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DESIGN AND ENGINEERING INFORMATION

DUNG QUAT REFINERY PROJECT PROJECT SPECIFICATION

DESCRIPTION OF PROCESS UNITS

SECTION II SUBSECTION 3.0 REV: D4 PAGE 1 OF 21

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REVISION O1 D1 D2 D3 D4 DATE Mar 00 May 00 Apr 30 04 July 30, 2004 Aug. 23, 04 ORIG. BY M Stockle A Creek H. Yoshimura H. Yoshimura H. Yoshimura APP. BY A Creek R. Spengler R. Spengler R. Spengler STATUS For FDC Review For FDC For FDC Pages modified under revision D2: all Pages modified under revision D3: 4, 5, 13, 14, 21 Pages modified under revision D4: 7 to 13

SECTION II SUBSECTION 3.0


CONTENTS

SUBSECTION SUBJECT 3.0 DESCRIPTION OF PROCESS UNITS 3.1 REFINERY CONFIGURATION 3.2 FEEDSTOCK COMPOSITION 3.3 PRODUCT SPECIFICATIONS 3.4 CRUDE DISTILLATION UNIT (UNIT 011) 3.5 NAPHTHA HYDROTREATER (UNIT 012) 3.6 CONTINUOUS CATALYTIC REFORMER (UNIT 013) 3.7 KEROSENE TREATER (UNIT 014) 3.8 RESIDUE FLUID CATALYTIC CRACKING (UNIT 015) 3.9 LPG TREATER (UNIT 016) 3.10 RFCC NAPHTHA TREATER (UNIT 017) 3.11 SOUR WATER TREATER (UNIT 018) 3.12 AMINE REGENERATION UNIT (UNIT 019) 3.13 SPENT CAUSTIC NEUTRALISATION UNIT (UNIT 020)

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3.14 PROPYLENE RECOVERY UNIT (UNIT 021) 3.15 SULPHUR RECOVERY UNIT (UNIT 022) 3.16 LIGHT NAPHTA ISOMERIZATION UNIT (UNIT 023) 3.17 LCO HYDROTREATER (UNIT 024) ATTACHMENTS 1. CRUDE ASSAYS





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3.0 DESCRIPTION OF PROCESS UNITS 3.1 Refinery Configuration The units included within the refinery configuration are;

• Crude Distillation Unit • Naphtha Hydrotreater • Light Naphtha Isomerization Unit • Continuous Catalytic Reformer • Kerosene Treating Unit • Residue Fluidised Catalytic Cracker • LCO Hydrotreater • RFCC Naphtha Treating Unit • LPG Treating Unit • Propylene Recovery Unit • Amine Regeneration Unit • Sour Water Stripper • Caustic Neutralisation Unit • Sulphur Recovery Unit

The refinery is designed to produce the following products;

• Domestic LPG • Polymer Grade Propylene • 90 RON Domestic Gasoline • 92 RON Domestic Gasoline • 95 RON Domestic Gasoline • Burning Grade Kerosene • Jet A1 • Auto Diesel • Fuel Oil

The refinery will also have it’s own utility and power production systems. Crude feedstock will be unloaded via a single point mooring and stored in the crude tank farm. Some intermediate refinery tankage is provided within the refinery fence, however, finished products are stored in a separate product tank farm. Product loading facilities will be provided for both Ocean and Coastal ships. Truck loading will also be provided for supply local to the refinery.

A block flow diagram showing the refinery configuration (6960-000-20-0001) is included in Section V, Subsection 1.0.





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3.2 Feedstock Composition

The refinery is designed to operate on two feedstocks, with a exception of installing DeSOx Unit in RFCC and Sulphur Recovery Unit for Sour Case.

• 6.5 Million Tonnes per Annum of Bach Ho Crude (Sweet Case)

• 5.5 Million Tonnes per Annum of Bach Ho and 1 Million tonnes per annum of Dubai crude (Sour Case)

The Bach Ho and Dubai crude assays are included in Attachment 1. For the Bach Ho assay a number of corrections and amendments have been issued. These are summarised in an addendum to the original assay. Data supplied in the addendum supersedes any data provided in the original assay.

3.3 Product Specifications

The following sections contain the product specifications for the refinery products

Specifications are given for the following products;

• Domestic LPG • Export LPG • Polymer Grade Propylene • 90 RON Domestic Gasoline • 92 RON Domestic Gasoline • 95 RON Domestic Gasoline • Jet A1 • Burning Grade Kerosene • Auto Diesel (2001, future) • Fuel Oil

The normal refinery operating slate will not include the production of export products, however, the specifications are provided for LPG and 92 RON Gasoline for information purposes. For Auto Diesel a future specification is provided. This is the likely future specification based on typical trends in product specification around the world and is provided for information only.





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3.3.1 LPG

The specification for mixed LPG is included below.

Test Method

DOMESTIC EXPORT

SG 15oC/4oC, (min.)

ASTM D1657or D2598

0.5 0.545

Vapour Pressure,kPa @38 0C ASTM D1267

480-820 380-830

Composition ASTM D2163

- -

Ethane, (mol %) 3 -

C3s + C4s - 97.0 vol. %

C3s, (mol %) 20-50 44.0 vol. %

C4s, (mol %) 50-80 53.0 vol. %

C5+ (mol %) (max.) 1.5 1.5 vol %

Cu Corrosion 1hr @38 oC (max.)

ASTM D1838

1 1

Free Water % Vol Nil Nil

Calorific Value MJ/kg ASTM D3588

40-55 -

Total Sulphur, ppm wt, (max.)

ASTM D2784 or D4045

170 100

Volatility (95% evaporated @ oC) (max.)

ASTM D1837

- 2.2

Olefins % vol (max.) - 20

Mercaptans, ppm (max.) ASTM D6228 20 20

H2S, ppm (max.) ASTM D4048 0.5 0.5





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3.3.2 Propylene

The specification for polymer grade propylene is included below.

Test Method Polymer Grade Propylene, wt % ASTM D2712 99.6 min Total paraffins mol% ASTM D2712 0.4 max Methane ppm wt ASTM D2712 20 max Ehtylene ppm wt ASTM D2712 25 max Ethane ppm wt ASTM D2712 300 max Acetylene, Methyl Acetylene, Propadiene ppm wt

ASTM D2712 5 max (Note 1)

C4 + ppm wt ASTM D2650 50 max Hydrogen ppm wt ASTM D2504 20 max Nitrogen ppm wt ASTM D2504 100 max Carbon monoxide ppm wt ASTM D2504 0.33 max Carbon dioxide ppm wt ASTM D2504 1 max Ammonia ppm wt UOP-430-70T 5 max Oxygen ppm wt Oxygen Analyzer 1 max Water ppm wt Moisture Analyzer saturated Oxygenates ppm wt UOP-496-60T 15 max Chlorides ppm wt ASTM D2384 1 max Total Sulphur ppm wt ASTM D4468 1 max Carbonyl Sulphide ppm wt ASTM D6228 2 max Arsine ppm wt UOP-834-82 0.03 max Phosphine ppm wt Note 2 0.03 max Antimony ppm wt Note 2 0.03 max

Note 1: Combined acetylene, methylacetylene and propadiene content 5 ppm wt max Note 2: To be provided during Detailed Engineering

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3.3.3 Domestic Gasoline

The Specifications for 90 RON, 92 RON and 95 RON Domestic Gasoline are included below.

Test Method

90 RON 92 RON 95 RON

Octane No MON ASTM

D2700 81 83 85

RON ASTM D2699

90 92 95

SG @ 15oC/15oC ASTM D1298

0.72 - 0.76

Lead,g/l, (max.) ASTM D3237

Zero (0.01)

Distillation, oC ASTM D86 IBP, (min.) 40 50%, (max.) 120 90% 190 FBP, (max.) 215 Residue, % Vol 1.5 Cu Corrosion 3hrs @ 50oC

ASTM D130 1a

Existent Gum, mg/100ml, (max.)

ASTM D381 4.0

RVP, kPa @ 37,8 oC ASTM D323 60 summer 75 winter

Total Sulphur, % wt, ppm (max.)

ASTM D1266 or D4294

0.05

Oxidation Stability-minutes (min.)

ASTM D525 480

Aromatics, Vol %, (max.)

ASTM D1319

50

Benzene, Vol %, (max.)

ASTM D1319

5

Olefins, Vol %, (max.) ASTM D1319

45





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3.3.4 Export Gasoline

The specification for Export Gasoline is included below..

Test Method Export Gasoline Octane No MON ASTM D2700 83 RON ASTM D2699 92 SG @ 15oC/15oC ASTM D1298 0.72-.76 Lead,g/l, (max.) ASTM D3237 Zero (0.01) Distillation, oC ASTM D86 IBP, (min.) 40 50%, (max.) 120 90% FBP, (max.) 205 Residue, % Vol 1.5 Cu Corrosion 3hrs @ 50oC ASTM D130 1a Existent Gum, mg/100ml, (max.)

ASTM D381 4.0

RVP, kPa @ 37,8 oC ASTM D323 60 summer 75 winter

Total Sulphur, % wt, ppm (max.)

ASTM D1266 or D4294

200

Oxidation Stability-minutes (min.)

ASTM D525 480

Aromatics, Vol %, (max.) ASTM D1319 35 Benzene, Vol %, (max.) ASTM D1319 2 Olefins, Vol %, (max.) ASTM D1319 20





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3.3.5 Jet A1

The specification for Jet A1 Kerosene is included below..

Test Method Jet A1 Specific Gravity @ 15 oC/15oC ASTM D1298 0.775-0.84 Distillation @ 101 kPa ASTM D86 IBP Report 10%, (max.) 204 20% 50% 90% FBP (max.) 300

Viscosity @ -20 oC (cSt) (max.) ASTM D445 8.0 Smoke Point, mm, (min.) ASTM D1322 25 Note 1

Flash Point, oC, (min) ASTM D93 or D56 38 Sulphur, % wt (max.) ASTM D1266 or D4294 0.3

Doctor Test or ASTM D235 Negative Sulphur Mercaptan % wt, (max.) ASTM D3227 0.002

Cu Corrosion 3h @ 100 oC ASTM D130 1

Ag Corrosion 4h @ 50 oC IP 227 2 Acidity, mg KOH/g (max.) ASTM D3242 0.015 Existent gum, mg/100ml, (max.) ASTM D381 7

Freeze Point, oC (max.) ASTM D2386 -47 Specific energy, KJ/kg (min.) ASTM D3338 42800

Thermal Stability (260 oC) mmHg (max.) ASTM D3241 25.0 Water reaction Interface ASTM D1094 1b Ash % wt. (max.) ASTM D482 0.003 Water Separation (min.) ASTM D3948 85 Aromatics % vol., (max.) ASTM D1319 22 Olefins % vol., (max.) ASTM D1319 5.0 Saybolt Colour (min.) ASTM D156 +25

Note 1: Or 20 min. smoke point and 3% max. naphthalenes





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3.3.6 Burning Grade Kerosene

The specification for Burning Grade Kerosene is included below.

Test Method Domestic

Saybolt Colour, (min). ASTM D156 +20

Acidity, mg KOH/g (max.) ASTM D 3242 0.02

Sulphur, % wt,(max.) ASTM D1266 or D4294

0.1

Distillation ASTM D86

IBP, (min.) 144

50%, (max.) 200

FBP, (max.) 277

Flash Point, oC, (min.) ASTM D93 40

Existent gum, mg/100ml, (max.)

ASTM D381 1

Viscosity @ 40 oC cSt ASTM D445 1.0 - 1.9

Smoke Point mm, (min.) ASTM D1322 20

S.G. @ 15 oC/15 oC,(max.) ASTM D 1298 0.83

Cu Corrosion, 2h @ 100 oC ASTM D130 1a





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3.3.7 Auto Diesel

The main grade of diesel produced by the refinery will be Auto diesel. Production of this Auto Diesel will be aimed mainly at the domestic market, but some export may take place.

Test

Method Domestic for year 2001

(*)

Future Market Requirements

Cetane Index, (min.) ASTM D4737

45 48

Distillation, oC ASTM D86

50% vol., (max.) 290 290

90% vol., (max.) 370 357

Viscosity @ 40 oC cSt ASTM D445

1.8-5.0 1.8-5.0

Flash point, oC, (min.) ASTM D93

65 65

Pour Point, oC ASTM D97

Winter, (max.) 0 0

Summer, (max.) +5 +5

Ash, wt. %, (max.) ASTM D482

0.01 0.01

Water, % vol ASTM D95

Nil Nil

Colour, (max.) ASTM D1500

2.0 2.0

Oxidation Stability, mg/l, (max.)

ASTM D2274

25 25

Existent Gum, mg/100ml, (max.)

ASTM D381

50 50

Total Sulphur, % wt, (max.)

ASTM D1266 or D4294

0.3 0.05

Cu Corrosion, 3hr @ 50 oC, (max.)

ASTM D130

1 1

S.G @20oC/20oC, (max)

ASTM D4052

0.86 0.84

(*) Design Basis is 2001 spec.





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3.3.8 Industrial Diesel

Deleted.





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3.3.9 Fuel Oil

The specification for fuel oil is included below.

Test Method

Domestic for year 2001

S.G. @ 15 oC/15 oC, (max.)

ASTM D1298

0.96

Viscosity @ 50 oC cSt, (max.)

ASTM D445

160

Sulphur Content wt. %, (max.)

ASTM D129

2.0

Flash Point oC, (min.)

ASTM D93

66

Pour Point oC, (max.)

ASTM D97

+21

Sediment & Water vol.%, (max)

ASTM D1796

1

Water Content vol. %, (max.)

ASTM D95

0.5

Heat of Combustion Kcal/kg, (min.)

ASTM D240

9,800 *

Vanadium, ppm (max.) ASTM D5863

200

Sodium, ppm (max.) ASTM D5863

100

* Expected Figure





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3.4 Crude Distillation Unit (Unit 011) 3.4.1 General Description

Crude enters the Crude Distillation Unit (CDU) and is preheated against product and pumparound streams prior to entering a fired heater. The crude is split into a number of products in a main fractionator and associated side stream strippers. Overhead Naphtha is further processed in a stabiliser.

The CDU products are:

Product Destination Full Range Naphtha Naphtha Hydrotreater Kerosene Kerosene Treater Unit Light Gas Oil Refinery Tankage Heavy Gas Oil Refinery Tankage Atmospheric Residue RFCC

Light ends from the CDU are sent via the RFCC gas plant to the LPG Treater Unit (LTU). Full Range Naphtha from the CDU is fed to the Naphtha Hydrotreater Unit (NHT) where the naphtha is heated and the naphtha vapour is contacted with a fixed bed of catalyst before being sent to the Continuous Catalytic Reformer Unit (CCR).

Kerosene from the CDU is sent to the Kerosene Treater Unit (KTU) and routed directly to Kerosene tankage or it is once stored in the Refinery tankage and is used as a blend stock for diesel and fuel oil production. In the KTU the levels of mercaptan, hydrogen sulphide and naphthenic acids are reduced, and water is removed. The treated kerosene is then sent to tankage where it is used for Jet A1 and burning grade kerosene. Light gas oil from the CDU is once stored in the Refinery Tankage and pumped directly to the Diesel blenders and from there to tankage at the Product Tank Farm. A part of light gas oil is sent to LCO Hydrotreater (LCOHDT) as required.

Heavy gas oil is pumped to tankage at the Refinery, from which it is pumped to the Diesel/Fuel Oil blenders. A part of heavy gas oil is sent to LCOHDT as required.

Residue from the CDU flows to RFCC where it is upgraded into higher value intermediate products.





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3.5 Naphtha Hydrotreater (Unit 012) 3.5.1 General Description

The Naphtha Hydrotreater Unit is required to process the Full Range Naphtha stream from the Crude Distillation Unit (CDU).

A single fixed bed catalyst reactor is employed and the catalyst regeneration cycle life is a minimum of 2 years. Facilities shall be provided to regenerate catalyst in-situ.

Naphtha product from NHT is sent to Naphtha Splitter and light naphthas is routed to Light Naphtha Isomerization Unit (ISOM), while heavy naphtha being routed directly to the Continuous Catalytic Reforming Unit (CCR).

Off-gas from the NHT shall be routed to the RFCC Gas Plant for processing through the fuel gas amine absorber.

3.6 Continuous Catalytic Reformer (Unit 013) 3.6.1 General Description

The Continuous Catalytic Reformer processes hydrotreated straight run heavy naphtha feedstock from the NHT Naphtha Splitter.

The reactor feed contacts with a recirculating catalyst, which is continuously regenerated to maintain activity.

Reactor effluent is separated into a hydrocarbon liquid stream and a hydrogen rich gas stream.

Valuable hydrocarbon liquids are recovered from the hydrogen rich gas stream.

The Reformate liquid stream undergoes re-contacting and fractionation to produce Reformate and un-stabilised LPG. The Reformate is routed directly to tankage at the Refinery. The un-stabilised LPG is blended with other refinery LPG streams before being routed to storage at the Product Tank Farm.

3.7 Kerosene Treater (Unit 014) 3.7.1 General Description

The Kerosene Treater Unit is designed to process the Kerosene cut from the Crude Distillation Unit.





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The Kerosene Treatment Unit is designed to reduce mercaptan levels, hydrogen sulphide and naphthenic acids, from the straight run kerosene feedstock produced in the CDU.

Fresh caustic for the unit is provided at the desired concentration from off plot facilities.

The Kerosene Treatment Unit removes all water from the product. The required product specification is achieved in one stage of extraction.

Product from the Kerosene Treater is routed to tankage at Product Tank Farm, from tankage it is either sold as Jet A1 or burning grade kerosene. A part of treated kerosene is once stored in the Refinery tankage and used as a blend stock for Diesel and Fuel Oil. The Kerosene Treater produces kerosene capable of meeting the Jet A1 specification.

A weak amine solution (MEA) will be used on the KTU on an infrequent batch basis for regeneration of the catalyst.

3.8 Residue Fluid Catalytic Cracking (Unit 015) 3.8.1 General Description

Convertor Section

The Unit receives hot atmospheric residue directly from the Crude Distillation Unit (CDU), or cold from tankage.

The Convertor Section of the RFCC shall produce the following streams:-

• A wet gas stream which is routed to the RFCC Gas Plant

• An overhead distillate which is routed to the RFCC Gas Plant

• A light cycle oil (LCO) which is routed to tankage and then to LCO Hydrotreater (LCOHDT).

• A decant oil (DCO) which is routed to fuel oil blending or to refinery fuel oil.

The Converter Section comprises the reactor/regenerator section, main fractionator, waste heat boiler, catalyst handling, LCO stripper, product cooling/rundown equipment and associated facilities.

RFCC Gas Plant

The wet gas and overhead distillate from the main fractionator are charged to the RFCC Gas Plant, which shall produce the following streams:

• An unsaturated off-gas from the amine absorber located within the RFCC Gas Plant.





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• A mixed C3/C4 stream which is routed to the LPG Treater Unit prior to separation within the Propylene Recovery Unit.

• A whole naphtha stream which is routed to the RFCC Naphtha Treater Unit;

The RFCC Gas Plant includes two amine absorption columns to treat fuel gas and LPG prior to them leaving the Unit and will use a stream of lean amine from the Amine Regeneration Unit (ARU). The rich amine stream shall be returned to the ARU from the RFCC Gas Plant.

3.9 LPG Treater (Unit 016) 3.9.1 General Description

The LPG Treater Unit (LTU) is designed to process the C3/C4 stream from the RFCC Gas Plant prior to routing to the Propylene Recovery Unit. The bulk of the H2S in the LPG stream is removed in an amine absorber, located in the RFCC Gas Plant.

The LTU is designed to reduce mercaptan and H2S levels in the C3/C4 product, when charged with design feedstock.

3.10 RFCC Naphtha Treater (Unit 017) 3.10.1 General Description

The Naphtha Treater Unit (NTU) is designed to process the RFCC Naphtha from the RFCC.

The unit is designed to produce a sweet (i.e. low mercaptan sulphur) naphtha product.

Product from the NTU is once stored in the Refinery tankage and routed to the Mogas blenders.

Fresh caustic at the desired concentrations is supplied to the unit for use in the treaters. Spent caustic from the treaters is routed to the Spent Caustic Neutralisation Unit (CNU).

3.11 Sour Water Treater (Unit 018) 3.11.1 General Description

Sour water from the CDU, NHT, RFCC and LCOHDT units is fed to a surge drum where hydrocarbons are degassed. These sour gases are routed to the sour flare header.

Combined sour water is pumped via feed / bottoms heat exchanger to a single stripping column where dissolved ammonia and hydrogen sulphide are removed from the sour water.





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Sour gas overhead from the stripper column is directed to Sulphur Recovery unit (SRU).

Stripped water is cooled against incoming feed and air prior to routing to the effluent treatment plant. A slipstream of stripped water is used as desalter water on the CDU.

A sour water storage tank is provided to allow for outages on the unit. The tank is sized to give two days storage of sour water. Under normal operation the tank will be by passed and so will be normally empty.

3.12 Amine Regeneration Unit (Unit 019) 3.12.1 General Description

Combined rich amine from the RFCC and LCOHDT units is routed to a feed surge drum where hydrocarbons are skimmed and degassed from the amine. Skimmed oil is routed to light slops and sour gases are scrubbed and routed to fuel gas.

Rich amine is routed via feed / bottoms heat exchange to a regeneration column where hydrogen sulphide is stripped.

Sour gas overheads from the column are condensed and refluxed, and the residual concentrated sour gas is directed to SRU.

Stripped lean amine is cooled against incoming feed and air. The lean amine is then pumped and treated with anti-foam agent (if required) back to the H2S absorbers on the RFCC and LCOHDT. A slipstream of amine is filtered to remove impurities.

An amine surge tank is available to hold the total refinery amine inventory in the event of a shutdown. Fresh amine is stored in a small make-up tank for preparation of initial and make-up solutions.

3.13 Spent Caustic Neutralisation Unit (Unit 020) 3.13.1 General Description

The Spent Caustic Neutralisation Unit is required to neutralise and remove phenolic and naphthenic oils from various spent caustic streams.

The spent caustic is degassed and then neutralised by treating with sulphuric acid. The neutralised brine is routed to the effluent treatment plant. The Sour Gas produced from the unit is routed to Incinerator unit on SRU.

Flows to the unit are on both a batch and continuous basis.





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The unit is designed to produce neutralised brine with a pH of between 6-8, when charged with design feedstock.

Fresh sulphuric acid is supplied to a storage tank within the battery limits of the unit.

3.14 Propylene Recovery Unit (Unit 021) 3.14.1 General Description

The PRU is designed to process the mixed C3/C4 stream from the LPG treatment unit. The PRU will separate and purify propylene to polymer grade (99.6wt%) specification. The first stage in the process is a C3/C4 splitter, which removes C4’s from the LPG. The main propane/propylene splitting facility normally has two stages. The first of these is a de-ethanising stage, which releases products lighter than Propylene. The second stage is the Propane/Propylene

splitting column, which is a low-pressure heat pumped column. The propylene product from the propane/propylene splitter undergoes further purification. The first stage would be secondary carbonyl sulphide removal over a dry catalyst bed. The second purification stage normally consists of removal of arsenic, phosphorous and antimony, again over a dry catalyst bed. The purification stages are combined in a single vessel.





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3.15 Sulphur Recovery Unit (Unit 022)

3.15.1 General Description

The SRU is designed to process acid gas from ARU for Sweet Case, while ammonia acid gas from SWS and off-gas from CNU are directly routed to and burnt in the incinerator on SRU. Product sulphur is solidified on a concrete apron and solid sulphur is transferred by a truck after breaking up with front-end loader.

3.16 Light Naphtha Isomerization Unit (Unit 023) 3.16.1 General Description

Light Naphtha from the upstream Naphtha Splitter is charged to the feed dryers and then to the charge surge drum. The recycled liquid stream from the deisohexanizer (DIH) is a side-draw stream that is pumped from the DIH column and also routed through the dryers, prior to being mixed with the fresh feed. The Hydrogen make-up gas flows to a methanator to remove trace levels of CO and then onto the gas dryers, similar to those on the liquid feedstock, prior to being mixed with the combined feed from the charge surge drum. The combined feed is heated through exchange against reactor effluent and a steam charge heater. Chloride is injected into the stream and then sent to the reactors. The combined feedstock reacts to form a higher octane reactor effluent steam. The effluent from lead reactor is cooled via exchange with the combined feed to lowe the temperature of the stream prior to being charged to the inlet of the second reactor. The high octane reactor effluent from the lag reactor is heat exchanged with the combined feed and pressured directly to the product stabilizer column. The overhead vapor product from the stabilizer receiver flows to the caustic scrubber column to remove hydrogen chloride before flowing to the fuel gas system. The stabilized and isomerised liquid product from the bottom of the stabilizer column passes to the DIH column. The DIH column fractionates the stabilizer bottoms material into three streams. The overhead stream is primarily composed of pentanes and high octane dimethylbutanes. The side-cut stream recovers most of the n-hexane, methyl pentanes and some of the C6 naphthenes, and is returned to the dryers as a recycle stream for further octane upgrading. The DIH bottoms product consists primarily of the C7+ compounds and some of the C6 naphthenes. DIH overhead and bottoms products are combined and routed to the Refinery tankage as mogas blending stock.





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3.17 LCO Hydrotreater (Unit 024) 3.17.1 General Description

Untreated LCO from RFCC is pumped and mixed with the recycle gas coming from the recycle compressor and also with the make up gas coming from the make up compressor. The mixture is preheated by the reactor effluent in the feed/effluent exchangers and brought to reaction temperature by the reactor heater. The hydrogenation reactions occur in a fixed bed catalyst reactor to get stable products for use as auto-diesel blend stock. Reactor effluent is cooled down first in the stripper feed preheater then in the feed/effluent exchangers. At the outlet of the heat recovery system, water is injected in order to avoid any salt deposition. The effluent is cooled down in an air cooler followed by a trim cooler before entering the separator drum. The aqueous phase is sent to SWS, while the liquid phase is sent to the stripper column. The gas phase is returned to the recycle KO-drum and to the recycle compressor. The liquid phase of the separator drum is preheated against the stripper bottom and against the reactor effluent. The overhead is partially condensed in air condenser followed by a trim cooler. The overhead liquid product is sent to RFCC as wild naphtha. The decanted water is collected in a boot and used as washing water make-up. The sour gas is sent to off-gas amine absorber to remove H2S and routed to the fuel gas system. The stripper bottom is cooled down in the feed/bottom exchanger, and then it passes through a coalescer and is sent to a vacuum dryer in order to get rid of the dissolved water. Hydrotreated LCO product is routed to the Refinery tankage and used as Auto-diesel blend stock.

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