PL3TALLATIO

GX-P-O-PL-050

PE LAYING

UT

Coating)

dle work for

3 PIPELINN PROCE

03 PL1 & PL3 P

G PROCE

N

NE DURE

D

PIPELINE INS

EDURE

No.1 Station (Fi

No.5 Station (

DOCUMENT Nu

BPROJ FA

BRZ GX

TALLATION P

it-up & Root)

(NDT)

mber

BRZ-GX-AC. P

25X

PROCEDURE

P(cle

O-PL-05PAGE

5 of 48

Line-up S

Pipe Ready Rack eaning & bevelin

503 REVISION

1

Station

g)

N

DOCUMENT TITLE


DOCUMENT Number


26 of 48 REVISION

1 BRZ GX


4.2 MATERIAL TRANSFER & PREPARATION WORK

4.2.1 RECEIVING AND INSPECTION

Upon arrival of the pipe haul barge in the field, the HD-423 will bring the barge alongside to begin

offloading the pipe. The 32" pipes will be handled with wire slings wrapped by soft-rope to protect the

pipe coatings (Refer to BRZ-Q5B0-PL-1240 in Installation drawings), while the piggy-back joints will be

transported in bundles. The pipe joints to be used will be transported from the material barge to the HD-

423 and stored on deck until ready for use.

NOTE: The first layer of the pipe joints will be placed on wooden padding. And all base layered pipes

will be secured with stanchions on each side. Once removal of a single joint on the bottom stack is

made, adequate chocks will be placed to secure the stack.

All coated pipe and project materials will be received inspected and documented upon arrival on the HD-

423. The tally and inspection will be carried out as per the Quality Assurance (QA) and Quality Control

(QC) documents. The individual pipe information, heat number, length, etc., will be recorded on the tally

sheets and stored for final project documentation. A daily report which will contain a log of the day's

activities and recap of the tall will be generated.

NOTE: During the inspection process, damage to the pipe coatings will be noted. Any minor damage to

coating(s) will be repaired as the pipe is assembled. If the damage is assessed as major, the pipe joint

may be removed from the ready-rack and repaired at a later time.

NOTE: Pipe joints shall be not transferred when the lay barge is located on any subsea PL/Cable or

structure.

Concrete Coating Damage Repair 1) Spalling

Spalling damage shall be repaired if the damaged area exceeds 0.09 m2 (1 ft2), or if the depth of

damage exposes the reinforcing steel. Repairs to spalling damage shall be performed by the following

procedures, If the damaged area is 0.28 m2 (3 ft2) or less, remove the damaged concrete.

If the damaged area exceeds 0.28 m2 (3 ft2), remove the concrete from around the entire pipe

circumference throughout the length of damaged area. Restore the reinforcement steel, if necessary.

Wet the fresh surface of the remaining concrete coating at the point of coating damage for a minimum of

two hours.

Place the concrete repair mixture into and through the reinforcing steel until the surface is level with the

coating around the repair. Cure the repair.

2) Cracking

Cracks requiring repair are as follows:

Circumferential cracks that extend more than 180 degrees around the pipe circumference and are

greater than 1.6 mm (1/16 in.) wide

Longitudinal cracks that extend more than 305 mm (12 in.) along the pipe, irrespective of width.

DOCUMENT TITLE


DOCUMENT Number


27 of 48 REVISION

1 BRZ GX


Repairs to cracks shall be made by the following procedures:

Chisel the crack out to a width of not less than 25.4 mm (1 in.) throughout the length of the crack,

without damaging the reinforcement steel Wet the crack surface for a minimum of two hours

Fill the crack with concrete repair mixture. Cure the repair

For FBE repair work, refer to V-PIPEP506-756, Quality procedure for Fusion Bond Epoxy coating.

3) MPI for MEG pipe

After loading MEG line pipe on HD-423 deck, all of MEG pipeline ends shall be conducted MPI as per

company specification before transfer to ready rack

4.2.2 LINEPIPE PREPARATION

1) Introduction of Linepipe

Each joint of pipe will be lifted from a stockpile location and placed upon a transverse rack at mid-ship.

It is here where the inside of the joint will be blown clean with a brush pig (or equivalent), with the

assistance of a tugger. Once complete the transverse conveyors will carry the pipe over to the first

longitudinal roller, this is where the bevelling process will begin."

Bevel Work sequence ;

- Both sides of pipeline bevelling machines

- Load the pipe on the ready rack

- Insert the bevelling tool into the pipe

- Bevel tool operator sets the machine to bevel the pipe.

- The Tool is rotated and the pipe is bevelled.

- Operator checks the bevel condition.

DOCUMENT TITLE


DOCUMENT Number


28 of 48 REVISION

1 BRZ GX


Pipe-Inside Clean Work

- Through the pipe inside, 1/2 wire is passed to the opposite side of the pipe. - Worker connects a wire to the cleaning tool and inserts the tool into the pipe. - Pull the tool by the winch located in the opposite side of the pipe.

2) Linepipe bevelling

The bevels of the pipe joints will be protected with bevel protectors, however, this does not always

prevent damage to the pipe's bevel. Further, to support the welding process, a compound bevel will

need to be made on the pipe-end, thus the process will begin at this first longitudinal track location. As

the pipe is progressed forward (to the bow) on the longitudinal roller system, the pipe is further readied

to assembly."

3) Ready-Rack

At the bow of the HD-423 is the area known as the "ready-rack". It is here where the pipe joints are

received from the longitudinal roller system, and any further completions of beveling will be performed.

This rack will stage approximately six (6) pipe joints ready to be introduced into the firing line for the start

of the welding process.

Also in the ready-rack area, the pipeline tally sheets will be completed, which will include the pipe joint

number, length, pipe material specifications, location of anode joints, etc. The tally man shall particular

attention to the sequence of the anode pipe joints to be loaded onto the conveyor system in order to

maintain the correct anode spacing along the pipeline.

4) Bead-Stall Operations

Once all pre-work is complete on each pipe joint, the joints are stored on the ready-rack. Upon the

completion of activities along the firing-line, the beadstall will be in need of another joint for introduction

into the process. The pipe is transferred from the ready-rack onto stalking shoes. The stalking shoe

operator will manipulate the pipe on the shoes/rollers so as to roughly align the pipe (diameter and seam

orientation) with the section of pipeline in the ramp's firing line.

After the rough alignment, the reach rod for the internal line-up clamp will be pulled from the joint

previously welded in the pipeline, and into the joint just roughly aligned. The clamps will be activated on

the pipeline side, and the stalking shoe operator will slowly end the pipe up to the pipeline. The spacers,

in conjunction with the stalking shoe operator will perform the required fine adjustments for final

alignment (high/low, root spacing, etc.). The clamp will be set, and readied for the welding process.

During these activities, the sequential pipe joint number will be painted on the end of the pipe joint

DOCUMENT TITLE


DOCUMENT Number


29 of 48 REVISION

1 BRZ GX


nearest the bow. Successive joints of the pipeline will be consecutively numbered using quick-cured

marine paint. The numbers will be at least 200-mm in height. Numbers shall be painted at the 9'-o'clock

and 3-o'clock positions."

4.3 WELDING & FILED JOINT COATING

4.3.1 WELDING

For the piggyback line welding station, the piggyback welding station shall be prepared as the drawing in

section 7.2.1.

1) Field Welding

After alignment of the pipe, the root bead and hot pass will be welded in the bead stall. Further, stalls 2,

3 and 4 will subsequently complete the welding process with fill and capping. In the tower, the welding

performance (and other stations) of the main line and piggy-back line shall be monitored for progress.

Once each process is complete in each station, a ready-light button will be pressed to indicate station

readiness to proceed."

2) NDT Station

After the weld is completed on a joint, all production welds shall be visually inspected and Ultrasonically

Tested (UT) for the main line, and Radio graphically Test for the piggy-back line. The COMPANY

representative and CONTRACTOR will monitor as the SUBCONTRACTOR will interpret the result of the

UT and RT. If the test is not satisfied with the QA requirements, the weld shall be repaired and NDT

shall be performed. The field weld joint will be inspected in accordance with the NDT procedure

approved by COMPANY.

4.3.2 TENSIONER

1) Operation Tension

As a part of normal pipelay operations, the barge tension will be continuously recorded and periodically,

the barge maintenance personnel will inspect the tensioners for hydraulic leaks, unusual sounds etc.

The field engineer will compare the proper tension, the pipe departure angle and depth against

information in BRZ-GX-O-PL-0507, PL1&PL3 Pipeline Field Data Book.

The tensions of tensioner & buckle detector are recorded on the recording system in the control tower.

The loads on the stinger rollers are monitored by load-cells and the stinger depth is monitored by

pneumo in the stinger cabin. The stinger operator will reside in the stinger cabin to monitor the loads on

the rollers and pneumo of stinger tip. And he will log the stinger pneumo and loads on the rollers every

10 minutes.

2) Buckle Detector

The buckle detector is used for pipelines to detect the occurrence of a buckle in the pipeline as the pipe

is being laid. It is pulled through the pipe when the barge pulls forwards and is located after the touch

down point.

DOCUMENT TITLE


DOCUMENT Number


30 of 48 REVISION

1 BRZ GX


The buckle detector shall have a pull force load cell with a constant display and continuous recording of

the load. Distance behind the laybarge shall be sufficient to ensure that the pipe is resting safely on the

bottom without buckle or other deformities

Normally a buckle detector is located a minimum 50m beyond the touch down point. Adequate wire will

be provided to ensure that the buckle detector rides approximately 5 joints behind the touch down point

of the pipe string. The field engineers will determine the length of the buckle detector wire by calculating

the distance of the pipeline touchdown point in addition to the 5 pipe joints. Buckle detector will be

inserted in presence of company representative and will be signed by him on the gauging plate. If the

buckle detector is pulled out at any stage during pipelaying for any reason, company representative(s)

on board to be informed prior to removal.

The Buckle detector tension gauge indicates more than 1 MT, pipelaying operation will be stopped and

then it will be informed to barge superintendent and Company rep to decide the recovery.

Diameter of Buckle Detector

The following formula may be used

d = D -2t s Where: s = 0.01D+0.4t+5L with all units in mm

d = diameter of detector

D = nominal outer diameter of pipe

t = nominal wall thickness of pipe

L = 20% of t, or 5mm. whichever is smaller For the detail disk size, refer to section 7.2.1.

Pipe Applied Section D (mm)

WT (mm)

20% L (mm) S (mm) d

(mm) THK (mm) CRA

CLAD (mm)

725.048

LTE to 500m 819.2 25.4 0 5.08 5 43.352 725.048

500m to KP 0.5 812.8 22.2 0 4.44 4.44 39.208 729.192

KP 0.5 to KP0.0 825.6 28.6 0 5.72 5 44.696 723.704

DOCUMENT TITLE


DOCUMENT Number


31 of 48 REVISION

1 BRZ GX


4.3.3 FIELD JOINT WORK

1) Field Joint Coating Stations

After each joint has been approved at the NDT station, the pipe will be pulled into the field joint coating

stations where various applications will be applied.

Prior to foam (HDPF) infilling, the surface has been carried out in accordance with Process Control

Procedure S/001/F/FBE. PS and has been accepted by the COMPANYs coating inspector.

The field joint shall be coated within four hours of blast cleaning or before the appearance of rust bloom,

whichever is the shorter. If there is evidence of rust bloom or if more than four hours has elapsed or the

blast is not in accordance with Sa 2 , the field joint shall be re-blasted in accordance with process

control procedure S/001/F/FBE PS. Whenever there is a stoppage on the production line, the blasted

field

Pipe will be blast-cleaned with grit or combination of grit and shot. The surface will then be heated to

correspond with the application temperature of the FBE powder, which will be circumference applied. Similar applications will be made for the piggy-back line as well.

For detail, refer to the BRZ-GX-O-PL-0636 Procedure for field joint coating and infilling work

Once the FBE coating is accepted free of defects, the HDPF will be applied to complete the field joint.

A pre-cut steel sheets with a 1-1/2 hole will be then wrapped around the field joint using intra-fuse.

Polymeric foam mixture from the injection pump is then injected into the hole to fill up the field joint. The

hole is then plugged temporarily for the foam material to set. The process described above is then

repeated for successive joints. The field joint coating detail for concrete coated pipe is as below.

For the Piggyback line and the non-concrete coated pipe, HDPF will not be applied.

CONCRETE COATED TO CONCRETE COATED PIPE

DOCUMENT TITLE


DOCUMENT Number


32 of 48 REVISION

1 BRZ GX


From BRZ-GX-D-PL-0545 Field joint details drawing

4.3.4 BARGE MOVEMENT

Upon completion of the activities in each station including piggyback line, the ready light will be activated.

This activity will give the Tower Foreman a green light indicator in the tower. All stations showing

green light(s) will signify that the cycle for one complete joint has been completed, and that the barge is

ready to be pulled forward. After the last ready light is activated, the anchor operator in the tower will

signal the barge movement by giving a blast of the air horn and/or announcing on the intercom that the

barge is pulling the pipe. An audible blast will also be used once pulling has been completed.

4.4 BUNDLE WORK FOR PIGGY BACK LINES

4.4.1 Clamping Station

When the piggy-back line arrive at the clamping station (Station #9), a rubber spacer block will be added

atop the concrete coating as per BRZ-GX-D-PL-0550-001 & 002, 3.5 & 4.5 Mono Ethylene Glycol

Single Piggy Back Arrangement Detail. The spacer block has a side-cut to insert the piggy-back line.

According to the concrete coating thickness, a specific rubber spacer type and spacing will be used as

per the table in section 2.3.

4.4.2 Clamping Work Sequence

Refer to BRZ-GX-V-PIPE-P510-001, Product drawings (Piggy back saddle and straps), and BRZ-GX-V-

PIPE-P510-801, Installation Manual (Piggy back saddle and straps) in Appendix B.

4.5 CATHODIC PROTECTION CABLE FOR PIGGYBACK LINES

Configuration

3.5" & 4.5" PIGGYBACK LINE FIELD JOINT

DOCUMENT TITLE


DOCUMENT Number


33 of 48 REVISION

1 BRZ GX


The one side of connection cable will be pre-attached to the main pipeline anode in the coating yard,

and the other end will be attached to the piggy back line on the barge. The cable will be thermit welded.

Refer to BRZ-GX-V-PIPE-P506-758, Quality procedure for Anode Installation and BRZ-GX-V-PIPE-

P506-851, WPS & WPQR Anode.

Coating

On completion of thermit welding, all weld connections and bare metal areas shall be cleaned and

applied with two component epoxy patching compound recommended by the FBE manufacturer. The

thickness shall be 400 microns.

DETAIL 1SCALE: NTS

DOCUMENT TITLE


DOCUMENT Number


34 of 48 REVISION

1 BRZ GX


5.0 PL1 & PL3 PIPELAYING PROCEDURE

5.1 INITIATION

The shore pull method will be performed to initiate pipelaying. The shore approach procedure for PL1 &

PL3 is described in BRZ-GX-O-PL-0522. In short, HD-423 stern will be located at KP 87.030 for PL1

and KP 79.598 for PL3, approximately 1,700m from the LTE, and start welding the pipe. The welded

pipeline will be pulled by two linear winches located in onshore. When the pulling head of 32 pipeline

arrives at LTE, the pulling head will be hold by onshore padeye. After confirmation of securing the

pulling head, the normal laying will be started along the designed route. (Please refer BRZ-GX-O-PL-

0522 Shore Approach Procedure )

5.2 PIPELAYING

HD-423 will initiate PL3 shore pulling and proceed about 3km laying and down it on the seabed. And

HD-423 will return to the initiation point of PL1. After PL1 initiation, HD-423 will lay the all PL1 line

section. PL-3 will be laid after PL1.

5.2.1 Laying Sequence (Only for Information)

Seq. Operation KP WD (m) Description

1 PL3 Laying start 79.597 8 Shore Pull Operation, Laying Start with 4.5 MEG PB Line 2 PL3 Laydown 76.597 13 Temporary laydown for PL1 shore pull operation

Return to Shore pull location 3 PL1 Laying start 88.734 8 Shore Pull Operation

4 PL1 BRZ-TEE 12 16.671 48.0 Lay down: 4.5 MEG PB Line, Start: 3.5 MEG PB Line 5 PL1 Dummy Spool (BRZ-WYE1)

12.773/ 12.826 46 2 Flange joint

6 PL1 Laying Finish 0 52 Lay down Return to PL3 laydown location

7 PL3 Recovery 76.597 13 Recovery PL3 and Laying 8 BRZ-TEE 32 9.394 47.0 Start : 3.5 MEG PB Line

9 Dummy Spool (BRZ-WYE3) 5.174/ 5.124 42 2 Flange joint

10 PL3 Laying Finish 0 44 Lay down

DOCUMENT TITLE


DOCUMENT Number


35 of 48 REVISION

1 BRZ GX


5.2.2 The approved route centreline

During normal pipeline laying operations the actual pipeline position shall be within 10m of the approved route centreline.

BRZ-PL1

Refer to Pipeline Alignment Drawing for 32 BRZ-PL1 Pipeline from WHP-1 to LTE

BRZ-W1XP-D-PL-0501 ( Total 36 sheets)

BRZ-PL3

Refer to Pipeline Alignment Drawing for 32 BRZ-PL1 Pipeline from WHP-3 to LTE

BRZ-W3XP-D-PL-0501 ( Total 33 sheets)

5.2.3 Tension Scheme Table

The Tensioner- tension shall be controlled the below table as per the WD and CC thk.

Refer to the BRZ-GX-O-PL-0507 PL1 & PL3 Pipeline Field Data Book.

5.2.4 Pipelaying at Pipeline/Cable Crossing location

The crossing supports shall be installed before laying start as per BRZ-GX-O-PL-0523, Pipeline support

installation procedure. When HD-423 approaches to the pre-installed support location, ROV will be

deployed from ROV vessel to check the support location and condition. After confirming the locations,

HD-423 will keep the heading of the barge and ROV will keep monitoring the pipeline until the Pipeline

touches on the supports.

5.2.5 Pipeline Laydown and Termination

As HD-423 approaches to the pipe laydown/termination area, the surveyors and onboard personnel will

begin to monitor and calculate the remained length of pipe, considering the gain length of Pipeline.

Laydown/Termination Sequence

1. Termination case: confirm the remaining length of pipeline for the termination point by surveyor.

2. Remove buckle detector and other equipment from pipeline

3. Weld Termination Head on pipeline

4. Connect intermediate Termination Wire to Termination Head

5. Connect A&R cable to intermediate Termination Wire and transfer load to A&R"

Once all the tension in the A&R winch wire is 0, diver will disconnect the A&R wire from the intermediate

wire, and then connect marker buoy. Diver(or ROV) will checks to confirm position of termination head

by using USBL beacon.

DOCUMENT TITLE


DOCUMENT Number


36 of 48 REVISION

1 BRZ GX


5.3 PIGGYBACK PIPELINE INSTALLATION PROCEDURE

5.3.1 Deck Preparation Works

Prior to commencement of pipe laying, deck area of pipe laying barge should be prepared for the safe

and appropriate installation of 4 MEG pipelines.

1) The required preparation work at the deck area is as follows

2) Arrange pipe storage racks and pipe preparation work area

3) Install pipeline guide rollers and supports

4) Install welding / NDT station

5) This station will be installed near the X-ray cabin.

6) Install field joint coating and repair station

7) Install clamping station and electrical connection station

5.3.2 Piggyback Pipeline Initiation

1) The end of the piggyback pipe will be welded to the pulling head.

2) The pulling head will be connected to the 1/2 wire. And 1/2 wire will be connected to the

padeye on the mainline pulling head to be secured.

From BAZ-Q5B0-PL-1331, 32 details of pulling head

3) Piggyback pipeline will be bundled with main pipeline by using spacer block.

4) Piggyback pipelines will be installed with main pipelines during normal laying. The spacer

block will be installed as per the designed spacing and near of the piggyback pulling head.

5) Anodes for piggyback pipeline will be Thermit welded to the piggyback pipeline.

5.3.3 Installation Procedure

Duplicated parts with main pipeline installation procedure are not described in this procedure. Following

step by step description concerns the general procedure for installation of 4 MEG pipeline.

HG-228 (19.1mm) SPACER BLOCK

DOCUMENT TITLE


DOCUMENT Number


37 of 48 REVISION

1 BRZ GX


Transportation & Handling of 3.5 & 4.5 MEG pipes

On arrival of the pipe transportation barge in the field, a deck crane will begin offloading the pipe in the

order as required for normal laying. The pipe will be handled with wire slings wrapped around by rubber.

The pipe will be stored in the laybarge storage racks until needed. After storage of pipes, all pipes will

be

1) Material inspection and Documentation including MPI

2) Bevels and cleaning pipes

3) Pipeline alignment and fit-up

4) Pipes are transferred to simple supports guide rollers to fit-up the pipes.

5) Field Welding

6) Welding of pipe joints shall be in accordance with client specification and company approved WPS.

In addition, pipe joint numbers will be painted onto the outside surface.

7) Field joints shall be tested in accordance with company approved NDT procedure.

8) Field joints shall be coated in accordance with company approved field joint coating procedure.

9) Clamp pipe and electrical connection.

10) In this stage, 3.5 & 4.5 lines will be clamped to 32 main line according to the company approved

clamping system.

5.3.4 Piggyback Pipeline Termination

1) When the pipeline termination area is approached, the piggyback pipeline termination operation is

also prepared.

2) Once the main pipeline pulling head is attached to the end of pipeline and A&R winch wire is

connected to the pulling head, the termination operation will be commenced.

3) The piggyback pipeline termination head will be connected to the main pipeline termination head by

using 1/2 wire and turn buckle. And the spacer block will be installed as per the designed spacing

and near of the piggyback pulling head.

4) Piggyback pipeline termination operation will be done with main pipeline termination operation.

DOCUMENT TITLE


DOCUMENT Number


38 of 48 REVISION

1 BRZ GX


5.4 LAYING WITH BAR- TEE OR FLANGE JOINT

Bar-tee to connect to 24 lines and the flange joints of the Dummy spools shall be laid with the pipeline.

HD-423 has 3 tensioners (3 x 150 Kips).

For the layout details, refer to drawing No. BRZ-GX-D-PL-0551, 0555&0557 and BRZ-W21IP-D-PL-

0510 andBRZ-W23IP-D-PL-0510 .

2) Pipeline Reference Point

Location Easting (m) Northing (m) KP WD, LAT (m) TEE TIE-IN(BRZ-PL12) 589,379.18 2,925,453.18 16.671 48.0

SPOOL TIE-IN(BRZ-PL12) 589,382.28 2,925,454.03 16.677 48.0 TEE TIE-IN(BRZ-PL32 589,222.60 2,924,755.05 9.394 47.0

SPOOL TIE-IN(BRZ-PL32 589,225.13 2,924,753.07 9.390 47.0 BRZ-WYE1 (Dummy) Refer to Drawing BRZ-GX-O-PL-0555 Rev.1

BRZ-WYE3 (Dummy Spool) Refer to Drawing BRZ-GX-O-PL-0557 Rev.1

LTE at BRZ-PL1 551,567.74 2,869,713.13 88.734 +2.0 LTE at BRZ-PL3 551,571.27 2,869,711.25 81.309 +2.0

Bar-tee/ flange will be welded in the welding stations and the tensioner will be opened when the bar-tee

or flange joint arrive at the tensioner. During passing the tensioner, the others (2 tensioners) will

maintain the below required tension. And the flanges to be connected to 24 intrafield pipeline will be

blinded by a temporary blind flange. The detail operation scheme refer to the drawing No. BRZ-Q5B0-

PL-1542 &3 and the operation tensions in PL1&PL3 Pipeline Field Data Book (BRZ-GX-O-PL-0507) are

simplified for the easy operation.

The piggyback line to be connected with interfiled line will be terminated as BAZ-Q5B0-PL-1331 in

section 7.2.2.

DOCUMENT TITLE


DOCUMENT Number


39 of 48 REVISION

1 BRZ GX


6.0 CONTINGENCY PROCEDURE

This section details the various contingency and emergency response procedures.

6.1 ABANDONMENT

Temporary abandonment of pipelay operations may occur for a number of reasons; however equipment

failure and weather are the two most likely reasons to force a temporary abandonment. HD-423

Superintendent will assess the situation and determine if abandonment is needed. If conditions or the

situation allow, slow lay of the pipe will continue as long as viewed prudent by the HD-423

superintendent to do so. Company representative will be notified of any changes in the pipeline

production or pipeline.

When weather conditions are such that the barge or support vessels must cease operation, the pipeline

will be temporarily capped and placed on the seabed. This also applies when the weather forecast

indicates extreme weather conditions which would require the lay spread to depart location or otherwise

abandon normal operations.

In this case, the barge will lay out from under the pipeline by attaching an abandonment head to the

pipeline. All internal equipment including the buckle detector will be removed from the pipeline and the

head will be welded to the pipeline in the bead stall. The termination head will then be shackled to the

A&R winch wire.

Excess slack will be taken out of the A&R winch wire. The barge will then begin moving forward as the

tension is gradually transferred from the tensioner to the A&R winch wire. Lay tension will be maintained

throughout the procedure. The pipe-support of stinger will remain at the required depth until the

abandonment head has passed.

The length of wire paid out will be monitored and checked against the engineering calculations. The

barge will continue to move forward until the recommended length of wire has been paid out. The barge

will then remain stationary while excess wire is spooled off of the A&R winch. The survey team will

record the coordinates of the end of the pipeline for future recovery.

If the barge is to remain on location, the wire will remain connected to the abandonment head and to the

barge. The excess slack will be required to ensure that the movement of the barge due to sea state is

not transferred to the pipeline on bottom via the wire.

If the barge will be required to abandon the location, the A/R winch wire will be paid off from the drum. A

marker buoy will be attached to the end of the A/R winch wire for retrieval by the barge at a later time.

As an alternate, the pipeline may be laid on seabed and left without a buoy for recovery by the barge

using divers or ROV at a later date.

Step By Step Procedure for Abandonment

If, for weather forecast reasons, the decision to abandon the pipe is taken by the superintendent of the barge, steps are as follows; 1) Check and if necessary re-position anchor pattern for barge moving without anchor handling during

DOCUMENT TITLE


DOCUMENT Number


40 of 48 REVISION

1 BRZ GX


abandonment steps.

2) Finish all welds.

3) Recover line-up internal clamp and Buckle detector.

4) Weld the abandonment head, and NDT will be carried out. And the piggyback pipeline will be cut off

and supported to keep the gap for pulling head welding operation.(If required, the piggyback spacer

block behind the pulling head location will be installed after welding of pulling head to keep the

space for welding of piggyback pipe pulling head.)

5) Connect the A/R winch wire and spool the slack.

6) Transfer the tension from tensioner to A/R winch.

7) Once tension is transferred, fully open the tracks of tensioner to pass abandonment head.

8) Move the barge ahead until the abandonment head is reached to the last station of the barge.

9) The piggyback pipeline will be cut off and supported to keep the gap for pulling head welding

operation.(If required, the piggyback spacer block behind the pulling head location will be installed

after welding of pulling head to keep the space for welding of piggyback pipe pulling head)

10) It is recommended to keep the stinger in a median position while the abandonment head moves

from the laying ramp to the last roller of the stinger.

11) When the abandonment head leaves the barge, a pendant rope with a marked buoy is attached to

the abandonment head, and a mark is painted on the A/R winch wire at a distance equal to stinger

length.

12) As soon as the abandonment head leaves the stern of barge, start to adjust the stinger in a proper

position according to the results of stress analysis.

13) As soon as the abandonment head has left the stinger, stop the stinger operation and move the

barge ahead a predetermined distance as per the calculation for abandonment.

14) Pay out A/R winch wire by decreasing the tension of A&R winch until the pipe touches down on the

seabed. Then the wire is slacked and kept on board or released. If released, the wire is lifted with a

pendant buoy.

15) In all cases, the plotting of the barge route will be precisely made, in particular when the head

comes at the stern of barge.

16) If abandonment is required, according to the decision of the Barge superintendent, the stinger will

be disconnected or not.

6.2 RECOVERY

When weather or other conditions are better, the barge will prepare to recover the pipeline from the

seabed. For this procedure, the barge will be positioned over the abandonment location in the correct

lay orientation. The marker buoy on the A/R winch wire will be recovered to the barge.

Step By Step Procedure for Recovery

1) The A/R winch wire will be passed through the stinger, up the pipe alley and connected to the A/R

DOCUMENT TITLE


DOCUMENT Number


41 of 48 REVISION

1 BRZ GX


winch. The barge will now be moved ahead the minimum distance.

2) The barge will remain stationary and begin spooling in the A/R winch wire. As the wire tension is set

up the required lay tension, the barge will begin slowly back under the end of the pipeline while

maintaining this required tension.

3) The barge will continue back under the pipeline until the end of the pipeline is past the tensioners.

4) At this point, the tension will be transferred from the A&R winch to the tensioners. Once all the

tension is transferred from A&R winch to tensioners. When all the tension in A&R winch is

transferred to Tensioner, A&R winch wire will be disconnected from A/R head and A/R head will be

cut from main pipeline. The next joint of pipe will be ready to be welded.

5) If there is any piggyback pipeline, the A/R head of piggyback pipeline will be disconnected from A/R

head of main pipeline. And then the A/R head will be removed from pipeline.

6) Normal operations will commence at this time.

Dry Buckle

The location of the buckle and the extent of damage will be determined. The buckle will be surveyed by

ROV or Diver and a conclusion will be made as to whether the buckled area can be recovered to the

barge.

If the buckle will pass through the pipe-support and onto the barge, the barge will begin back under the

pipeline in the reverse process of laying pipe.

As the pipe joints come into the bead stall, they will be cut from the pipeline and set aside for re-

bevelling. As the buckled pipeline arrives in the line-up station of lay ramp, it will be cut out. The barge

will then begin stalking on the pipe joints and normal lay will resume.

If the buckle could not be passed through the pipe-support or recovered to the barge, the abandonment

head will be welded on the end of the pipeline. The pipeline will be laid down to the seabed as per the

termination procedures.

The barge will lift the pipeline alongside the port side by using the davits or by using a single point

pickup if possible. The buckle will be cut out and the recovery head will be welded on the pipeline. And

then the pipeline will then be placed on seabed and recovered as per the recovery procedures. Once on

the barge, normal pipelay will resume.

Wet Buckle

The location of the buckle and the extent of damage will be determined. In case, the buckle or damage

has allowed water to enter the pipeline, the pipeline will be laid on the seabed as per the abandonment

procedures. The buckle will be surveyed by ROV until it is determined that pipeline is fully flooded. Only

then can divers begin to work near the pipeline.

Divers will cut the pipeline at the damaged area. Divers will then insert pig stopper bars in the cut end of

the pipeline. Pipeline shall be air pumped in the end of the pipeline (shore side or start pulling head

location) so as to dewatering pig inserted in initiation head can dewater from start point to the damaged

DOCUMENT TITLE


DOCUMENT Number


42 of 48 REVISION

1 BRZ GX


area.

The pipeline will then be recovered to the barge as per the recovery procedure while pressurizing until

the buckled joint comes up to the surface.

Failure of Tensioner System

The tensioner will be checked and monitored regularly. However, tensioners have their own shut down

system for emergency case. Therefore if there is any unexpected situation occurred, tension will can be

kept until the tensioner is fixed.

If the situation requires that the tension on the tensioner needs to be released from the pipe, the A/R

head will be attached and connected to the A/R winch wire.

The tension will be transferred to the A/R winch and then the tensioner release the tension and then to

be fixed.

Failure of Anchors and Anchor Lines

HD-423 has 10 anchoring system, and for pipelaying operation only 8 anchor systems will be used.

Therefore if there is any failure of anchor lines and mooring winch, other mooring winch will be used.

However, once if any failure of anchoring system is found, the pipelaying operation will be stopped.

The detail procedure for anchor winch trouble and anchor line failure will be described in the Anchor

Handling Procedure.

Breakdown of positioning system

Once the positioning system is broken down, the laying operation will be stopped and then be waited

until it is fixed.

Piggyback Pipeline and Cable Contingency Procedure

Piggyback Pipeline Contingency Procedure

In case temporary abandonment is required during pipelaying operation piggyback pipeline will be also

abandoned with following sequence.

While the A/R head is welded in the line-up station, the piggyback pipeline will be cut, and temporary

A/R head will be welded and bundled as the Tee joint case in BAZ-Q5B0-PL-1331 in section 7.2.2.

When the abandonment condition is completed, the recovery operation of piggyback pipeline will be

done with main pipeline.

And the main pipeline is arrived in the line-up station, the temporary securing will be released and A/R

head will be cut out, and then welded to the end of coiled pipe.

If there is any damage to the pipe coating, the coating repair will be done according to the coating repair

procedure, FBE and concrete coating procedure which will be submitted by vendor.

DOCUMENT TITLE


DOCUMENT Number


43 of 48 REVISION

1 BRZ GX


7.0 APPENDIX

7.1 APPENDIX.A: SPECIFICATION OF VESSELS

7.1.1 HD-423

7.1.2 AHT

LINEPIPES ON DECK

RegistryClassificationLengthWidthDepthLight WeightOperating DraftQuartersHelideck

Gross TonnageNet TonnageFuel StorageFresh Water Storage

SPECIFICATIONVanuatu

A.B.S. A1121.9 m38.4 m16.6 m

13,175 Tons8.5 m

254 Persons (Full A/C)25.3 m x 25.0 m Square

Suitable for SIKORSKY S61N10,636 Tons3,190 Tons

1,930 CBM (1,641 Tons)1,500 Tons

WinchesLine PullWire SizeLengthAnchorsType

POSITIONING EQUIPMENT10 x MANITOWOC-700

75 S.Ton65 mm Dia.

1,830 m10 x 15 TonsDelta Flipper

Generator/EngineMainEmergency

CompressorMain EmergencyWater Maker

AUXILIARY EQUIPMENT

5 x 600 kW1 x 250 kW

3 x 600 CFM1 x 500 CFM

120 m3/Day

Maker / ModelFixedRevolvingAuxiliaryWhip

MAIN CRANECLYDE/52-DE-230+30+15

750 S.Ton600 S.Ton150 S.Ton50 S.Ton

Maker / ModelCapacity

DECK CRANEMANITOWOC-4100W

200 S.Ton

Max. O.D.

PIPELAY CAPACITY66

RadarGyro CompassEcho Sounder

NAVIGATION EQUIPMENT1 x FURUNO Elec

1 x TOKIMEC1 x SHIPMATE

TensionersA/R WinchWork Stations

Auto WeldingDevit Crane

PIPELAY EQUIPMENT3 x 150 Kips1 x 400 Kips

2 x Beveling Stations1 x Lineup Station

5 x Welding Stations1 x NDT Station

1 x Field Joint Station12 x SATURNAX

4 x 50 Tons, 1 x 20 Tons

SSB RadioINMARSAT

VHF Radio

UHF Radio

COMMUNICATION EQUIPMENT1 x SEA 330 HF/SSB

1 x NERA1 x NERA MINI-M

1 x GME ELECTROPHONE1 x TRITON 55/75

1 x SAILOR RT 20481 x TRITON 2 MOTOROLA

1 x EXICOM 835

CONTROL TOWER

TENSIONER

WELDING

HYUNDAI-423

64/121

STBD PROFILE

MAIN DECK PLAN

HYUNDAI-423

HYUNDAI-423SEMI-SUBMERSIBLE DERRICK/PIPELAY BARGE

65/121

HE

IGH

T IN

ME

TE

RS

AB

OV

E D

EC

K

ROTATION

70.1

04m

RADIUS IN METERS FROM CENTER OF ROTATION

10.06m 1.57m

MAIN

6.55

m16

.76m

24 30 36

AUXILIARY

REVOLVING

WHIP

9042 48 54 60 7266 78

MAIN FIXED

LOA

D C

AP

AC

ITY

IN S

/TO

N

30018

0 0

6

12150

100

50

200

250

24

30

350

400

500

450

550

42

36

48

700

650

600

750

800

9.14

4m

C.L

4.57

0m

84

54

60

66

72

78

90

96

-423

LOAD AND HEIGHT CURVESOF HYUNDAI-423

HYUNDAI-423

66/121

GAC MARINE L.L.C. Tel +971 2 501 4900 PO Box 8101 Fax +971 2 550 2895 Abu Dhabi Email [email protected] United Arab Emirates Web www.gac.com

This vessel specification is given in good faith and assumed to be correct but is not guaranteed August 2010

GENERAL:

Built GAC Marine & Engineering- U.A.E., 2004

Flag Panama Class X I 3/3 E. B.V.

MAIN DIMENSIONS:

Length Overall 49.50 m Beam Moulded 13.60 m Depth Moulded 6.40 m Draft (Max) 5.59 m Free Deck Space 205 m2

TONNAGE:

GRT 1148 tons NRT 344 tons DWT 974.96 tons

MACHINERY:

Main Engines 2 x Wartsila W6 L32 Break Horsepower 8,000 BHP Generators 3 x 240 Kw Bow Thruster 650 hp, 7 tons thrust Stern Thruster 400 hp, 5 tons thrust Propulsion 2 x CPP Propellers in kort nozzles Rudders 2 x independent / synchronized

SPEED & CONSUMPTION:

Maximum Speed 14.5 knots Service Speed 12 knots Consumption 9t/24H Free Running

18t/24hrs Towing TANK CAPACITIES:

Marine Gas Oil 741.10 m3 Potable Water 337.4 m3 Ballast Water 359.9 m3

ACCOMMODATION:

Air-conditioning Fully air-conditioned Walk-in cooler 9.70 m Walk-in freezer 9.10 m Berths 15x crew, 17x passenger

Total 32

TOWING & A/H EQUIPMENT

Bollard Pull 110 tons Anchor Winch D.D. Waterfall 200T @ 7m/min,

30 T @ 40M/min Breaking load 280 tons

Wire Dimensions 1200m x 64mm Stern Roller SWL 250 tons, (L) 4.3m x (D)

2.3m Shark Jaws Retractable SWL 300 tons Towing Pins Retractable with horizontal

locking tops Tugger Winch 2 x 15 tons / wire dimension,

38mm x 300m Anchor Windlass 1 wire drum and Smit bracket

SWL 150 ton

RADIO & NAVIGATION EQUIPMENT:

GMDSS Sailor 4000 Radar 2 x Decca Bridgemaster Gyro Compass Anschutz STD-20 Auto Pilot Anschutz Pilot Star D DGPS Koden KGP 931D Echo Sounder Skipper ED 161 Navtex JMC NT 900 EPRIB MC Murdo E3 AIS CNS System

Fifi SYSTEM:

Fire Monitor 2 x 20,000 LPM (FiFi 1) Pump Capacity 2 x 1500m3/h at 14 Bar Horizontal Throw 120 m Foam Capacity 14.5 m3 Detergent Capacity 14.5 m3

MISCELLANEOUS

1 x Water Cargo Pump 70m3/h @60mH, 1 x Sewage Treatment System 1 x F.O. Cargo Pump 90m3/h @ 48mH Spare tow wire 1100 m x 64 mm Silencers equipped with spark arrestors Hydraulic knuckle boom crane 9 m / 2.1 T capacity 3 m / 6.5 T capacity Oil dispersing system Lifting points fitted at stern for emergency propeller repairs, etc.

SUSANNA ANCHOR HANDLING TUG

67/121

68/121

DOCUMENT TITLE


DOCUMENT Number


44 of 48 REVISION

1 BRZ GX


7.2 APPENDIX.B: DRAWINGS

7.2.1 PIPELINE DETAIL ENGINEERING DRAWINGS

Before mobilization, the detail engineering drawings listed in BRZ-GX-D-PL-0500-001 shall be provided

in HD-423.

DOCUMENT TITLE


DOCUMENT Number


45 of 48 REVISION

1 BRZ GX


7.2.2 PIPELINE INSTALLATION DRAWINGS

S.N. Drawing No. Drawing Title

1 BRZ-Q5B0-PL-- 1000 PROJECT FIELD LAYOUT

2 BRZ-Q5B0-PL-- 1010 HD-423 PLAN & E

BRZ-GX-O-PL-0503 Pipeline Installation Procedure R1 2

Documents

Transcript of BRZ-GX-O-PL-0503 Pipeline Installation Procedure R1 2