Our Innovative Breakthrough Vessel: 5 ura 30 0 Sapura 3000 is the most advanced and versatile vessel for

conventional and deepwater construction activities in the

region .

This purpose-built combination vessel (pipelay and heavy

lifting) is unique in its overall capabilities, w ith dynamic

positioning in deep and shallow water and fully revolving mast crane capable of 3000ST lifts. Conventional S-Lay is

used for shallow water, pipelay and steep S-Lay or Hay for

deepwater pipelay and/or steel catenary riser installation in

water depths of up to 2000m.

SapuraAcergy has further enhanced the vessel's capabilities

by installing two (2) permanent Work Class Remotely

Operated Vehicles (WROVs) Due to the WROVs having

extreme ly long excursion capabilities, the need for a

standalone support vessel to monitor pipe touch-down

in many cases is not required . Driven by fibre optics, this

veh icle is the most sophisticated medium in the remote

construction market

Sapura 3000 has accommodation for up to 330 people w ith full office facilities, recreation room, gymnasium and helideck suitable for Sikorsky S92, providing a friendly and

conducive environment for offshore activities.

SapuraAcergy is committed to an incident-free workplace

and has taken the necessary precautionary steps to ensure

the Sapura 3000 and its crew adhere to the highest quality

and safety standards (1S0 9001 and OHSAS 18001 )

In addition, SapuraAcergy is certified with ISO 14001 for Environment Management System, Document of Compliance (ISM Code) and International Ship Security (ISPS Code) All the Management Systems are achieved through SapuraAcergy's Integrated Management System OMS) as certified by the American Bureau of Shipping

(ASS).

Strength and Depth

Sa u a 300 specifications.... - , .... ..... ......... .

.... ...... -......... ., .........'

3000ST" at 27m rad ius

22005T at 3 1 n1 radius

8005T at 53m radius

2200ST at 9 1 m radius

MAIN PARTICULARS

Length 15~1.2m

Breadth mou lded 378m

Dept h to work deck, moulded 15.0m

Depth to freeboard deck, moulded 9.1m

Draft, m aximum loaded 6.5m

Classification A 1 (E) AMS DPS-2 Heavy LifV

Pipe Laying Vessel

Flag Bahama's

Helldeck SUitable for Sikorsky S92

Accom modat ion capacity 330

Transit speed 8-10 knots

Deck load capacity, work deck 10 IviT/sq.m

Free deck area 2000sq. m

ACCOMM ODATION

Ali cab ins have int pgra ted toiie t faci lities equipped w!ih vacu um sy~tern

lO x l -person cabins 50 x 2-oerson cabi :i s 5.5 x 4~ p~ r s o!l cdb,n ~,

FtJUy ajr-cond itioned accommodat ion equipped w ith offices for ciients,

recreation mom, gymnasium, v;deo roo m, nplicopter drrivaUdepc1rture roO I~ l ,

prayer room, etc.

POWER GENERATION

Main diesel generat ors 6 x 4000kW

Emergency diesel generator 1 x 1000kVV

PROPU LSION & DYN.II.M lC POSITIONING

Non-retrac tabl e aziiTtwh 2 y 2400kW

Thftl$ters (stern )

.Retractable a.z irnu th th rusti.::rs 5 x 2400kW

Kongsberg SDP22 CLASS II systelll

AUXILIARY EQUIPMENT

• \IVater makers 2 x 60T Iday capacity

fI Sewage treatment system Suitabie for f ull complement

• Oily water separator

SA FETY EQ UIPMENT

Li feboat 4 x 85 persons capacity Li te raft 100% capaCily

Spri nk ler sys-tern In (lccornrn oda t!on

• Fi re detection system in accommoda tion

and rnachinery SpdCt:S

.. Waler mist system in engIne room • CO2 fire fighting sys le~ 1

• Foam system for hefldeck

TELECOMMU NICATIONS EQUIPMENT

VSAT (Dual Antenna) w ith 1M bps Data Link

GiV1DSS 512

INMARSAT Fleet

HEAVY LIFT CA PABILITY

Heavy Lift M ast Crane

Capaci t y, ma in ho ist

(± 25" over stern)

Capacity, main hoist revolv ing

Capaci ty, au>~ lI ia r y hoist

CapaC! ty, Wll'P nOIS!

* (Main hoist capaclW can be upqraded to 3000111 T)

Vv'h ip hOIst is su itabie for 2000m of hook tr"avel in sir,glf:l part reeving

C'i \Nhip iioist and auxi liary hOlst can be reeved together to achieve subsea Irftinq capabti lt ji of approx 300ST for ' j aOOrn hcok travel or approx . 7005T

for 500m o f hook tra vel

Anti-heeling System for Crane Operations

Ded icated pumps 1 x 1600cum/hr

3 x ! 200cum/ ll r

SUBSEA STRUCTURE INSTALLATION

• Usrng main crane

• Using A&R winch via A-frame over port or starboard Side

PIPELAY CA PABILITY

Pipe size 6" to 60" diameler plus

concrete coating

No. of work stations 9 stations in total

6 off weld ing stations + 1 off NDTI

repair stiltion + 1 off station for

corrooion coatingtolasting + 1

off field joint coaling

Cel ltre-Iay fi ring line S-Iay system cons,st ing of

• Pipe handl ing ((anes on the work deck

• Pi pe storage on work deck

• Endo conveyor line to the bevelling stat ion on work deck

• Bevelling station v'lith transverse conveyor

and transfer vehicle on work deck

• Pipe 21evator loader and elevator for transport of th e pipe

to the freeboard deck through pipe load ing hatch

• [nc:io conveyor line fo r j Cansport to the ready rack transverse

chain conveyor on the freeboard deck (port)

• Transverse chalfl conveyor & transfer v~hlcl es on freeboard deck

• Line up slatlo n With seam rollers on freeboard deck

• Pipe support ro ll ers ,n fll'lng line on freeboard deck

3 o ff l ensioners and A&R Winch

• Movabie work stations in firing line

• Stinger & stinger handling system

• Transfer vehi cle fOl' transport of rejected Joints to the kick out

endo con'leyor line on f reeboard deCK and subsequent removal

through kICk o ul hatch by pipe handling crane (starboard)

Ten sioners 3 x 80 lvlT

A&R winch

Line pull, max 360MT

Wire capacity 3000m of 109mm wire

Pipe Davits 6 x SOivlT capaci ty (C an be

installed on port or sl (:l rboard side)

Stinger

Total length 90m (adjustable geometry In

three sections)

fv1i!lirnurn overbend radius 70m

Iv1a,xlmurn pipe depart ure angle 87deg

EqUipped with load cells,

underwater cranes & lights etc.

Stinger handling tackle capable

01 adjustment o f tJle stinger from

su rVival condi tion to t he minimum

over bend radiUS. Handling system

IS eqUipped with backup tackle.

Stinger can be installedlremoved

using main crane.

Pipe handling cranes 1 oil 011 port Side & 1 off on

starbOcHd side. Capac!W - 40ST at 29m ra dius. i\/i3xlrn llm outreach of

4'3m Both cranes certified fo r man

[ioll'1 g. EqUipped With an ti-co il 'sion

system.

OPTIONAL OPERATIONS

J-Iay System

• System is installed on starboard side when required

• Designed for rapid installation and removal with main crane

• USIllg 360MT A&R Winch • Pipe size up to 20" d,ameter

• Double joint Installation

• Installation of SCRs and flowlines

2 Units of Work Class Rem o tely Operated Vehicles (WROVs)

~ Vehide Techn ica l SpecificatIon (Dept h Ralin ;; 3000m)

u Hydra ulic System {1 x i 50 Shaf t HP Electric Motor)

¥ lVla nipulators (5-fu l lCtio n Schi ll ing Rigma'iter)

( 7-f unctlo ~ Sctlfl lmg T4)

• TeH1er (\.1anagernen t Syste m (TMS)

iii

~SapUraAcerg~

Work Class Remotely Operated Vehicle (WROV) Permanently Installed On oar t Sapura 3000 has further enhanced its capabilities by installing two (2) work class ROVs systems - the Acergy Core Vehicles (ACVs). The ACV is one of the most advanced ROV systems available and is designed to support SURF, IMRand Survey operations.

The ACV is driven by a 150SHP hydraulic system comprising of a 21 Occ mam pump and 71 cc auxiliary pump. The ACV is configured with four (4) Sub-Atlantic SA420 horizontal thrusters and four (4) Sub-Atlantic SA300 vertical thrusters giving a substantial bollard pull and a stabie vertical lift capability. The ACV is also fitted with a subsea dynamic positioning system "Station KeepTM" wh ich provides enhanced control of the ROV during operations

ur 0 The ACV is fitted with a Schilling T4, 7-Function Master Slave Manipulator and a 5-Function Grabber as a complimenting pair to provide a very versati le range of manipulator operations.

The ROV system is designed to provide an efficient intervention support to projects and is equipped with a high level of structural intervention points. There is a range of hydl'aulic and electrical connections for the operation of tooling and auxiliary equipment The connections are all designed to be easily accessible and are of a " Plug and Play" design for quick, efficient change out of equipment

The Tether Management System (TMS) can accommodate up to 1500m of tether for long excursion operations. Thisenables the ,A.CV to perform touch down monitoring in deeper water depths. To further enhance the excursion, the Til/IS unit is fitted with two (2) SA420 thrusters to enable TMS heading hold and offsets from launch point

Strength and Depth

ACV specifications . . . . .. . . . ....... . ........... ...... . . . .. . . . . . ' "

VEHICLE TECHNICAL SPECIFICATION

Depth Rating 3000m Forward Thrust 1000kg bollard pull Lateral Thrust 720kg bollard pull Vertical Thrust 600kg bollard pull Propulsion comprises of 8 Sub-Atlantic th ruster units 4 x SA420 vectored horizontal 4 x SA300 vert ica l Speed : 3kts horizontal and 20kts vertical

VEHICLE FRAME Height 1.955m Width 1.899m Length 3.353m Lift Point SWL 7.9Te Through Frame Lift 3.0Te

. . . . . .. .. .. . .... .. . - . ......... .... , ... .. ..... . . . . :

INTERNAL PAYLOAD CAPABILITY 300kg payload over standard ROV fit Nomina lly 150kg on the Manipulator Deck: and 150kg on the Centre Deck .

EXTERNAL PAYLOAD CAPABILITY

Undel·slung 3000kg Rear 1000kg Side 250kg Front 1000kg

HYDRAULIC SYSTEM 1 x 150 Shaft HP Electric Moto l" Main Pump (Linde HPR 02 21 Occ) Auxil iary Pump (Rexroth AWVS071) Aux system can deliver 125LPM 2 ~( 4way TC U for Thruster/Ancil lary equipment 2 x 12 Station valve packs for manipu lators and tooling 1 x High Flow Valvepack

MANIPULATORS 5-function Schilling Rigmaster 7-function Schilling T4

TELEMETRY SYSTEM Schilling Digital Telemetry System (DTS) 3 x DTS 16 Port Nodes

VIDEO EQUIPMENT T4 Manipulator Camera Kongsberg OE15-l 02 SIT Replacement Kongsberg OE 14-366 Colour Zoom Kongsberg 0E15-1 08 PAL 2 x Electric Pan and Tilt Units

NAVIGATION

Tritech Super Seeking Obstacle Avoidance Sonar 8 x 250W DSP&L Midwater Sea lites 2 x 70W DSP&L SeaArc 5000 HID lights (Optional) Seimac ST400AR Emergency Strobe

SENSORS CDL M in ipos II RLG INS RDI Navigator 1200 DVL Kongsberg MST324N Responder Paroscientific Digiquartz depth sensor

TETHER MANAGEMENT SYSTEM (TMS)

Length 2.3m Width 1. 9m Weight in Air 4.5Te Weig ht in Water 3. 5Te Lift Point SWL 12 5Te Latch SWL 8.0Te Tether 27mm OD, 1500m long 35mm OD, 850m long Speed 0-50m/min Average Line Pull 100kg

--

~SapUraACerg~

DEEPWATER PROJECT

Kikeh Gas Pipeline System for Kikeh Development Project Introduction

The Kikeh Field was discovered in August 2003 and w as pipeline installed in the Asia Pacific region to date, and a

the first offshore deepwater development in Malaysia. major milestone for both SapuraAcergy and Malaysia.

The field's first oil production commenced in August 2007,

some 5 years after the commercial discovery of the block. SapuraAcergy was awarded the EPCIC contract by Murphy

Sabah Oil Company, Ltd. (the operator) for the Kikeh

The Kikeh Field is located 11 Okm off the north-west coast Gas Pipeline System for the Kike h Development. The

of Sabah, Malaysia in a water depth of approximately project was successfu lly completed in 2008 with minimum

1450m making the Kikeh gas pipeline the deepest rigid installation dow ntime.

Strength and Depth

Project Name

Client

Contract Type

Water Depth

Project Duration

Vessel Uti lised

Scope of Work

Project Overview

The Kikeh Field was developed utili sing dry tree wells

located on a Dry Tree Unit (DTU) floating platform and

subsea completions connected to a turret-moored Floating,

Production, Storage and Offloading (FPSO) vessel through a

system of subsea manifolds, pipelines and ri sers.

Treated and stabilised crude oil wi ll be periodically offloaded

from the FPSO to shuttle tankers via tandem offloading.

Associated gas wil l initial ly be re-injected into the Kikeh

reservo ir until commissioning of the Kikeh Gas Pipeline (KGP)

system, after which the gas will be exported to the Labuan

Gas Te rminal (LGAST) plant on Labuan Island for sales to the new PETRONAS Mega Methanol plant. The KGP system

includes a shallow water tie-In flange located at the proposed

Kinabalu Deep and East platform w here infill gas may be

injected into the KG P at a future date.

SapuraAcergy was appointed for the performance of offshore

installation work at Kikeh Field for the Kikeh Gas Pipeline

System . The scope of work Includes the complete EPCIC of a

138km, 12 " diameter export pipeline insta ll ed in water depths

between 13S0m and 14S0m to shore (Om) The contract

included the line pipe procurement and coating, shore

crossing w orks, the installat ion of a deepw ater pipel ine end

terminat ion (PLET), tie- in jumper spool and an in-line future

tap tie-in at the Kinabalu East/Deep Platform.

Project Fact Sheet

Kikeh Gas Pipeline System

Murphy Sabah Oil Company Ltd

Engineering, Procurement, Construction, Installati on and Commissioning (EPCIC)

From Om (Shore) to 14S0m

2006 - 2008 Kikeh Phase 1 - Gas Export Pipeline Kikeh Phase 2 - PLET Installation

Sapura 3000

Performance of offshore insta llation works at Kikeh Field - EPCIC - wh ich includes:

• Deepwater tie-i n to t he Kikeh Field

.. Tie-in jumper connecting the PLE M to the gas injecti on/export manifol d (G IM) suppl ied/ instal led by others;

• ShalIO\A/ w ater tie-in f lange located at the proposed Kinaba lu Deep and East Platform loca tion for future tie-in;

• Provision for deepwater t ie-in for future tie-in at the Kikeh PLEM;

o 12" nominal diameter carbon steel pipeline from the PLEM to the onshore beach valve stati on at Labuan;

• Onshore maintenance valve; and

• Provision of operational pig launcher for operations/inspection/pigg ing

PlpeliJle conditioning spread at shore work-site

Project Challenges

The Kikeh export pipeline contract involves the complete

EPCIC of a 138km, 12" diameter export pipeline installed

in water depths from the beach (Om) out into the Kikeh

field at 14S0m. The contract illCluded the line pipe

procurement and coating , shore cross ing works, the

installation of pipeline end termination (PLET) in deepwater,

the insta llation of a tie-in jumper spool and an in-line

future tap t ie-in at the Kinabalu East/Deep Platform.

Subsea completion work w as performed util ising the two (2) permanen tly deployed ROVs on board the Sapura 3000

in 14S0m water depth. Th is included a SOm long spool

installation and pipeline pre-comm issioning operations.

The KGP project was completed with minimum downtime.

Challenge 1 - Shore Crossing

Shore crossing operations were performed by SapuraAcergy

from onboard the DLB Sea Horizon. The shore crossing

consisted of a 750m section of pipe being pul led from the

lay barge offshore into the beach. Loads recorded during

the pu ll -in operatloh were up to 90Te in sections. The

operati on was completed successful ly allowing the DLS Sea

Horizon to continue with pipelay operation into a water

depth of 20m. Three (3) units of existing pipelines lequired

to be crossed requiring specifi c pipeline crossings were

constructed during this pipe\ay sect ion.

Figure 1

Challenge 2 - Hook-Up of Pipeline to lGAST

The installation of a pipeline and the connection of

the pipeline at the existing LGAST terminal presented

sign if icant chalienges. With limited access, SapuraAcergy

needed to construct an access from the main road in

Labu an down to the pipe li ne pull -in iocation. This iimited

space also pl'esented chall eng es for the pipel ine testi ng, conditioning and testing operations . The f inal con nection

of the offshol'e pipeline to the land section as shown in

Figure 2, req uired an open excavation over 2m in depth t o

be const ructed in t he tidal zone at the beach .

Figure 2 The final connect ion of t he offshore pipeline to the onshore sect ion

Challenge 3 - Future Tap Tee Installation

At a water depth of 60m, an in-li ne tee needed to be

insta lled during the pipelay operation. The in-line, fu ture

tap tee (supplied by Oilstates), was install ed with an integrated protection frame making the total weight of

the in-line joint 5MT

The future tap tee now sits upright on the seabed for future

hook-up from the Kinabalu B platform that w il l ut il ise the

pipel ine to export sales gas to the LG.AST fac ility.

Challenge 4 - Stinger Change-Out

Pipelay operations up to 120m WD vvere executed vvith a single section stingel' (hinge section). However, to

accommodate pipe laying operations in water depths

beyond 120m, an additional section (section 2) needed

to be installed as a stinger extension to enable a steeper

departure angle for the pipeline to faci litate deeper water

pipelay operations to 1450m WD. In full operation t he total

stinger weight IS 700IVn with an overa ll length of 90m.

Challenge 5 - Deepwater Pipe laydown

Pipelay operations constructed into the Kikeh Field (1450m)

where the pipeline needed to be laid into a 6m x 3m target

box on the seabed. The pipe was laid dow n in an S-Iay

configurati on, into the existing Kikeh Field in an area that

was al ready populated w ith subsea structures and fl exible

pipe. The Klkeh pipeline was laid-dow n successfully inside

t he target box and maximum pipelay lay down tensions

were recorded at lOTe.

Challenge 6 - Deepwater Pipe Recovery and PlET Installation

For the installation of the deepwater Pipeline End

Termination (PI,t T), the Sapu l'a 3000 was mobil ised w ith

a project specifi c pipe hang-off plati'orm that allowed the

pipe to be recovered in a J-Iay confi gul-ation and hung-off

on the side of the vessel , a load of 84Te was experienced

at the new hang-off ciamp . Once the pipe lay down head

'.Nas removed, the 83Te PI_ET was then up-ended and hung

into its near vertical position for connection to the subsea

pipeline The PLET and pipeline w ere welded, tested and

readied for subsea deployment

Once ail tests were complete, the pipel ine and PI_tT vvere

lifted (163Te) and successfully laid onto the seabed into a

target box of 6m x 3m .

Figure 6 Insta Iialion of PLET

Challenge 7 - Subsea Jumper Installation

The final connection between the newly laid Kikeh pipeline

and the existing Gas manifold was made using a subsea

jumper spool . The spool was 45.5m in length and needed

to be installed f looded with" Superdry" fl uid. This f luid

needed to be turned into a gel prior to deployment to

prevent loss during connection operations.

The jumper spool was successfu lly fabricated and tested

onboard the Sapura 3000 by the onboard team and then

deployed and successfu lly connected using t he two (2) units

of work class ROVs. Once installed, the vertica l connections were successfully tested followed by a subsea leak test on

the jumper to confirm its integrity in -situ.

Challenge 8 - Pipeline Testing, Pre-commissioning, Conditioning and Nit rogen Packing

The pre-commiss ioning services were completed

successfully and w ithout a lost t ime incident wh ich was a magnificent result considering the challenges of

6600psig (445barg) test pressure in such deepwater and

with complex subsea arch itecture. Without the use of an

innovative Gel isolation, the project would have been at risk of inducing hydrates immediately upon start up (which

are expensive and difficult to correct) as well as causing

potential de lays to production.

Achievements/Results

The Kikeh f ield is the fi rst deepwater development in

Malaysia. In 2008, SapuraAcergy successfully com pleted

the works at a maximum depth of 1450m making the

Kikeh gas export pipeli ne the deepest rigid pipeline

insta lled in the .I'>.s ia Pacific region to date and a major

milestone for SapuraAcergy.

Additionally, the PLET insta llation at 1450m water depth

w ith a weight of 83MT, was the first of its kind in Malays ia,

and a signifi cant insta llation achieve ment for the

Sapura 3000.

~SapUraACerg~

I CONVENTIONAL PROJECT .

Mumbai High South Re-Development Project Phase II (MHSRP-2) Introduction

The Mumbai High South Re-Deve lop ment Project Phase II construction and installation of new platforms, the laying (M HSRP-2) is a project by the Oil & Natural Gas of pipe lines and subsea cable and the modification of Corporation (ONGC) to support the re-development of the some existing platforms. Sapu raAcergy was appointed by Mumbai High South Field. Discovered in 1974, the field Larsen & Toubro to be the sub-contractor for the offshore

was put on production in May 1976. The MHSRP-2 project insta llation of the three (3) Wellhead Platforms. was awarded to Larsen & Toubro and includes mainly the

Strength and Depth

Project Fact Sheet

Project Contract Name

Location

Client

Contract Type

Water Depth

Project Duration

Vessel Utilised

Scope of W ork

~umbaiHigh South Re-Development Project Phase II (MHSRP-2) - Wellhead Platforms

Mumbai, India

Oil & Natural Gas Corporation (ONGC) . ,. ... - _.... ... ..

Installation Subcontract related to the scope of work (Larsen & Toubro as the main contractor)

71 - 78m

2008 - 2009

Sapura 3000

Installation of 3 Wellhead Platforms (RS 15, RS 16, RS 17), including

• Pre- and post-installation debris survey

• Heavy lift and installation of:

- 3 x 4-legged jackets from 1760 to 1820MT

- 3 x 4 piles of 72" and 78"

- 3 x 12 conductors of 30"

- Grouting of jacket leg annulus

- 3 decks (from 1258MT to 1970MT)

- 3 boat landings

• Remova l of installation aids up to 25m depth

Project Overview

The Mumbai High South Re-Development Projed

Phase II (MHSRP-2) was located in shallow water India,

approximately 87 NM west of Mumbai.

The Project comprised of the installation of three Wellhead

platforms including jacket main piles, straight and curved

conductors, jacket appurtenances and topsides.

The Scope of \Nork included the project management,

procurement related to scope of work, installation

engineering, pre- and post-construction debl'is surveys

and installation.

Jacket lih Driving of pile & hold back wire for pile free fa ll

for SapuraAcergy. The project was completed with

minimum installation down time with the Sapura 3000,

SapuraAcergy's state-of-the-art dynamically positioned

heavy lift and deepwater pipelay vessel.

The MHSRP-2 contract involved the installation of th ree (3)

Wellhead platforms including jacket main piles, straight

and curved conductors, jacket appurtenances and topsides

at 71 m to 78m water depths.

The major challenges for this project were the LogistiCS

(documentation for authorities and daily management) and

the unexpected soil conditions at site (Initial hard layers

followed by soft layers).

The project was completed successfully by focusing on the

Project Challenges logist ics management. The logistics team w orked closely

with Larsen and Toubro and agents to ensure that proper

The Mumbai High South Re-Development Project Phase II and timely documentation w as in place at all times.

(MHSRP-2) was the first project out of Malaysian waters

I - -.--~ ~':l

: CONVENTIONAL PROJECT I

KARRATHA Devil Creek Gas Plant._------­-­ .-­

DAMPIER TO BUNBURY GAS PIPELINE

peninsulaBUffup

HOO Shore Crossing

Cape Preston

Offshore Platform

Project Location

Port Hedland

•r:-end Karratha

Road IExmouth • OnslowI •Pipeline

Reservoir

HOD Horizontally Directionally Drilled

• ••• • • f .. .......... . ..... .. "' . ... ... • •• ".·. ·· ·,···· ,,· ···· . . ... .. .. ............. . . ..... ... .

Devil Creek Development Project from Apache Energy Ltd in Australia ••• ••• • • "' • •• • • ••• • • ••••• •••• ••• •••• •• , •• • G ••• • •• • ••••••••••••••••• • ••• • • , ••••••••• 0 ""0 '

Introduction

The Devil Creek Development Project is a greenfield gas SapuraAcergy was awarded the offshore pipeline and

development which is located approximately 80km northwest platform installation . The Scope of Work includes t he

of Dampier Port off the coast of Western Australia. transportation and the installation of an unmanned

wellhead platform comprising of a four-legged jacket

The project comprises of an offshore gas production and topside; together with a single 16 " x 91 km raw gas

platform, an onshore and offshore gas supply pipeline, a pipeline which will link the wellhead platform to the

gas processing plant and gas export pipeline tied into the onshore gas plant.

Dampier-to-Bunbury Natural Gas Pipeline.

Strength and Depth

Project Name

locat ion

Client

Contract Type

Water Depth

Project Duration

Vessel Utilised

Scope of Work

I I

~~ >\}

., .~

__ I

Project Fact Sheet

Devil Creek Development Project

Approximately 80km northwest of Dampier Port, North West Shelf, Australia

Apache Energy Ltd.

Main Contractor for the Offshore Transport and Installation Works

Circa 60m

Offshore commencement: September 2010

Offsho re duration : circa 95 days (25 days shal low w ater pipelay, 62 days Sapura 3000,

8 days stabilisation)

Sapura 3000

a Project management

• Industrial Relations (IR) management

.. Transport & installation engineering

• Interfacing with clients other vendors

• Transportation of client-provided materials

• Fabrication of rigid tie-in spools

• Offshore installation and testing

8 Mob & demob of insta llation activities

Q As-built survey and as-bui lt report

J

I" I /- ­

Y FOATY'~BEACH 1

Project Overview

The Devil Creek Development Project (DCDP)

has been ini t iated to recover and process the

gas reserves from the Reindeer gas field located

approximately 90km northw est of the Dampier

Port at water depth of 60m.

The offsho re installation activities comprise of:

• 16 " x 91km pipeline

• Pipeline stabilisation (45 x Rocks Bolts)

• Wellhead Platform (1700Te drilled/grouted

piled Jacket + 450Te Topside)

o SSIV structure c/w protection frame

o Tie-in spools

" Tie-in spool stabilisation (gravity anchors)

e Umbilical and umbilical stabilisation

(mattresses)

• Umbilical protection frame

" Pre-commiSSioning

The project will span a period of 15 months,

including 3 months of offshore installation work .

Preliminary planning and engineering work has

already begun in Kuala Lumpur and in Perth.

Offshore installation work is due to commence

in late 20 10, utilising the Sapura 3000. Sapura

3000 w il l perform the heavy lifting, pipelaying

and subsea tie-in w ork.

FlEINDEER l eu

-

J... '_

Field Location

CONVENTIONAL PROJECT

Lan Do Block 06.1 Phase III Development Project

Introduction

The Lan Do Phase III Development Project is located in the Block 06.1 - Phase III projec v· ill deveto the al Do '!eld Block 06.1 which encompasses both Lan Tay and Lan Do wh ich lies at offshore Vietnam. The field ·s loca·ed 370 m gas fields. Phase 1 of the Block 06.1 development project southeast of Vu ng Ta u city and 27 .6k east of ~h e was completed at the end of 2002 when the Lan Tay exist ing Lan Tay platform, in 190m wa~er depth. Platform started feeding gas through the Nam Con Son Pipeline (NCSP) to the Di nh Co gas processing terminal in SapuraAcergy was awarded the subsea installat ion Southern Vietnam. services for the Lan Do Phase III Development Project f rom

TNK Vietnam BV in September 2011. In 2007, gas compression facilities were instailed on the Lan Tay Platform as part of Phase II Development.

Strength and Depth

roject Contract Name

Location

Cl ient

Contract Type

Water Depth

Vessel Utilised

Scope of Work

Project Fact Sheet

Block 06.1 Phase II I - Lan Do Development Project

Southern Vietnam (Lan Tay/Lan Do Field Vietnam)

TNK Vietnam BV

Subsea Installation Services

Approximately 190m

Sapura 3000 - Pipelay and Umbilical Lay

Rockwater 2 - Tie-I ns and Pre-Commissioning

Provision of Subsea Installation Services, including: • Installat ion of a main and infi eld umbil ical including hydraulic and

electrical flying lead connections to w eil head 1101, 1102 and SSI\I • Pipeline and umbilical t rench ing • l_aying of a 12 -i nch gas pipeline (CRA) including an ILS • Insta llation of Rock support and protection • Insta llation of a PLET and t ie- in to the new pipeline • Installation of SSI\I and tie-in to the existing platform and new pipeline • Installation of subsea jumpers between well 1101 and PI_ET, w ell 1102

and ILS • Pre-commissioning of the pipeline system and umbilica l • Fabrication SOW

Structural fabrication of ILS & PLET W PQ for piping welds Pipe Coating

Project Overview

The Lan Do Phase III Development Project is the first project for SapuraAcergy in Vietnam. Located in the Block 06.1 of the

Lan Do gas field, which is approximately 190m water depth of 370km southeast of Vung Tau city and 27 .6km east of

existing Lan Tay Platform,

SapuraAcergy scope of work covers project management, engineering, line pipe storage and coating, onshore fabrication,

seabed remediation, flowline and in-line structures installation, umbi lical, subsea tie-ins and all associated subsea surveys.

The scope of work also includes mechanical comp letion and commissioning support

The Lan Do Phase III Development Project consist of:

• 2 off veliical subsea we lls located approximately 2.6km apart, tied back via a 12-inch 27 .6km rigid predominantly

13% chrome flowline to a pre-installed 12-inch inconel 625 clad carbon steel riser at the Lan Tay Platform, In line, the

flowline w ill include SSIV, ILS and PLET structures and have 35-off incone! 625 CRA clad carbon steel anode joints

installed along its length for anode placement A combined main and SSIV umbilical and an in-field umbilical with

associated contro l equipment and SUT structures w ill also be part of the scope,

• At the Lan Tay Platform, topside (brownfield) modifications will include insta llation of piping and valves from the top

of existing 12-inch Lan Do riser to a new tie-in point in the exist ing Lan Tay process facilities, installation of a new wet

gas flow-meter, installation of a J-tube extension, installation of structural strengthening, pipe supports and service

platform, combined main and SSIV umbilical pull-in, hook-up and associated contro l system modifications.

~SapUraAcerg~

Montara F"eld Development Project Introduction

The Montara oil & gas field w as first discovered in

March 1988 by BHP Billiton and was operated by

Coogee Resources in September 2003. Later, in

December 2008, PHEP Australasia (Ashmore Cartier)

Pty Ltd (a Thailand-based petroleum and natural gas

exploration company) acquired Coogee Resources and

took over as the operator of the field. The Montara

Development fie ld consists of the Montara, Swallow ,

Sw ift and Skua fields.

The field is located approximately 690km West of

Darw in, NT (Northern Territory).

Moving forward, the PHEP Australasia (Ashmore

Cartier) Pty Ltd awarded SapuraAcergy with the

Transportation and Installation contract for The

Montara Field Development Project.

Strength and Depth

Project Fact Sheet

Project Contract Name

Location

Client

Contract Type

Water Depth

Project Duration

Vessel Utilised

Scope of Work

Montara Field Development Project: Engineering, Procurement, Load Out, Transportation and Offshore Construction Activities associated with the Removal and Disposal of the Damaged Montara WHP Topside, Transportation and Installation of Rigid Pipelines, Risers, Umbilicals, Spools, Manifold, FPSO Mooring System and the New Montara WHP Replacement Topside

Offshore, Darwin NT, Australia

PTIEP Australasia (Ashmore) Cartier Pty Ltd

Transportation & Installation

Approx. 80m

Approx. 13 months

Sapura 3000 (Heavy Lift) and Rockwater 2 (Diving Support Vessel)

• Removal and disposal of damaged Montara WHP Topside • Transportation and installation of:

- New Montara WHP Topside - Rigid Pipelines - Risers - Umbilicals

Project Overview

The Montara Field Development, consisting of the

Montara, Swallow, Swift and Skua fields, is located

approximately 690km West of Darwin, NT, in the

Ashmore Cartier permit area of the Timor Sea within

the AClRL3 retention lease. PTIEP Australasia (Ashmore

Cartier) Pty Ltd (PTIEP AA), the Operator, intends to

develop these fields and operate the developed

facilities for commercial production of the oil reserves.

The water depth throughout the fields varies

approximately 80m. The Swift and Skua fields are

approximately 17km and 26km respectively north­

northwest of the Montara field.

SapuraAcergy was awarded the Transportation and

Installation of the Montara Development Project. Its

- Spools Manifold FPSO Mooring System

• Installation of:

* 14", 10", 6" & 4" rigid pipelines

* piled moorings, chain and STP Buoy

* subsea manifold and riser base structures

* flexible risers and statiddynamic umbilicals

* rigid spools

• Pipeline and umbilical stabilisation

• Pre-commissioning

• As built survey

• Demobilisation of Marine spreads

Offshore installation work will be performed by the

SapuraAcergy vessel, the Sapura 3000 and supported

by Rockwater 2 supplied by Subsea 7.

scope of work consists of Engineering, Procurement,

Load Out, Transportation and Offshore Construction

Activities associated with the Removal and Disposal

of the Damaged Montara WHP Topside; as well as 12'1<

Transportation and Installation of Rigid Pipelines,

Risers, Umbilicals, Spools, Manifold, FPSO Mooring

System and the New Montara WHP Replacement

Topside.

Detailed activities falling under the purview of

SapuraAcergy include:

Transportation of permanent works to site:

• Mobilisation of marine spreads to perform the

offshore works

• Pre-installation site survey

• Removal of existing wellhead platform

• Rigid spool piece fabrication

.-w;;;;.;;~.--- ­'w

f£lm _____-' 124: E:¢: Hay>\«>ll 1

/-<70.,.., I /

!----;---'/

Wi}\y- j i lOr I

r . J ~.

-­\ ," t-.~ '1- ._.) L- -~~ " - ; 4'-G>

...... e .. ...... O.:l ••• ,. ~ . ... I .. .. ........ O~ ••••• •• ••••••••••• ..... . .. ... . " . .. . ................ .

Iwaki Platform Decommissioning Project

Introduction

The Iwaki Gas field, operated by Offshore Iwaki

Petroleum Co. Ltd., was initially discovered offshore

Japan in 1973, developed in 1983 and ceased production

in 2007. Offshore Iwaki Petroleum Co. Ltd.'s consortium

comprises ExxonMobil, Yugen Kaisha and Tonen General

Sekiyu K.K.

Located approximately 40km east of Nahara Cho, in a

water depth of approximately 154 metres, the Iwaki

Platform consists of a steel jacket structure, topside

drilling, production modules and a 12 " diameter pipeline

Strength and Depth

for transporting gas from the field to the onshore plant in Nahara Cho.

SapuraAcergy, using their key asset, the Sapura 3000,

was awarded the Heavy Lift Subcontract of the

Decommission ing Scope. This subcontract includes lifting

and transportation of the topsides, Jacket and sections

of the 12 " gas export pipeline to an onshore location for

disposal by others. The decommissioning work w as

successfully com pleted in July 2010

Project Fact Sheet

Project Name Iwaki Platform Decommissioning Project

location Iwaki Field, Japan

Operator Offshore !waki Petroleum Co. Ltd.

Client Nippon Steel Engineering Ltd.

Contract Type Heavy Lift Sub-Contract

Water Depth 154m

Project Duration 2009-2010 (Approximately 60 Days Vessel Onsite)

Vessel Utilised Sapura 3000

Scope of Work SapuraAcergy's scope includes the following:

• Removal of topside facilities and module support frame

• Cutting jacket members at EL-92 metres

• Lifting of upper section of jacket, lowering onto seabed and toppling

• Cutting and stabilising export pipeline

Project Overview

The Iwaki Gas facility, commissioned in 1983, consists of

offshore drilling, process and accommodation modules

installed on a jacket structure. A gas pipeline transports

gas from the field to the Offshore Iwaki Petroleum onshore

plant in Nahara Cho.

The Iwaki platform has 8 legs, weighs 20,735MT and stands

in 154 metres of water. The platform is located 40km off

the east coast of Japan and was the first ever installed

offshore Japan. It is also the largest to be decommissioned

in Japan. The Iwaki platform was shut down in 2007.

SapuraAcergy Sdn Bhd was awarded a sub-contract in May

2009 for the Iwaki Platform Decommissioning Project which

included:

.. Removal of 16 modular topside lifts ranging from

10MT to 1100MT

e 118 subsea cuts, at a depth of 92m

$ Removal of 16 No. pile sections

• Cutting and removal of a section of 12" pipeline

~ Lifting the jacket, lowering to seabed and toppling (to

create an artificial reef)

This proJect, worth an estimated US$60 million, was

successfully completed on behalf of Nippon Steel

Engineering Co. Ltd., in July 2010.

Project Challenges

Challenge 1 - Environmental Conditions

From historical weather data and knowledge of the sea

conditions and downtime during installation, it was known

that measures vvould have to be taken to mitigate the

weather risk. This was carried out by physical measures to

enable lifting to continue in poor conditions and project

planning to ensure as many work faces were open at any

one time. It was also essential to ensure that some of the

work faces were not sensitive to adverse weather.

The above strategy proved to be successful and allowed the

topsides operations to run almost in parallel to the less

sensitive subsea works.

Challenge 2 - Jacket Cutting Philosophy

Tr·aditionally, jacket cutting had been performed upon

completion of the topside removal. On review of previous

decommissioning offshme programmes, it was clear the

subsea cutting scope carr ied a huge schedu le and

operationa l risk. With this knowledge, SapuraAcergy

developed a method to mitigate these risks and reduce the

overall offshore schedu le. This includes the development of

a full structural model of the jacket which allowed the stress

w ithin each leg and brace to be calcu lated. Within the

model, each of the planned module lifts was able to be

simulated and the resu lting changes in the leg and member"

stl"esses were able to be accessed. This method allowed the

low stress liiembers to be identified, enabling a sequence of

stl"uctura l members to be cut after each lift

Challenge 3 - Subsea Cutting Equipment

In order to reduce risk and improve schedu le, it was

concluded that "Fly to Place" cutting equipment was required.

Following a market revievv, it INas found that although the

cutti!ig tool ing to complete the cuts was ava ilab le, a rel iab le

ROV delivery system was not. ,6.fter a demanding selection

process, which cumu lated in a 400te diamond w ir"e

compressiorl cut being perfmmed, Proserv offshore were

awarded the jacket cutting subcontract.

The ROV delivery system was identified as the cr it icai

component to enable cutting operations to be carried out off

the critica l path. SapuraAcergy, Proserv and TMT worked

together to design, build, complete factory acceptance 2nd site

testin9 of the ROV delivery system. Refiliements were made

throu9hout this process which ensured a fuHy integrated and

rigor"ously tested system 'Nas taken offshore .

,6.11 subsea cutting operations We(2 performed off the critical

path and without Impact on the topside lifting and jacket

removal scope .

Challenge 4 - The Jacket lift Challenge 5 - logistics

During the engineering phase, it was determined that

the actual lift weight of the jacket could vary

significantly, depending on the amount of marine

growth and integrity of the jacket legs for instance. In

order to mitigate the risk associated with a large range

of weights, it was decided to seal the jacket legs,

de-ballast them and use the buoyancy created. A

method of ballasting and gradually increasing the load on the crane, in stages, was developed such that the

actua l lift weight could be accurately and predictably

mainta ined. In fact, a buoyancy of 1543MT w as

gained from 78% of the leg length being filled w ith air

resulting in the crane experiencing a total weight of

1050MT.

Lessons Learnt

One of the key challenges to overcome, was the sourcing,

transport, storage and maintenance of the required equipment

Also, due to the remote location, it was essential to have

adequate cont ingency and spares to mitigate the risk of

downtime. The fo llowing list provides an indication of the

magn itude of equipment which was carried on the Sapura 3000:

• 200MT of fabricated insta llat ion aids

• 70 heavy lift slings up to 14" in diametel'

• 75 heavy lift shackles up to 700T

• 14 subsea cutting too ls

• 360m of diamond wi re

• 64MT of garnet (grit)

• 1400m of w ire rope

• 9 compressors

• 1800m of air hose

• Air diving spread

The Iwaki Decommissioni ng project w as SapuraAcergy's first venture into decommissioning work and hence we have gai ned

extensive and detailed first-hand knowledge of the unique challenges associated w ith decommissioning. The follow ing highlights

just of few of the lessons learnt

lesson 1: Risk Analysis - As Installed

The Iwaki Platform was more than 28 years old when decommi ss ioned. One

of the key risks is the reliability of the provided information with regards to

original configuration, modifications, inherent structural defects, weight and

weight growth. For this project, the information provided by our client,

Nippon Steel, was very accurate, with excellent records being maintained.

This information, coupled with many on-site visits proved invaluable in the

efficient planning and execution of the works.

Step 1 Afr" iva! at the j'Naki field; !wdki Platform

Step 2 Li ft 7; Platform af ter Cargo Barge 1 Step 3 Li ft 10; Platform after Cargo Barge 2 Step 4 Lift 13; Platform after the removal of Departure Departure Ivlodule 7, 6 and 5.

Step 5 Lift 15; Platform after removal of all Lilt 15; Plat!orrn afTer the removal of Step 7 The Iwakl Platform was successfLlllj modules removed.

Lesson 2: Regulatory Compliances

It was a cha llenge for Sapura;'\cergy to ensure the compliance with the

Japanese regulatory !-equi!-ements especially \;vhen English is not widely

used as the medium of communication. ,6.s such, an engagement of a

local legal consultant in Tokyo has facilitated SapuraAcergy to establish

a Japan Branch Office (1BO) in !waki-City, Fukushima-prefecture,

application of a Construction LKense for SapuraAcergy, application of

Aviation ljght License for Sapura 3000, personnel \/isq fulfillment and

othel- loca! requirements prior to the execution of the offshol-e

campaign in Japan by Sapura 3000. A Sapur-aAcergy JBO representative

and local Project Engineer was appointed to administer the JBO. Having

a loca l employee has helped the communications between SapuraAcergy

with the local client, suppliers, contractors, government and the

community. It is also learnt that lengthy pel'iod is required for any

fonnalities in Japan. in addition, al! documentation shal! be tl-ansiatea ill

Japanese. As slIch, it is essential to prepare a complete documentation

to shorten the process. The JBO is closed and Construction License is

cancelled I-ight after the completion of the pmject. A.II requirements

were achieved on time or ahead of schedule.

Ach ievements/ResuIts

The Iwaki Platform Decommissioning Project was

SapuraAcergy's maiden decommissioning project

Some key facts include

.. Approximately 276,500 manhollrs were expended

onboard the Sapura 3000

e The total vessel duration was 92 days, of which

approximately 60 days were on site. This was two

days longer than planned

e Seven critical path weather days were incurred

.. Zero lost time incidents were incurred

.. Invaluable experience has been gained from the

Iwaki decommissioning project - this shall enable

SapuraAcergy to execute even more challenging

projects III the future, with confidence we shall

deliver.