NMAGE GDU Tech Bid Rev 0 23rd July 08

SYRIAN GAS COMPANY

NORTH MIDDLE AREA GAS EXPLOITATION PROJECT

TEG DEHYDRATION PACKAGE-PU-03

TECHNICAL OFFER

(Process Group International Quotation: 1168 Rev 0)

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CLIENT STROYTRANSGAZ (STG) PROJECT NORTH MIDDLE AREA GAS EXPLOITATION PROJECT QUOTE NO. 1168 Rev 0 DATE 24th-July-2008

Table of Contents

1 Introduction

1.1 Summary Scope of Supply

2 Technical Details

2.1 Process Design & Guarantees

2.1.1 TEG Process Design Data 2.1.2 TEG System Process Guarantees 2.1.3 TEG Process Description

2.2 Environmental Data

2.3 TEG Utility Consumptions

2.4 Equipment Schedule

2.4.1 Extent of Packaging / Skid Mounting 2.4.2 Instrument & Electrical 2.4.3 Surface Protection, Insulation & Heat Tracing

2.4.4 Pipework, Valving & Supports 2.4.5 Quality Control 2.4.6 Packing, Shipment & Site Re-assembly 2.4.7 Language and Documentation

2.5 Spare Parts

2.6 Assistance and Support from within Syria

3 Attachments

3.1.1 PID Comments

3.1.2 Simulation Results

3.1.3 Reference list 3.1.5 Typical GA's of similar units


1 Introduction

Process Group Intl is a leading supplier of process systems and complete process trains for a range of process industries including the oil and gas and petrochemical industries. Process Group Intl’s continued success depends largely on a team of highly motivated, experienced professionals who are committed to excellence in all aspects of project execution including estimation, process, detailed engineering design, procurement, construction, fabrication and commissioning. Our technical staffs includes engineers with backgrounds in mechanical, civil, chemical, electrical, instrument and process engineering that are supported by a team of technical specialists such as CAD design draftsmen, fabrication, construction and commissioning experts. Process Group Intl is a joint venture between Process Group Pty, Australia (www.processgroup.com.au) & Euro Mechanical Intl, UAE (www.euromechanical .com). Process Group Intl primarily concentrates in Middle East, Asia & Africa regions. Process Group Intl specialises in the supply of the following range of Plant, Equipment and Packages on either a complete EPC or supply only basis. Separation (Oil/Gas/Water)

Test & Production Separators ( 2 & 3 phase) Liquid/Liquid Coalescers Slug Catchers Free Water Knockouts

Gas Conditioning / Processing

Scrubber & Dry Gas Filters Fuel Gas Conditioning Systems Indirect Fired Water/Glycol or Salt Bath Heaters Gas Sweetening Plants (Including Membrane Systems Products) Gas Dehydration Systems (Glycol/ Molecular Sieve/Solid Desiccant) Metering Packages Pressure Reduction Systems

Crude Dehydration and Desalting

Thermal-Mechanical Heater Treaters Electrostatic Dehydrators’ and Desalters

Produced Water Treatment Units

Hydrocyclones ( Deoiling & Desanding) Floatation systems (IGF’s) Dual Media Filters, Magnetic Descaling CPI Separators


1.1 Summary Scope of Supply

PGI’s offer covers the design, material supply, fabrication, assembly, testing, inspection,

painting, preparation for shipment, and documentation of 1 off TEG Gas Dehydration Package.

The Package will comprise the following:

TEG Dehydration Column with integral scrubber

Description QTY

Glycol Contactor, complete with internals and instrumentation and valving as per the enquiry P&I D

Glycol contactor (with integral inlet gas scrubber) to have vane inlet device and cyclone deck to achieve required droplet carry-over specification.

1

TEG Regeneration Skid

TEG Glycol Regeneration Skid, as detailed in the enquiry P&ID ‘s (Reflux (Still) Column Disconnected for loading and transport)

1

The Skid will comprise the following equipment items ; installed on a pre-fabricated skid, complete with all on skid pipework, instrumentation, internals and access steelwork:

Glycol Flash Drum (Horizontal) 1

Rich Glycol Particulate Filter 2

Lean Glycol Particulate Filter 1

Glycol Carbon Filter 1

Glycol Reboiler & Surge Drum c/w natural draft fire tube and stack. Stripping column to achieve 99% glycol concentration. Reboiler to be controlled by BMS panel

1

c/w Reflux Condenser Coil 1

c/w Still Column 1

Glycol/Glycol Exchanger – Plate Type 1

Lean Glycol Circulation Pumps – API 674 2


Overhead recovery systems comprising: Air cooled overhead condenser, Gas/Liquid separator vessel. Fixed orifice ejector, Recycle pressure control valve (actuated butterfly valve), drum level control valve (actuated butterfly valve), emergency vent valve (actuated butterfly valve), one number pressure relief valve to protect reboiler from over-pressure, and instrumentation as per enquiry

Anti Foam dosing unit with 2 off electric dosing pumps 1 Unit

pH dosing unit with 2 off electric dosing pumps 1 Unit

TEG Drain Vessel (30 Days capacity) with 1 vertical submersible pump (1m3/hr)

1 Unit

Imp Notes:-

→ Our offer is subjected to comments on enquiry P&I D as attached with this offer. → We are not possession of Al Furat Engineering Standard Schedule G and hence

MOC of the equipments is based on our experience and industry standard.

In general the skid shall be supplied complete, including:

• Continuous skid supporting all components including ancillaries and controls with beam

drain holes, earthing lugs, and gratings. Drip trays under the filters and Pumps only.

• All local instrumentation and controls as marked in PGI’s supply on attached P&ID’s.

• All electrical/instrument cabling, 316SS cable tray, junction boxes and glands within the

skid limits;

• Junction boxes for all Purchaser interface connections;

• All interconnecting piping, pipe supports, valves & appendages within the confines of the

skid, including drains, with all piping terminal point connections brought to a common

location at the edge of the unit, in accordance with the appended P&ID’s;

• Finish painting, preservation & packing; (Crating of contactor vessel not required)

• Ladders, platforms, walkways and hand railing, grating for safe operation and access to

equipment, valves and instruments etc.;

• Electrical continuity to earthing bosses;

• Air supply header and pneumatic hook-ups;

• Vent and drain headers;

• Lifting equipment, beams, shackles with lifting lugs on vessels, skid and removable items;

• Process and mechanical design guarantee

• Insulation and Personnel Protection

• Third party inspection on pressure vessel coded equipment

• Safe area control system as per attached details.


No special tools or fixtures are currently envisaged for the supplied equipment for installation,

removal and routine maintenance. If special tools are subsequently identified in the detailed

design of the equipment, [including the sub-vendor equipment], then they will be supplied.

Exclusions to PGI Scope of Supply

The following are NOT included in the PGI scope of supply (i.e. Items within client scope).

• Unit / equipment installation at site;

• Cabling, wiring and impulse lines beyond the skid edge junction boxes;

• Electrical, instrument & control wiring between skid edge junction boxes and off skid

items;

• Fire proofing and/or fire protection/detection equipment beyond those stated;

• Power cabling to electric motors (as motor terminal boxes will be located next to skid

edge)

• Roof / weather protection;

• Supply of Utilities and Consumables;

• Special Tools - none required;

• Insulation on Contactor

• Certifying Authority

• Skid Hold-down bolts

• Skid Lighting

• Piping requirements between Contactor & Regeneration Skid

Technical Clarification

• We have not considered separate inlet gas scrubber at the inlet of the contactor. The

contactor will have integral scrubber at the bottom which is common practice acceptable as

per API 12 GDU and Shell DEP.

• No Air Blower (G-K-372) has been considered in our offer. The reboiler burner will be

natural draft type.

• PGI will participate in HAZOP , however any increase in scope

• Document submission schedule to be mutually discussed and agreed during kick off

meeting in the event PGI is the successful bidder.

• For main gas line we have considered piping spec BBO and for TEG line AAO.


2 Technical Details

2.1 Process Design & Guarantees

TEG Glycol Dehydration & Regeneration System is designed using PGI’s validated in-house

programs and HYSYSTM

2.1.1 TEG GDU Process Design Data

The following data has been used for the design of the GDU package.

Temp 30 degC Pressure 36 – 37 barg Gas Volume rate 124,572 kg/hr ( 120% case) Mol.wt 19

Gas composition as per section 3.6 of document Data Sheet for TEG dehydration Package.

2.1.2 TEG System Process Guarantees

PGI guarantees the following;

• 120% design margin and 40% turn down.

• Dew point of the gas leaving the contactor will be - 30 degC

• Lean TEG circulation rates is 11 USGPM ( Including 20% margin)

• Lean Glycol Purity with stripping gas = 99.8 wt %


2.1.3 TEG Process Description

The TEG Glycol Dehydration and Regeneration Package is designed to be in continuous

operation and to handle wet gas.

Plant operation is fully automatic and under normal circumstances requires no operator

intervention. The plant control systems remain active under all circumstances except for when

the instrument air or electrical supply is shutdown.

Feed gas is routed to the Glycol Contactor; where it passes through a inlet scrubber to remove

any droplets entrained in the flow. The gas then passes up through the chimney tray into the

absorbing section of the column, where it flows counter-current to the water lean TEG and

contacts over a bed of structured packing. The TEG absorbs moisture from the gas, thus

achieving the desired water dew point at the top of the tower. A demisting device at the top of

the tower minimises glycol carryover.

The contactor scrubber will be fitting with a high efficiency cyclone deck to achieve droplet

carryover specification

Water rich TEG is fed to the Glycol Regeneration Skid, first flowing into the Reflux Condenser

Coil, mounted in the top of the Glycol Still Column. Should the low level trip fail, then the Glycol

Flash Drum relief valves will handle the relief load arising from the gas blowby condition from

the contactor, in addition to the fire case. Prior to entering the Glycol Flash Drum the TEG has

first been heated in the Reflux Condenser Coil to a temperature which is sufficient for liberation

of gas and liquid hydrocarbons (approx 60 C). The rich TEG is then flashed in the Glycol Flash

Drum to allow free vapours to be released and to allow any hydrocarbon liquids to be separated

and drained off under automatic control via the hydrocarbon bucket. Flash vapour is routed to

the LP Flare. The Glycol Flash Drum is designed for a liquid residence time of 15 minutes at 60

C (based on 50% full) and is provided with a demister on the vapour outlet to minimise glycol

losses to the Flare.

The rich TEG is then filtered in the Glycol Filter, to remove solids [98% > 5 microns]. The rich

TEG then flows through the Glycol Carbon Filter (sized for 100% slipstream flow) where

activated carbon serves to remove glycol degradation and polymerisation products, which may

otherwise build up on heat transfer surfaces.

The rich TEG is then heated by exchange with the hot lean TEG, in the Glycol Exchanger prior

to entering the Glycol Still Column random packed section, after flowing through the glycol flash


drum level control valve. This is located here to minimise vapour in the upstream Glycol

Exchanger.

In the Glycol Still Column the TEG undergoes the necessary distillation to achieve the required

TEG concentration in the Glycol Regenerator. The reflux from the Reflux Condenser Coil

provides additional condensing duty at the top of the Glycol Still Column to minimise the TEG

losses to the vent. The reboiler heat duty is provided by a firetube. Overhead vapours from the

Glycol Still Column are routed to the overhead vapour recovery system.

Lean TEG flows from the reboiler into the glycol stripping column where the glycol is stripped

using stripping gas to achieve 99% concentration.

The glycol then pases through the TEG/TEG exchnager before reaching the Glycol Surge

Drum. Which provides a residence time buffer for circulation variance, and Glycol Contactor

packing drain-down, along with the capacity to allow for 1 month of glycol losses. From here it

passes to the Glycol Circulation Pumps.

The API 674 type reciprocating constant volume Glycol Pump, pumps the TEG back to the

Glycol Contactor, via a lean TEG cooler which serves to further cool the lean TEG to within 5-

10C of the feed gas to the contactor, to minimise vaporisation losses within the Glycol Contactor

and prevent foaming.


2.2 Environmental Data

Air temperature: 5 to 50ºC

2.3 TEG Utility Consumptions Electrical 400 V, 3 phase, 50 Hz TEG Pumps 3.77 kW 24 V DC is also required for control purposes CI Pumps

0.75 kW (Intermittent > 1 hr/month)


2.4 NMAGE GDU Equipment Schedule

The following main vessels & equipment are included in our scope of supply:

Glycol Contactor (free standing skirt mounted)

Size: 1700 mm ID x 12,800 mm T/T Design Press: 48 bar g (Flange Rating 300#) Design Temp: 82ºC Material: CS + 3 mm 316 SS Cladding up to Chimney Tray Design Code: ASME VIII div 1 Packing: Structured Packing

Glycol Flash Drum Size: 1100 mm ID x 3,100 mm T/T [Horizontal Vessel] Design Press: 7 bar g + Full Vacuum Design Temp: 0/85 ºC Material Carbon steel + 3 mm CA Design Code: ASME VIII div 1

Glycol Particulate Filters ( Lean & Rich ) Size: 200 mm diameter, 650 mm T/T [Vertical Vessel] Design Press: 7 bar g Design Temp: 0/85 ºC Press Drop: 0.3 bar [dirty] Flowrate 11.0 USGPM Filtration: 98% of 5µm Material: Carbon Steel + 3 mm CA Design Code: ASME VIII div 1

Glycol Carbon Filter Size: 24” diameter, 1200 mm T/T [Vertical Vessel] Design Press: 7 bar g Design Temp: 0/85 ºC Press Drop: 0.3 bar [dirty] Flowrate 11.0 USGPM Material: Carbon Steel + 3 mm CA Design Code: ASME VIII div 1


Glycol Reboiler –Gas Fired – 150 KW Size: 762 mm ID x 4375 mm T/T[Horizontal Vessel] Design Press: 7 bar g Design Temp: 0 / 235 ºC Material: Carbon Steel + 3 mm CA Design Code: ASME VIII div 1

Surge Drum Size: 762 mm ID x 4400 mm T/T[Horizontal Vessel] Design Press: 7 bar g Design Temp: 0 / 235 ºC Material: Carbon Steel + 3 mm CA Design Code: ASME VIII div 1

Glycol Still Column Size: 14 inch ID, 4500 mm FOF/Head Design Press: 7 barg Design Temp: 0 / 235 ºC Material: 316L Stainless Steel Packing: 1” 316 SS Pall Rings Design Code: ASME VIII div 1

Glycol Stripping Column Size: 8 inch , 1800 mm weir/BTL Design Press: 7 barg Design Temp: 0 / 235 ºC Material: Carbon Steel Packing: 1” 316 SS Pall Rings Design Code: ASME VIII div 1

Glycol/Glycol Heat Exchanger – Plate Type , Fully Welded

Design Duty: 200 kW Design Press: 7 barg [Plate] Design Temp: 0 / 230 ºC Material: SS


Lean Glycol Cooler – Gas / Glycol Design Duty: 50 kW Design Press: 48 Barg Design Temp: 0 / 120ºC Material: CS

Design Codes TEMA ( Shell & Tube Type ) Note :- Gas / Glycol exchanger will be attached to the contactor at the top.

Glycol Circulation Pumps Design Press: 48 bar g Design Temp: 0 / 120 ºC Capacity: 11 USGPM Material: Carbon Steel with Stainless Steel Wetted Parts Design Code: API 674


Overhead Recovery System compromising of the following

Overhead Condenser -Air cooler – 75 KW

Single Bay with single bay & 1 fan

316SS Tubes and Tube Sheets

To be mounted above reboiler.

KO Pot

8” Dia x 1445mm LNG 316L SS Pot

Ejector

1 x Fox type ejector (or equal)

Discharge pressure: 6 psig

Motive gas flow rate : 120 kg/h (Max)

Note the above backage, including piping and valves are offered in 316L SS, however the HP flare header (where the ejector discharges into) is CS with 3mm corrosion allowance

Condensate Pump Design Press: 6 bar g Design Temp: 0 / 80 ºC Capacity: 0.25 m3/h Material: Stainless Steel Design Code: ANSI

Anti Foan Injection Package ( Anti foam ) Tank Capacity: 50 Litres Material: 316L SS Pumps (2 off) Capacity: 0.1 Litres/h Material: 316SS Design Code: API 675 We have provided only one pump as continuous injection is not required.


pH Injection Package Tank Capacity: 50 Litres Material: 316L SS Pumps (2 off) Capacity: 0.1 Litres/h Material: 316SS Design Code: API 675 We have provided only one pump as continuous injection is not required.

Lifting Equipment We have considered the supply of one lifting beam complete with slings and shackles. The lifting beam will be subject to 100% NDT and will be proven by trial lift. The slings and shackles will be proof load tested.


2.4.1 Extent of Packaging / Skid Mounting

The package to be supplied by PGI will comprise;

• Free standing Glycol Contactor(Note :- Gas / Glycol exchanger will be attached to the

contactor at the top)

• One complete TEG regeneration skids complete with overhead recover system

The Still Columns and exposed instruments would be removed for shipment and require re-

assembly on site.

The skid structures will be designed and supplied on the basis that it will be supported on 4

[four] discrete points. PGI assume that the location of these supports can be selected by PGI to

suit the design of the skid structure. Skid members will be sized suitable for a single point lift

and will cater for the dynamic conditions specified (dynamics normally only applicable to

offshore applications), taking due account of any imposed loads from equipment in PGI supply.

No imposed loads from outside of PGI’s package limits have been allowed for.

The responsibility for re-assembly of the package on site rests with purchaser. Any shimming

and attachment of holding down bolts are the responsibility of the purchaser.

Skid mounted pressure vessels will either be welded or bolted to the skid base.

Access will be provided for routine operation & regular maintenance of the plant. Access for

major maintenance activities will not be specifically provided (i.e. no specific access for

maintenance block valves, maintenance spectacle blinds, start-up vents & drains).

Direct mounted instrumentation, (such as temperature & pressure gauges & transmitters), will

be self supported, where appropriate. Instrumentation may also be supported off brackets

mounted on pipework.

2.4.2 Instrument & Electrical

This section covers the main requirements for instrumentation on this contract. Scope of

instrumentation supplied with this package is as defined in the enclosed P&ID’s. Note: our offer

only includes for the supply of instruments indicated within our scope.


Scope of Supply:

Items wired to junction boxes, located at the skid edge.

Skid-mounted Instrumentation: (per P&ID as attached) Pump Start/Stop Stations: Lighting: by others Power Sockets: none Fire & Gas Detection: Engineering to be supplied

Control Panels: No control system will be provided. BMS panel for reboiler will be supplied for installtion in safe area.

Hazardous Area Considerations:

Field instruments are located in the following zone classifications:

Zone: 1 Gas Group: IIA Temp Class: T3

Safety Techniques Used: Zone 0: Exia Zone 1: Exia/ib Ex’d’ Ex’e’ Ex’p’ Zone 2: Classification ignored – use Zone 1 Ex’N’

Enclosure Ingress Protection:

IP: 65

Level Gauges:

Reflex gauges for abolsute level measurement

Transparent for interface level measurement. Tubular glass type for Chemical injection Tanks

Pressure Gauges: Bourdon type, 4” dial

Flow/Restriction Orifice: Square edged orifice flanges, 316 SS

Level Switches/Transmitters:

We have included for Displacement type transmitters for short ranges (upto 1 M) and DP type

transmitters for larger ranges.

Control Valves: Actuator Type: Pneumatic


Valve Type: Globe

Shutdown/Switching Valves:

Actuator Type: Pneumatic Valve Type: Ball

Relief Valves: Type: conventional

The scope of the relief valve system offered, has taken no allowance for elevated flare headers.

Sized in accordance with: API 521 Spared: as per P&ID

Thermowells: Connections to Vessels: 2" 316 SS Connections to Piping 1.5” Connections to Instrument: ½” NPT Minimum Flange Rating: 300#

Transmission / Control: Type of Process Control: Customer PCS Transmission: Electronic 4-20 mA (HART)

Cabling: Colour: Intrinsically Safe (I.S.) Blue Non- Intrinsically Safe Black

Type:

Process Control / Power: Flame Retardant; IEC 332 Shutdown / Safety Systems: Fire Resistant; IEC 331 / 332

Junction Boxes:

Protection: Ex ‘e’ Material: GRP with Brass Continuity Plates

Tray work & Installation: Cable Tray Construction: Medium Duty; Without Covers Cable Tray Material: 316 SS Cable Tray Supports: 316 SS (unistrut) Junction Box Racks: 316 SS (Unistrut)

Note: Single cables may be supported in unistrut.

Hydraulic / Pneumatic Hook-up: Pneumatic Tubing Material: ½" 316 SS Impulse Tubing Material: ½" 316 SS Tube Fittings: Twin Ferrule Compression


2.4.3 Surface Protection, Insulation & Heat Tracing

This section covers the main requirements for surface protection, insulation and heat tracing on

this contract.

Applicable Standards for Surface Protection: PGI Standards Client Standards

Insulation: System: Mineral wool Cladding: Stainless Steel Valves: Un-insulated Flanges: Un-insulated Vessel Nozzles: Un-insulated Personnel Protection: Guards or Insulation as required

2.4.4 Pipework, Valving & Supports

This section covers the main requirements for piping design and installation. Scope of piping

supplied with this package is as defined on the enclosed P&ID’s.

Applicable Standards for Piping Valving & Supports: BBO (Around Contactor) – 12 inch AA0 (Complete Regen Skid) – 1.5 inch

Design Features: Instrument Vents: Blank Flange, tapped and plugged, 1/2" NPT Instrument Drains: 3/4" flange/pipe to drain (where required) Dissimilar Materials: No Project Requirement Drip Rings: Drip Rings may be used to save space Pipe Restraint Method: <=6" NB; Sliding or Gripping 'U' Bolts >6" NB; Pipe Shoes/Clamps/Trunnions, as appr.

Pipe Stress Analysis: Scope of Analysis: None included

In general PGI use sound engineering judgement rather than rigorous calculation on most

piping systems.

Pipe supporting will generally be based on sound engineering judgement & experience and will

not be rigorously analysed, other than in exceptional circumstances (e.g. spring supports).


Butterfly Valves

In view of the low available pressure drops in the overhead recover system – we have

considered actuated butterfly valves for pressure and level control, and for venting to LP vent (if

the HP flare header pressure exceeds the design discharge pressure of the ejector).

We have also considered butterfly valves for isolation of the above items, but the final valve

connecting to the flare system will be a ball valve.

All butterfly valves will be of soft seated, high efficiency, offset design.


Non-Destructive Testing (NDT):

Refer to the following NDT matrix:

Non-Destructive Examination Item Part Radiography UT DPI MPI

L.P. Vessels (ANSI 150# flange rating)

Plate Forging & Fittings Non Pressure Parts

Per Code Per Code Per Code 100% on lugs

H.P. Vessels (>ANSI 150# flange rating)


100% Per Code Per Code 100% on lugs

Manual Valves Pressure Parts Non Pressure Parts

Vendor standard

Vendor standard

Vendor standard

Vendor standard

Control Valves Pressure Parts Non Pressure Parts

Vendor standard

Vendor standard

Vendor standard

Vendor standard

Relief Valves Pressure Parts Non Pressure Parts

Vendor standard

Vendor standard

Vendor standard

Vendor standard

General Instrumentation

Pressure Parts Vendor standard

Vendor standard

Vendor standard

Vendor standard

Structural Steelwork Primary Steel Lifting attachments Secondary Steel Trim Steel

10% 100% 10%

Piping Fabrication

150# - 300# >300#

Pipe & Fittings

10% 100%

10% 100%

Skid Assembly Bolting Gaskets

N/A N/A N/A N/A

Instrument Bulks Cable Tube Fittings

N/A N/A N/A N/A

Valve Requirements: Specification: Client Specification (see above) Special Requirements: per Pipe Spec.


2.4.5 Quality Control

Quality Management System:

PGI operates a Quality Management system which meets the requirements of BS EN ISO

9001:2000. PGI operates a system of QC approval on all sub suppliers.

Material Traceability & Inspection:

Material Traceability and Inspection will be in accordance with the following matrix:

Item

Part

Mat

Cer

tific

atio

n Ty

pe

(EN

1020

4 19

91)

Tr

acea

bilit

y Le

vel

IIA

Invo

lvem

ent

PGI / Nominated inspection agency involvement

L.P. Vessels (ANSI 150# flange rating)


3.1 B 3.1 B 3.1.B

1 1 3

YES Attendance at key hold points: -final dimensions prior to stress relief/hydrotest as applicable - Hydrotest - Final

H.P. Vessels (>ANSI 150# flange rating)


3.1 B 3.1 B 3.1.B

1 1 3

YES Attendance at key hold points: -final dimensions prior to stress relief/hydrotest as applicable - Hydrotest - Final

Manual Valves Pressure Parts Non Pressure Parts

3.1 B 2.1

2 3

NO Goods inwards inspection

Control Valves Pressure Parts Non Pressure Parts

3.1 B 2.1

2 3


Relief Valves Pressure Parts Non Pressure Parts

3.1 B 2.1

2 3


General Instrumentation Pressure Parts 2.2 3 NO Goods inwards inspection Structural Steelwork Primary Steel

Lifting attachments Secondary Steel Trim Steel

3.1 B 3.1 B 2.2 2.2

2 1 3 3

YES YES NO NO

Dimensional check Painting inspection

Piping Fabrication

150# - 900# >900#

Pipe & Fittings

3.1 B 3.1.B

1 1

NO Dimensional / fit-up (Sample) Hydrotest Painting

Skid Assembly Bolting Gaskets

2.2 2.2

2 2

NO Certification control & review E & I and insulation installation stage inspections Final inspection

Instrument Bulks Cable Tube Fittings

2.2 3.1 B 2.2

2 2 2

NO Material certification review Sample inspection


Material Traceability Levels:

(1) Full traceability. Supplier shall provide manufacturer’s material certificates (EN 10204

1991 3.1b). These shall be identified by means of showing their specific location on material

placement drawings.

(2) Type traceability – Supplier shall maintain a system to trace material supplied to a

manufacturer’s material certificate (EN 10204 1991 3.1b).

(3) Compliance traceability – Supplier shall maintain a system of traceability that shall enable

a certificate of compliance to be issued by the supplier (EN 10204 1991 2.1/2.2)

Third Party Inspection Bodies:

External Inspection Agencies are utilised for certification of pressure vessels and Certification of

stated materials and equipment.

Inspection Visits:

PGI will provide suitable notice of agreed Quality Plan notification points, and suitable access to

review / inspect ongoing work (as required).

Function Testing:

The scope of PGI’s function testing will be as follows:

Instrument Calibration at Manufacturer’s Works (Un-witnessed) Cable Continuity / Megger Testing Instrument Functional Test to Skid Junction Box after Skid Final Assembly Rotating Machinery ‘Type’ Tested to Code at Manufacturer’s Works (Un-witnessed) Additional Machine Testing at Manufacturer’s Works as Specified On Data Sheet Noise Tests Package Leak Test (5 psi Air) Panel Function Testing

Release of Equipment & Materials:

All materials and equipment are subject to formal release using the agreed PGI, or Client

supplied, Project release note format.


In general, materials will not be shipped without formal release from client and / or third party

inspectors.

2.4.6 Packing, Shipment & Site Re-assembly

Handling:

The skid module will be designed for a single point lift. Lifting lugs will be provided on the skid. Any equipment items shipped loose will also be provided with appropriate lifting facilities.

PGI will supply all slings, shackles and lifting beams as necessary. Certification as follows: Beam: Service Lift plus NDT Shackles: Proof load test Slings: Proof load test

Packing:

Prior to shipment all equipment will be dried and cleaned of grease, loose scale and debris both

internally and externally.

All exposed flanges and pipe terminations will be greased, sealed with tape and blanked off

using wooden blanks.

All equipment will be suitably protected to prevent damage during transit. Any instrument liable

to damage in transport will be removed and packed separately in wooden cases.

Pumps and other rotating machinery may be shipped without oil. Appropriate filling and re-

preservation requirements will be provided with the goods.

2.4.7 Language and Documentation

Documentation will be provided in English and final documentation will be provided on Cd ROM.

With reference to your provided VDDR, we would advise that Construction Assembly

procedures, Detailed General Arrangement drawings, Piping Line Lists, Padeye/Lifting/Design

Calculations will be advised 8-12 weeks after PO Date. With Fabrication drawings issued in line

with project schedule. Materials certification will be supplied in line with submission of the

Manufacturing Record Book.


2.5 Spare Parts

PGI would recommend and are supplying the following commissioning spares:

• 1 spare set of Particulate filter cartridges for duty filters

• 1 off pulsation damper charging kit

• 100% Filter closure gaskets and 100% spare manway gaskets

• 5 % spare bolts, nuts and gaskets;

• Spare Ignition spark plug and insulators for ionisation pilot flame detector

Special Tools

• Blade setting tool for the aircoolers (1 off)

• Pulsation Dampner charging kit (1 off)

PGI's Field Support department will provide a comprehensive 2 years spares quotation for client

review & purchasing, once engineering is completed & sub-suppliers have been selected,

during contract execution.

2.6 Assistance and Support from within Syria Assistance is provided in obtaining maintenance, repair, and spares through our local agent.

HESCO Details of which can be provided for your perusal if required


3 Attachments

3.1.1 PGI Comments on the enquiry P&I D’s.

3.1.2 HYSYS Simulation Results - Attached

3.1.3 Catalogue, Reference List for TEG Units

3.1.4 GA Drawing & Typical 3D view of the Regen skid of similar size unit.

00875-G350-PR-PID-0120

1. There will be no Chimney Tray on Contactor (G-C-351) 2. Are both PSV 352 and 351 required? No isolation between two vessels and therefore

PSV’s are connected. 3. Are PSV’s required on G-E-357 and G-F-360? These have direct isolation, however if

locked open code may not require PSV’s. Please check. 4. Recommend a bypass around Lean TEG filter to allow element change during

operation. If no bypass, is isolation required? If so, is PSV required? 5. Is isolation required around G-E-357 and G-F-360? If so is a PSV required?

00875-G350-PR-PID-0121

1. PDT361 – A/B are measuring exactly the same pressure drop on the same pipe. Is this required?

2. G-F-362A/B – Are duty/standby units required for these units? Bypass lines have been shown allowing each unit to be taken off-line for short periods during operation.

00875-G350-PR-PID-0122

1. A Condenser Coil is shown using the Rich TEG coming from the Contactor. This stream is not shown on the contactor P&ID. Additionally the Condenser Coil exit stream enters the Rich TEG outlet from the Hot HEX. Is there a reason for this? It would be more suited to enter upstream of the flash drum.

2. G-V-358 is labelled the Glycol Surge Drum in the upper title block and G-V-354 is labelled the TEG Reboiler. This is incorrect.

3. C-V-354 should not be positioned directly downstream of the reboiler. Stream exiting reboiler should pass through Glycol/Glycol exchanger (G-E-356) to recover as much heat as possible. Additionally, temperature exiting the reboiler and in the surge drum would be too high for pumps (since pumps are directly downstream of surge)

4. Is isolation required around G-E-359? Is so, is a PSV required? 5. Line direction between G-V-355 and G-V-365 is incorrect. 6. Line direction between “From Charcoal Filters” and G-V-365 is incorrect.

00875-G350-PR-PFD-0105

1. G-P-363A/B is not required – Pressure is sufficient. 2. Please discuss condenser coil positioning. Would be more beneficial upstream of flash

drum to provide better operation within the flash vessel (higher temp).

Mon Apr 07 10:53:31 2008 Case: S:\1.0 Quotes\1.8 Quotes 2007\07-288 PGI Amine & TEG\Calcs\Hysys\07288_25DEGC_3600KPAG_130.5MMSCFD revC.hsc Flowsheet: Case (Main)

WetGasInlet

MIX-1

Water toSaturate Inlet

Gas

KODrum

SaturatedGas

CondenserInlet Reflux

Coil

CondenserOutlet

FlashTank

FlashCondensate

FlashVapor

FlashOutlet

FilterOutlet

HotGlycolHEX

L/RHEX:RichGlycolOutlet

Filters

B

PressureLet-Down

B

Lean TEGtoContactor

WaterOutlet

Q-Cond

SurgeDrumInlet

VLV-100

StillOverheadGas

Q-Reboiler

Q-Condenser

SurgeDrum

2

SurgeDrumOutlet

MIX-2

Make-upTEGPump

Inlet

TEGRegenPump

PumpOutlet

Q-Pump

TrimCooler-TEGIntlet

TrimCooler- TEGOutlet

Q-Dummy

Dummy

RCY-2

R

RCY-4

R

StrippingGas Inlet

07-288 revCSTG / Syrian Gas CompanyGas Dehydration Package

108.8 MMSCFD + 20% overdesignInlet Temp: 25degCInlet Pressure: 3600 kPag

TEG Circ Rate: 9.2 USGPM + 20% overdesignTEG Concentration: 99.8wt.%TEG Reboiler: 200degC (Max Temp)

FuelGas VLV-101

Trim Cooler - TEG OutletMaster Comp Mass Frac (TEGlycol)Actual Volume Flow

0.998311.06 USGPM

SPRDSHT-1

Q-Pump

Heat Flow 3.773 kW

Hot Glycol HEX

Duty

Minimum Approach

194.9

30.00

kW

C

Q-Reboiler

Heat Flow 146.5 kW

Q-Condenser

Heat Flow 7.313 kW

Make-up TEGTemperaturePressureMass Flow

25.00350.0

7.323e-002

CkPagkg/h

CompSplitter

GasProperties

TEG

1

Outlet ofGas/GlycolExchanger

TrimCooler

RichTEG

Trim Cooler

Duty -51.80 kW

Q- Cond

Heat Flow 7.314 kW

ReboilerBottoms

Contactor

DryGas

StillColumnInlet

Reboiler Bottoms

Master Comp Mass Frac (TEGlycol) 0.9982

Still Overhead Gas

Temperature

Master Comp Mass Flow (TEGlycol)

Mass Flow

98.01

0.2984

174.5

C

kg/h

kg/h

Pump Inlet

Temperature 60.15 C

StillColumn

ColdGlycolHEX

FlashInlet

Hot HEX -LeanOutlet

RCY-1

R

ColdHEX -LeanInlet

Cold Glycol HEX

Duty

Minimum Approach

74.41

28.39

kW

C

op-104

VS

Water DewPoint @ 75 barg

Condtions

GPCondtions

WaterDew -32.08 C

ACHECondenser

OutletofACHE

G-V-355

Q-ACHEToLPFlare

ToTEGDrainVessel

To LP Flare

Temperature

Pressure

Mass Flow


60.00

16.00

68.81

0.0055

C

kPag

kg/h

kg/h

To TEG Drain Vessel

Temperature

Mass Flow


60.00

105.7

0.2929

C

kg/h

kg/h

LeanFilter

B

LeanFilterInlet

op-102

GP

op-102

lbH2Ommscf

WaterDew

0.5662

-35.32 C

Mon Apr 07 10:58:55 2008 Case: S:\1.0 Quotes\1.8 Quotes 2007\07-288 PGI Amine & TEG\Calcs\Hysys\07288_25DEGC_3600KPAG_130.5MMSCFD revC.hsc Flowsheet: Case (Main)

Hot HEX -LeanOutlet

RCY-1

Streams

Vapour FractionTemperaturePressureMolar FlowActual Volume FlowMass FlowMass DensityMolecular WeightViscosityMaster Comp Mass Frac (H2O)Master Comp Mass Frac (TEGlycol)

CkPagMMSCFDUSGPMkg/hkg/m3

cP

Wet Gas Inlet0.999825.003600

130.61.731e+004

124560.031.6919.15

<empty>0.00110.0000

Water to Saturate0.000025.003600

1.114e-0034.366e-003

1.01008

18.020.89051.00000.0000

Inlet Gas0.999825.003600

130.61.731e+004

124561.031.6919.15

<empty>0.00110.0000

Saturated Gas1.000025.003600

130.51.731e+004

124537.231.6819.15

1.236e-0020.00090.0000

Condenser Inlet0.011627.82620.0

0.520216.10

2946.4805.7113.7

<empty>0.04090.9548

Condenser Outlet0.011731.76600.0

0.520216.37

2946.4792.6113.7

<empty>0.04090.9548

Flash Condensate0.000070.00550.0

0.00000.0000

0.0479.757.68

0.10780.00250.0000

Flash Vapor1.000070.00550.0

6.082e-0035.769

6.95.28422.86

1.363e-0020.00930.0001

Flash Outlet0.000070.00550.0

0.514111.99

2939.51079

114.87.393

0.04100.9570

Filter Outlet0.001470.17350.0

0.514113.01

2939.5995.1114.8

<empty>0.04100.9570

L/R HEX: Rich Glycol Outlet0.0038158.3300.0

0.514116.73

2939.5773.8114.8

<empty>0.04100.9570

Lean TEG to Contactor0.000030.003800

0.381111.06

2818.01121

148.425.51

0.00150.9984



cP

Water Outlet0.000025.003600

2.648e-0020.1038

23.81008

18.020.89040.99960.0000

Surge Drum Inlet0.000760.155.000

0.381612.79

2818.2969.8148.3

<empty>0.00150.9982

Still Overhead Gas1.000098.0121.00

0.18811034

174.50.742918.63

1.050e-0020.66570.0017

21.000060.155.000

2.496e-0041.424

0.20.717818.67

1.260e-0020.00180.0006

Surge Drum Outlet0.000060.155.000

0.381311.37

2817.91091

148.49.870

0.00150.9983

Make-up TEG0.000025.00350.0

1.338e-0052.882e-004

0.11119

109.923.40

0.05000.9500

Pump Inlet0.000060.155.000

0.381311.37

2818.01091

148.49.870

0.00150.9983

Pump Outlet0.000058.753950

0.381311.29

2818.01099

148.410.28

0.00150.9983

Trim Cooler- TEG Intlet0.000060.153850

0.381311.30

2818.01098

148.49.911

0.00150.9983

Trim Cooler - TEG Outlet0.000030.003800

0.381311.06

2818.01121

148.425.50

0.00150.9983

Stripping Gas Inlet1.00006.21240.00

5.555e-002199.353.0

1.17119.15

1.080e-0020.00000.0000

Fuel Gas1.000026.353520

5.555e-0027.59153.0

30.7419.15

1.238e-0020.00000.0000



cP

Gas Properties1.000026.373520

130.41.782e+004

124408.730.7419.15

1.238e-0020.00000.0000

TEG0.0000210.43520

2.555e-0058.640e-004

0.2974.0150.2

0.52290.00001.0000

10.0277156.360.00

0.514181.38

2939.5159.0114.8

<empty>0.04100.9570

Outlet of Gas/Glycol Exchanger1.000026.373520

130.41.782e+004

124408.930.7419.15

1.238e-0020.00000.0000

Rich TEG0.000025.823600

0.520211.62

2946.41117

113.722.58

0.04090.9548

Reboiler Bottoms0.0000191.625.00

0.381512.69

2817.9977.4148.3

0.67110.00150.9982

Dry Gas1.000025.973570

130.41.752e+004

124408.931.2619.15

1.239e-0020.00000.0000

Still Column Inlet0.0276156.360.00

0.514181.28

2939.5159.2114.8

<empty>0.04100.9570

Flash Inlet0.011770.00550.0

0.520217.76

2946.4730.4113.7

<empty>0.04090.9548

Hot HEX - Lean Outlet0.0004100.215.00

0.381512.66

2817.9979.9148.3

<empty>0.00150.9982

Cold HEX - Lean Inlet0.0004100.215.00

0.381612.66

2818.2979.9148.3

<empty>0.00150.9982

Water Dew Point @ 75 barg1.000016.507500

130.47223

124408.775.8319.15

1.384e-0020.00000.0000



cP

Outlet of ACHE0.375160.0016.00

0.1881364.8174.52.10618.63

<empty>0.66570.0017

To LP Flare1.000060.0016.00

7.057e-002364.468.8

0.831419.57

1.196e-0020.15630.0001

To TEG Drain Vessel0.000060.0016.00

0.11750.4746105.7980.818.06

0.46680.99720.0028

Lean Filter Inlet0.000060.063950

0.381311.30

2818.01098

148.49.935

0.00150.9983

Q- Cond<empty><empty><empty><empty><empty><empty><empty><empty><empty><empty><empty>

Q-Reboiler<empty><empty><empty><empty><empty><empty><empty><empty><empty><empty><empty>

Q-Condenser<empty><empty><empty><empty><empty><empty><empty><empty><empty><empty><empty>

Q-Pump<empty><empty><empty><empty><empty><empty><empty><empty><empty><empty><empty>

Q-Dummy<empty><empty><empty><empty><empty><empty><empty><empty><empty><empty><empty>

Q-ACHE<empty><empty><empty><empty><empty><empty><empty><empty><empty><empty><empty>

Gas Dehydration- Glycol A.01

PROCESS GROUP Pty. Ltd.16 Kearney Street

Bayswater, (Melbourne)VIC 3153, Australia

Tel: +613 9720 1600Fax: +613 9720 1158

Email: [email protected]: www.processgroup.com.au

Photo: Spring Gully TEG Dehydration Package.Duty: 50 MMscfd / 10.4 usgpm TEG.

Location: Queensland, Australia (installed 2004).

IntroductionIntroduction

The use of Glycol to dehydrate gas streams is an established method that has proven its functionality and versatility over many years.

There are 3 common types of Glycol used for Gas Dehydration:

• Mono-Ethylene Glycol (MEG)

• Di-Ethylene Glycol (DEG)

• Tri-Ethylene Glycol (TEG)

The type of Glycol used and the package design depends on several factors, and the end-users specifi c requirements and objectives for the gas stream being processed.

Each package is typically designed in close consultation with the client to ensure the best overall design is achieved.

Design BasisDesign Basis

The design of TEG and MEG Dehydration Systems is unique for every requirement, and the overall package design will vary to meet the specifi ed moisture content of the gas at the process conditions.

Each system is typically designed and built as a complete turn-key package with particular emphasis given to the following issues:

• Discharge gas moisture content• High gas dehydration capacity• Minimum glycol losses• Minimum power consumption• Optimum plant effi ciency & design integrity• Compliance with HSE requirements• Environmentally conscientious design

Process DescriptionProcess Description

In a typical TEG package, water saturated gas enters near the bottom of the Contactor Tower and fl ows upwards through the internal trays/packing (1). Lean Glycol enters the Contactor Tower near the top and cascades down through the Contactor internals (9), making contact with the up-fl owing gas stream. The counter-current fl ow path of the Glycol and the high contact surface area absorbs water into the Glycol from the gas stream.

Rev 11-06

Gas Dehydration- Glycol A.01

Dehydrated gas fl ows out of the top of the Contactor, while the Rich Glycol fl ows out of the bottom of the Contactor and to the Glycol Regeneration Package.

The TEG Regeneration process typically involves passing the Rich Glycol through the still column to gain some heat (2) before entering the Flash Drum (3).

The Glycol is then passed through Particle Filters to remove particulates and Activated Carbon Filters to remove any dissolved hydrocarbon and/or chemical compounds (4). The Rich Glycol is heated in a cross exchanger to preheat the feed (5) to the Still Column where the Glycol present in the water vapour leaving the Reboiler is recovered (6).

Depending on the application, it may be necessary to increase the Lean Glycol concentration by using stripping gas (7), or running the Reboiler/Still Column under a slight vacuum. Lean TEG (typically >99wt%) is then cooled and pumped back to the top of the Contactor Tower (8) to repeat the process.

ReferencePackages Reference Packages

Santos Australia: Fairview Development Arrow Energy: Tipton West Field Development Origin Energy: Spring Gully Phase IIAnzon Australia: Basker Manta DevelopmentIOOC: Kharg Island Gas Project (Bahregansar)IOOC: Kharg Island Gas Project (Aboozar) CNOOC Indonesia: SES Gas Project

RelatedLiterature: Related Literature:

Other related brochures in this series:

A.03 Dew Point Control UnitsA.02 Molecular Sieve DehydrationA.04 Silica Gel DehydrationB.01 Amine Sweetening

A ‘typical’ Glycol Dehydration Package: a number of process components are added / modifi ed / removed to suit the requirements of each individual application

© Process Group Pty Ltd, 2006.

Process Group Intl Project Reference List

I:\Sales & Marketing\Latest Ref List.DOC

Client Project Description Year of Delivery

Payandan / NISOC Nargesi Associated Gas Gathering, Compression & Injection Project

Gas Dehydration Package ( USD 1.4 MM ) Under Execution

BHP Billiton Zamzama Phase 2 Development Amine CO2 Removal Package and Miscellaneous Equipment Items

2006

Anzon Australia Ltd. Basker Manta Field Development 35 MMSCFD TEG Dehydration Package for Crystal Ocean FPSO

2006

Iranian Offshore Oil Company Kharg Island Gas Gathering & NGL Recovery Project

Bahragansar 47 MMSCFD TEG Dehydration Package

2006

Iranian Offshore Oil Company Kharg Island Gas Gathering & NGL Recovery Project

Aboozar 66 MMSCFD TEG Dehydration Package 2006

CNOOC SES Gas Project 152 MMSCFD TEG Dehydration Package operating at 5,900 kPag, TEG circulation rate of 34 USGPM

2006

TXU Casan Project MEG Regeneration Package 2005

Shell Todd Pohokura Production Station TEG Regeneration and BTEX Recovery Package 2005

Origin Energy Spring Gully Development TEG Dehydration Package 2004

BHP Billiton (McConnell Dowell) Minerva Gas Plant Hydrocarbon Dew Point Control Plant MEG Regeneration Package Condensate Stabilisation Package Gas Metering Package Fuel Gas Conditioning Package

2004

NQGP Alliance North Queensland Gas Pipeline TEG Dehydration Package 2004




Esso (Worley) Longford Plant Upgrade MEG Regeneration Package 2003

Origin Energy (Clough) Bass Gas Development TEG Regeneration Package 2003

Sydney Gas Company Camden Gas Plant Development (Phase II)

TEG Dehydration Package 2003

Australian Gold Reagents Kwinana Refinery Ammonia Stripper Package 2002

OMV (Transfield/GHD) Patricia Baleen Field Development TEG Dehydration Package 2002

Japan Vietnam Petroleum Company (Worley)

Rang Dong Field Development - Vietnam

TEG Regeneration Package 2002

Cairn Energy Lakshmi Field Development - India 2 x TEG Regeneration Packages 2002

Swift Energy New Zealand Ltd Rimu Field Development - New Zealand

MEG Regeneration Package 2001

Cairn Energy (Clough) Ravva Satellite Development Project - India MEG Injection and Regeneration Package 2001

P.T. Titis Sampurna Gas Air Sedang Project – Berigin, Indonesia

Water/Hydrocarbon Dew Point Control Plant MEG Regeneration Package Propane Refrigeration Package LPG Production Package

2001

Santos Fenton Creek (Phase II) MEG Regeneration Package 2001

Chevron Petroleum Moran Petroleum Development Project - New Guinea

TEG Dehydration Package 2001




Sydney Gas Company Camden Gas Project (Phase I) TEG Dehydration Package Refurbishment 2001

BOC Gases Dandenong Cryocentre LNG Prepurification

Amine CO2 Removal Package Molecular Sieve Dehydration Plant

2001

IHI Bairnsdale Power Station Eastern Gas Pipeline

Fuel Gas Conditioning Package 2000

Oil Company of Australia Glycol Pumping Skid 2000

Premier Oil Anoa Gas Expansion Project – Natuna Sea, Indonesia

DEG Regeneration Package DEG Injection Package

2000

BP Queensland Clean Fuels Project Amine Package 2000

Santos Fenton Creek (Phase I) MEG Regeneration Package 1999

Australian Gas Fields / Energy Equity

Eromanga Gas Plant Amine CO2 Removal Water/Hydrocarbon Dewpoint Control MEG Injection and Regeneration Custody Transfer Metering Station

1999

Worley / Texas Utilities Australia Western Underground Gas Storage Project

2 x TEG Dehydration Packages 1999

Santos (Kvaerner Process) Ballera Gas Plant (Phase IV) MEG Injection and Regeneration Package (Duplicate order)

1998

Du Pont (Bechtel) Gladstone Sodium Cyanide Plant Upgrade

Amine CO2 Removal Molecular Sieve Dehydration De-methaniser Package

1997

Boral Energy Tubridgi Gas Facility Silica Gel Hydrocarbon Dew Point Control Plant 1997

DESCRIPTION

IRANIAN OFFSHORE OIL COMPANY

KHARG ISLAND GAS GATHERING &NGL RECOVERY PROJECT

GENERAL ARRANGEMENT DRAWINGBAHREGANSAR TEG DEHYDRATION SYSTEM

3D VIEWS

EPC CONTRACT FOR PLATFORM MODIFICATION AND OFFSHORE PLATFORMS

KHG2-VD-01-201-120- A1SCALE: 25:1 3179-82-2FG

PIDEC PROJECT NO: 1181

GPC PROJECT NO: G-1285

PETROCHEMICALINDUSTRIES DESIGN& ENGINEERING CO.

ERECTION& CONSTRUCTION& COMPANY

GULF PIPINGCONSTRUCTIONCOMPANY

PROCESS GROUP PTY LTD16 Kearney St

Bayswater 3153, Victoria, Australia

DISCIPLINE

DRAWING NO:

DRN.BY

CHKD.BY

APPD.BY

APPD.BY

DG BM BGINITIAL ISSUE 12/2/06

ISSUEDATE

DOC.STATUS

REV.

1

1REV.

PROJ.

PROJECT:

CONTRACTOR: CONSORTIUM OF PIDEC, GULF PIPING & ECC

Sheet 1 of 2

DESCRIPTION

IRANIAN OFFSHORE OIL COMPANY

KHARG ISLAND GAS GATHERING &NGL RECOVERY PROJECT

GENERAL ARRANGEMENT DRAWINGABOOZAR TEG DEHYDRATION SYSTEM

ELEVATIONS

EPC CONTRACT FOR PLATFORM MODIFICATION AND OFFSHORE PLATFORMS

KHG2-VD-01-201-120- A1SCALE: 25:1 3179-82-2FG

PIDEC PROJECT NO: 1181

GPC PROJECT NO: G-1285

PETROCHEMICALINDUSTRIES DESIGN& ENGINEERING CO.

ERECTION& CONSTRUCTION& COMPANY

GULF PIPINGCONSTRUCTIONCOMPANY

PROCESS GROUP PTY LTD16 Kearney St

Bayswater 3153, Victoria, Australia

DISCIPLINE

DRAWING NO:

DRN.BY

CHKD.BY

APPD.BY

APPD.BY

DG BM BGINITIAL ISSUE 12/2/06

ISSUEDATE

DOC.STATUS

REV.

1

1REV.

PROJ.

PROJECT:

CONTRACTOR: CONSORTIUM OF PIDEC, GULF PIPING & ECC

SHEET 2 OF 2

Documents

NMAGE GDU Tech Bid Rev 0 23rd July 08