S-000-1222-001 Bedd

JOB No.

Sohar Refinery Company SOHAR Refinery Project

CONTRACTOR DOC. No.

0-3100-25 DATE 14 −

PROJECT SPECIFICATION

REV.

S-000-1222-001

MAR

−

PREP’D

M.Saito

CHK’D

M.Tabuse

APP’D

A.Kato

2003

1

SHEET

R OF

30

BASIC ENGINEERING DESIGN DATA

FOR CONSTRUCTION

SOHAR REFINERY COMPANY L. L. C.

SOHAR REFINERY PROJECT

SOHAR, SULTANATE OF OMAN

REV.

DATE

PAGE

0

14 Mar 2003

All

1

15 May 2003

All

R

18 Aug 2003

Reference ITT Doc. No.

Rev

S-000-1222-001

D

PREP’D

CHK’D

APP’D

Issue for Preliminary Quotation

M.S

M.T

A.K

Issue for Approval

M.S

M.T

A.K

M.S

M.T

A.K

DESCRIPTION

4, 6, 8, 10, 14, Issue for Construction ( As per OM-JY-E-20150, 25, 26, 28, 29 JY-OM-E-20105 and JY-OY-E-20116)

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JOB CODE: 0-3100-25 DOC NO: S-000-1222-001 rev. R

Basic Engineering Design Data

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CONTENTS 1

GENERAL..................................................................................................................................................... 4 1.1 1.2

Common information.............................................................................................................................. 4 System of Measurement.......................................................................................................................... 5

SECTION A. 2

UTILITY CONDITIONS (STEAM) ........................................................................................................... 6 2.1 2.2

3

PROCESS AREA HEADER CONDITION ........................................................................................... 6 Condensate Recovery System................................................................................................................. 7

UTILITY (ELECTRIC POWER) ............................................................................................................... 8 3.1 3.2 3.3

4

BASIC ENGINEERING DESIGN DATA.............................................................................. 6

Distribution ............................................................................................................................................. 8 User Rating ............................................................................................................................................. 8 Emergency Power source........................................................................................................................ 8

UTILITY (WATER) ..................................................................................................................................... 9 4.1 4.2 4.3 4.4

Water ...................................................................................................................................................... 9 Treated Water ....................................................................................................................................... 10 Treated WASTEWATER quality ......................................................................................................... 11 Reused Wastewater Quality (Complying with MD 145/93).................................................................. 11

5

UTILITY (FUEL) ....................................................................................................................................... 12

6

UTILITY (AIR & NITROGEN GAS)....................................................................................................... 13 6.1

7

UTILITY UNIT PRICES FOR ECONOMIC STUDY............................................................................ 14 7.1 7.2

8

Basis of the estimation.......................................................................................................................... 14 Unit Prices of Utilities .......................................................................................................................... 14

CLIMATE CONDITIONS ......................................................................................................................... 15 8.1 8.2 8.3 8.4 8.5 8.6

9

Process Area Header Condition ............................................................................................................ 13

Direction & Pressure of Wind .............................................................................................................. 15 Temperature.......................................................................................................................................... 15 RAINFALL (Data source: Master Plan)......................................................................................... 16 Earthquake ............................................................................................................................................ 16 Atmospheric pressure (Data source: Sohar Port EIA) ....................................................................... 16 Environmental Conditions .................................................................................................................... 16

SITE CONDITIONS................................................................................................................................... 16 9.1 9.2 9.3

Soil Conditions ..................................................................................................................................... 16 Site Elevation (Basic Ground Level) .................................................................................................... 16 Bench Mark (B.M)................................................................................................................................ 17

10

ENVIRONMENTAL REQUIREMENT FOR AIR QUALITY (SOURCE EMISSION)..................... 17

11

ENVIRONMENTAL REQUIREMENT FOR NOISE ............................................................................... 17 11.1 11.2 11.3

Environmental Noise Limit ................................................................................................................... 17 Absolute Noise Limit............................................................................................................................. 17 General Work Area Noise Limit ........................................................................................................... 17

SECTION B. 12

PROCESS DESIGN PHILOSOPHY AND INFORMATION ................................................................ 18 12.1 12.2 12.3 12.4 12.5

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BASIC DESIGN PHILOSOPHY........................................................................................... 18

Unit turndown....................................................................................................................................... 18 Heat Recovery ...................................................................................................................................... 18 Design Margin ...................................................................................................................................... 18 Design Pressure .................................................................................................................................... 18 Design Temperature.............................................................................................................................. 18

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Sohar Refinery Company SOHAR Refinery Project Basic Engineering Design Data

12.6 12.7 12.8 12.9 13

Steam Purge Condition ......................................................................................................................... 19 Aromatics Handling.............................................................................................................................. 19 Standard Corrosion allowance .............................................................................................................. 19 Vacuum design ..................................................................................................................................... 19 Vessels .................................................................................................................................................. 20 Tray & Packing..................................................................................................................................... 21 Tanks .................................................................................................................................................... 22 Shell & tube heat exchangers................................................................................................................ 22 Air cooled heat exchangers................................................................................................................... 23 Heaters (excluding Reformer) .............................................................................................................. 23 Pumps ................................................................................................................................................... 24 Compressors ......................................................................................................................................... 25 Temperature instrument........................................................................................................................ 25 Level instrument ................................................................................................................................... 26 Pressure Instrument .............................................................................................................................. 26 Control Valve........................................................................................................................................ 27 Pressure relief valves (PRV) and Flare Load........................................................................................ 27 Plant Life .............................................................................................................................................. 27 Basis for Material Selection.................................................................................................................. 27 Reference .............................................................................................................................................. 29

BURNER MANAGEMENT SYSTEM REQUIREMENTS.................................................................... 29 16.1 16.2 16.3 16.4

17

30

MATERIAL SELECTION PHILOSOPHY ............................................................................................. 27 15.1 15.2 15.3

16

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INSTRUMENT DESIGN PHILOSOPHY & INFORMATION ............................................................. 25 14.1 14.2 14.3 14.4 14.5

15

SHEET : 3

EQUIPMENT DESIGN PHILOSOPHY & INFORMATION ............................................................... 20 13.1 13.2 13.3 13.4 13.5 13.6 13.7 13.8

14

JOB CODE: 0-3100-25 DOC NO: S-000-1222-001 rev. R

High High or Low Low Pressure of Main Fuel Gas ............................................................................. 29 Low Low Pressure of Pilot Natural Gas ............................................................................................... 29 High High Level of Fuel Gas K.O. Drum............................................................................................. 29 High High Pressure of Fire Box ........................................................................................................... 29

OTHER INFORMATION.......................................................................................................................... 29 17.1 17.2

Battery Limit requirements ................................................................................................................... 29 Interface Conditions with OPP and Other Third Parties ..................................................................... 30

Note : The changed portions from ITT BEDD, “S-000-1222-001” rev D, are marked by Italic letters.

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Sohar Refinery Company SOHAR Refinery Project

JOB CODE: 0-3100-25 DOC NO: S-000-1222-001 rev. R

Basic Engineering Design Data

1

GENERAL

1.1

Common information (1)

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Owner's Name and Location and Project Name The full names and abbreviations are as follows : (The latter are shown in [ ].)

(2)

(a)

Owner's Name

(b)

Location

(c)

Project Name

Sohar Refinery Company L.L.C [ SRC ] Sohar, Sultanate of Oman [ SOHAR ] Sohar Refinery Project [ SOHAR PJ ]

Related Documents (a) (b) (c) (d) (e) (f)

Numbering Procedure : Numbering System for Equipment, Instrument Piping, Electrical and Building; S-000-1140-102 Design Criteria for Piping & Instrument Diagrams and Utility Flow Diagrams; S-000-1225-001 Procedure for PFD & MSD Development; S-000-1225-002 Procedure for Hydraulic Check, S-000-1225-003 Review Procedure for Pressure Relief Valve, S-000-1225-004 Design Basis of process unit ; S-XXX-1223-001 (XXX: Facility Code)

General Notes

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(a)

The items or figures specified in Section A (Basic Engineering Design Data) in this BEDD supersede UOP BEDQ or other licensors’ basic engineering design data. The basic design philosophy specified by each licensor shall be followed in accordance with each licensor’s Basic Design Package.

(b)

Any figures different from UOP BEDQ are highlighted in bold characters.

(c)

The reference number of H-XXXX or “Category-1, Item X.X”, which are shown in this document, should be used only for Owner’s reference indication.

(d)

For information note that fuel data, emission limitations, process design flow rate margin, turndown, design pressure and temperature criteria, stack height, etc., all defined in this document need to be separately related to the Fired Heaters in a document such as Requisition. Refer to Category 1, Item 7.4.

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Sohar Refinery Company SOHAR Refinery Project

JOB CODE: 0-3100-25 DOC NO: S-000-1222-001 rev. R

Basic Engineering Design Data

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System of Measurement Engineering Design Specifications will be issued in the following system of measurement, with the exception of piping sizes, pipe classes. Language Temperature

English °C

Pressure (gauge)

bar(g)

Pressure (absolute)

bar(a)

Mass

kg

Volume

m³

Length

m, mm

Liquid Relative Density Liquid Absolute Density

SpGr T°C/15°C kg/m3 at 15°C

Vapor Flowing Density

kg/m³

Flowing Quantities Mass

kg/h

Vapor

m³/h

Liquid

m³/h

Standard Quantities Vapor Liquid

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normal m3/h at 0°C and 1.013 bar(a) std m3/h at 15°C and 1.013 bar(a)

Enthalpy

kcal/kg

Heat Rate

MM kcal/h

Viscosity

cP

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Sohar Refinery Company SOHAR Refinery Project

JOB CODE: 0-3100-25 DOC NO: S-000-1222-001 rev. R

Basic Engineering Design Data

SECTION A.

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BASIC ENGINEERING DESIGN DATA

The purpose of this section is to define the conditions relating to the basic design for the Sohar Refinery Project. 2

UTILITY CONDITIONS (STEAM)

2.1

PROCESS AREA HEADER CONDITION

Service

Min.

Pressure Nor.

HP

41.2

42.3

MP

18.0

LP LLP Remarks:

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(

Barg Max.

)

Temperature (°C) Nor. Max. Mecha. Design 385 420 400

Min.

42.5

Mecha. Design 49.3/FV

21.0

23.0

28.0/FV

280

320

350

400

9.5

10.6

10.8

14.0/FV

180

220

220

395

3.1

3.5

3.6

5.5/FV

144

180

180

270

350

Classification of Nor, Max. and Min. conditions.

(1)

Nor :

The average or typical steam pressure and temperature expected in the process area header during normal operation.

(2)

Min.:

The lowest steam pressure and temperature expected in the process area header during normal operation.

(3)

Max.:

The highest steam pressure and temperature expected in the process area header during normal (non-relieving) operation.

(4)

A) Heat exchangers in steam (consumption) services need to be designed assuming minimum operating conditions in headers. B) Heat exchangers (steam generators) in steam production services need to be designed assuming maximum operating conditions in headers. Refer to Category 1 Item 9.67.

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Sohar Refinery Company SOHAR Refinery Project

JOB CODE: 0-3100-25 DOC NO: S-000-1222-001 rev. R

Basic Engineering Design Data

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Condensate Recovery System Service

Pressure ( barg ) Ope Mech. Design

Temperature ( °C ) Ope Mech. Design

Note (3)

Suspect

NOTE

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2.0 (note 1)

5.5

Cold Condensate

4.5 (note 1)

10.0

Hot Clean Condensate

2.0 (note 1)

5.5

(1) (2) (3)

Condensate

Sat. (133 oC at 2.0 barg) 50

(note 2)

Sat. (133 oC at 2.0 barg)

(note 2)

150

Up to Header Header

120

150

Up to Header Header

At process unit Battery Limit at grade Maximum temperature at steam user inlet Cancelled. Refer to H-0222

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Sohar Refinery Company SOHAR Refinery Project

JOB CODE: 0-3100-25 DOC NO: S-000-1222-001 rev. R

Basic Engineering Design Data

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3

UTILITY (ELECTRIC POWER)

3.1

Distribution (1) (2) (3) (4)

3.2

Distribution Voltage Phase Frequency Power Import/Export

33 kV, 6.9 kV, 3 and 1 50 Hz 132 kV

433V,

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250V

User Rating (1)

Voltage and phase Horsepower Range(kW) Up to 0.75 kW Over 0.75 kW ~up to 150 kW Over 150 KW ~less 3000 kW 3000 kW and above

Motors

Lighting Instruments *1)

Phase (φ) 1 or 3 (*1) 3

Remarks 50Hz 50Hz

6.6kV(*2)

3

50Hz

(*3) 240 240

3 1 1

50Hz 50Hz 50Hz

240 V 50 Hz, Single Phase: For Non Hazardous Area 415 V 50Hz 3 Phase : For Hazardous Area Over 6.6 kV rated motor may also be applicable for larger capacity, subject to owner’s approval. Motor voltage for 3000kW and over shall be selected during detailed design stage individually

*2) *3) 3.3

Voltage (V) 240 or 415 415

Emergency Power source Type of Power Source Necessity Time of Back up User of Power

UPS for Plant Shut Down n YES ¨ No o 10 min. n 30 min. ¨

Diesel Engine Generator n YES ¨ No n 72 hr ¨ ¨

Note: Users of Power for UPS: Refer to S-000-1381-004, Para. 5.1.1

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JOB CODE: 0-3100-25 DOC NO: S-000-1222-001 rev. R

Basic Engineering Design Data

4

UTILITY (WATER)

4.1

Water

SERVICE Source Supply Pressure, barg Return Pressure, barg Supply Temp., deg C Return Temp., deg C Design Press., barg Design Temp. (Note 6) Fouling Factor, h m2 oC/kcal TDS, mg/l Chloride ion, mg/l Total hardness, mg/l Ca hardness, mg/l as CaCO3 Total alkalinity, mg/l as CaCO3 pH Residual chlorine, mg/l Suspend Solids,mg/l

Note:

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SHEET : 9

Potable Water

Service Water

Seawater Desalination 2.0 34 5.0 65 -

Seawater Desalination 3.5 34 8.0 65 -

< 500 < 250 < 50 < 20

Sea Cooling Water Seawater

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Secondary Cooling Water Circulating Water

2.5 1.0 34 44 7.0/FV (Note 2) 65 0.0004

4.5 2.5 38 46 7.5 65 0.0004

< 500 < 250 < 50 < 20

36000 21300 7300 as CaCO3 1200

< 500 < 250 < 50 < 20

< 20

< 20

< 20

6.5 ~ 7.5 0.2 ~ 1.0

6.5 ~ 7.5 0 ~ 0.2

131 (Note (5)) 8.2 ~ 8.5 N/A

6.5 ~ 7.5 0 ~ 0.2

Max.25

(1) per ITT S-530-1224-901,rev.B section 2.3.2(2),”Data Sheet for Desalination Package” (2) The vacuum design pressure condition can be deleted after provision of a vent at high point of seawater cooling. Refer to H-0416. (3) Pressure for liquid services are assumed to be at grade. Refer to Category 1 item 9.69. (4) Temperature and pressure conditions are given at the supply header at each process area. Refer to H-0226. (5) As per OM-JC-12224 (6 ) The Minimum Mechanical Design Temperature specified by UOP is 250°F (120°C) for Exchanger water side.

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Basic Engineering Design Data

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Treated Water At Process Battery Limit Conditions Demineralized Water

Supply Pressure at Grade (Barg ) Water Temp. (oC) Max. 50 Nor. 34 Water Pretreatment Type Demineralizer with Polisher Service BFW make up Mechanical Press. (Barg) 10.0 Design Condition 65 Temp.(°C) O2 (mg/l) Saturated Silica (mgSiO2/l) 0.02 Iron (mg/l) Copper (mg/l) Total Hardness (mg/l as CaCO3) pH (-) < 4.0 Conductivity @25oC(µS/cm)

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Deaerated Treated Boiler Feed Water HP BFW(*1)

MP BFW(*1)

60.3 148 110 BFW 83

30 148 110 BFW 45

150 < 0.007 0.02 0.025 < 0.02 0.2

150 < 0.007 0.02 0.025 < 0.02 0.2

8.0-9.5

8.0-9.5

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Basic Engineering Design Data

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Treated WASTEWATER quality PARAMETER

UNIT

STANDARD NOT GREATER THAN

BOD

mg/l

20 or less

COD

mg/l

150 or less

Metal –Total

mg/l

10 or less

Cyanide (CN)

mg/l

0.05 or less

Grease and Oil

mg/l

5.0 or less

Ammonia Nitrogen (as N)

mg/l

1.0 or less

Nitrogen –Total

mg/l

20 or less

pH

Between

6-9

(as N)

Phenols

mg/l

0.10 or less

Phosphorus (as P)

mg/l

1.0 or less

Sulfide

mg/l

0.10 or less

Total Suspended Solids

mg/l

15 or less

Benzene

mg/l

0.1 or less

Benzo(a) pyrene

mg/l

0.1 or less

Chromium –Total*

mg/l

0.5 or less

Chromium , Hexavalent*

mg/l

0.4 or less

Lead *

mg/l

0.1 or less

Total Residue Chlorine

mg/l

0.5 or less

Coliforms-Total 100 MPN/100 ml(80%sample) or less * Note: These materials will not be contained in the influent water, so no need for any treatment. 4.4

Reused Wastewater Quality (Complying with MD 145/93)

PARAMETER

UNIT

STANDARD NOT GREATER THAN

BOD

mg/l

20

COD

mg/l

200

Oil & Grease

mg/l

0.5

Suspended Solids

mg/l

30

Phenol

mg/l

0.002

Ammonia Nitrogen (as N)

mg/l

10

Nitrate-Nitrogen (as NO3)

mg/l

50

Cyanide

mg/l

0.1

Ph

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6-9

Phosphorus (as P)

mg/l

30

Sulfide (as S)

mg/l

0.1

Chloride (as Cl)

mg/l

650

Sodium

mg/l

300

TDS

mg/l

2000

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JOB CODE: 0-3100-25 DOC NO: S-000-1222-001 rev. R

Basic Engineering Design Data

5

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UTILITY (FUEL) Gas Description

Fuel Gas Max Gasoline Case

Natural gas LP HP

10,661

10,501

10,587

32.5 29.09 13.84 11.75 2.01 1.24 0.23 0.69 0.4 0.11 0.1 0.01 0.11 <100 ppm V

35.44 27.17 11.46 11.87 0.91 1.51 0.23 0.91 1.12 0.12 0.18 0.03 0.17 <100 ppm V

7.47

8.4

0.24 0.76 <20 ppmw 1.2 5.0

0.45 17.3 Supply Condition 4.5 4.0 40 38 7.2 150

0.48 17.0

19.6

Max Olefins Case Properties Net Heating Value Max. kcal/kg Nor. Composition, mol% H2 C1 C2 = C2 C3 = C3 C4= iC4 nC4 C5= iC5 nC5 C6+ Sulfur content (as S) CO2 N2 O2 H2O Average MW Header Press. (barg) Temp.(°C) Mechanical Design Condition

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Max. Nor. Max. Nor. Press.(barg) Temp. (°C)

4.5 4.0 40 38 7.2 150

83.9 5.5 2.1

1.3

4.5 4.0 7 7 7.2 120

31 31.0 22 22 34 120

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JOB CODE: 0-3100-25 DOC NO: S-000-1222-001 rev. R

Basic Engineering Design Data

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6

UTILITY (AIR & NITROGEN GAS)

6.1

Process Area Header Condition Description

Pressure (barg)

Max. Nor. Min.

Temp. (oC) Oil Free or not Dry or not Retention Time in Emergency (Minutes) Mechanical Design Presss. (barg) Condition Temp. *1 (°C ) Composition of Gas Dew Point (°C) at 7.0 barg Note :

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Instrument Air

Plant Air

8.0 7.0 4.0 50 *2 Oil Free Dry 20 11.0

8.0 7.0 6.0 50 Oil Free Dry Wet (Note *3) 5 11.0

Nitrogen (By Others) 9.0 7.0 5.0 0-50 Oil Free Dry 11.0

120

120

120

Air -3

Air N.A

O2<20ppm None

*1 : Mechanical design temperature for the equipment and main header in the air system. *2 : To be confirmed / finalized by Dryer Vendor. *3 : Refer to H-0312

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Basic Engineering Design Data

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7

UTILITY UNIT PRICES FOR ECONOMIC STUDY

7.1

Basis of the estimation Depreciation : Interest : Equity provided : Loans Inflation Natural Gas : Operation Time :

7.2

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30

10 years 10 % 30 % 70 % 0% 0.8 US$/MMBTU 8000 hour/year

Unit Prices of Utilities Utility Sea Water Fresh Water Demine. Water Steam to Loss -HP -MP -LP -LLP Steam to Condensate -HP -MP -LP Electric Power (import) Electric Power (export) Instrument Air Service Air Nitrogen

Unit Price 0.012 US$/m3 1.5 US$/m3 2.8 US$/m3 7.2 US$/ton 7.0 US$/ton 6.9 US$/ton 6.8 US$/ton 4.4 US$/ton 4.2 US$/ton 4.1 US$/ton 0.0516 US$/kWh 0.0336 US$/kWh 0.056 US$/NM3 0.047 US$/NM3 0.35 US$/NM3

*1 Please note that the above economic values are for economic evaluation (*1-1)*1-1: “during FEED only” is deleted. Refer to Category 1 item 4.8. *2 Steam to Condensate (*2-1) *2-1: “LLP” is deleted. Refer to H-0222.

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JOB CODE: 0-3100-25 DOC NO: S-000-1222-001 rev. R

Basic Engineering Design Data

8

CLIMATE CONDITIONS

8.1

Direction & Pressure of Wind (1)

SHEET : 15

Direction of prevailing wind

(Data Source

Season (Month) Direction

:

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30

Master Plan )

ALL NNW

(2)

Basic wind speed for design:

22.9

m/sec

(3)

Structure Design Wind Pressure ASCE 7-98

(4)

Importance factor Category 1I (I=1)

(5)

Exposure category D: extends in land from the shoreline a distance of 460 m or 10 times the height of structure or equipment Exposure category C: for all remaining area

Note: refer to clarification, H-0096. 8.2

Temperature (1)

Climatic temperature (Data Source: Sohar Port EIA) Max.

Dry Bulb Temp. (°C) Relative Humidity (%) Design Base Temp.(°C)

47.5 100 42

Monthly Mean Maximum 32 (May) -

Min. 10 6 5

Monthly Mean Minimum . 20 (Jan) -

Remarks; Min. Recorded temperature of 3.5 oC shall be used for examining the impact to transportation with high pour point fluid. (2)

Service temperature for each design purpose (a) (b) (c) (d) (e) (f)

(g)

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Dry bulb temp. of air for process calculation of AFC Minimum design metal temp. Min. temp. for piping stress analysis Winterizing temp. Design temp. for outdoor electrical equipment Design condition of air blower & air compressor Max. Dry bulb Temp. Min. Dry bulb Temp. Relative humidity Design Condition for air conditioning Summer dry bulb temperature Summer wet bulb temperature Winter dry bulb temperature

42°C 5°C 5 °C 5°C 5°C ∼ 42 °C 43 °C 5 °C 80 % 43.0 oC 30.1 oC 10.0 oC

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JOB CODE: 0-3100-25 DOC NO: S-000-1222-001 rev. R

Basic Engineering Design Data

8.3

RAINFALL

(Data source:

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Master Plan)

Per day Per hour Recorded Max. Rain fall (mm) 100 mm N/A. Design Base 100 mm 75 mm Snow Load ( Not applicable) Remarks; a) In excess of 90% of the rainfall occurs during the winter months, with the reminder falling in July and August. No rainfall was recorded for May, June or September between 1993 and 1997. b) For civil ditch design and roof drain design for FRT, rain fall of 25 mm/h is to be considered. 8.4

Earthquake (1)

8.5

8.6

Seismic factor

:

Not Applicable

Atmospheric pressure (Data source:

Sohar Port EIA)

Max, Min., Design Atmospheric Pressure,

1025.6 mb 990.2 mb 1016.0 mb

Environmental Conditions a) All equipment shall be tropicalized to eliminate mildew, fungi, and other detrimental effects of a tropical environment. Packaging shall be suitable for shipment and storage under tropical conditions. b) All field equipment shall be suitable for operation in a corrosive, salt laden, marine atmosphere. c) All equipment shall be suitable for operation in a dusty environment subject to frequent sand storms and ambient temperatures exceeding 40 oC. Contractor shall install sun-shielding equipment when specified by the vendor, or when anticipated conditions require it.

9

SITE CONDITIONS

9.1

Soil Conditions (1)

Soil conditions are assumed as per the soil survey data in given in the contract. •

(2)

Soil/Pile bearing value •

(3) 9.2

Soil survey report by Owner

As per soil report in ITB, which shall be verified by EPC Contractor.

Frost line depth

Site Elevation (Basic Ground Level) MSL + 4.0 m (EL100.000m) MSL + 3.5 m (EL99.500m) MSL + 3.15 m (EL 99.150m)

_ _ _ __ R_A_| D N I _ _ | _ 3 P-200 15-SE

N/A

at High Point for the North Tankage Area, Process and Utility Area at High Point for the South East Tankage Area, WWT Area, Truck Loading Area and Maintenance Area at High Point for Flare Area, Administration Area and Other Future Area

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Bench Mark (B.M) Elevation (above sea level)

10

Later

(

)

ENVIRONMENTAL REQUIREMENT FOR AIR QUALITY (SOURCE EMISSION) Ambient Particulate SOx, as SO2 NOx as NO2 CO HCl HF Phosphorous Component H 2S

mg/Nm3 mg/Nm3 mg/Nm3 vol % mg/Nm3 mg/Nm3 mg/Nm3 ppmv

100 (Note 1)(Note 2) min. possible (Note 1) 200 (Note1) 0.5 200 100 50 5

Note (1) : 6% dry O2 basis for Gas Turbines and Waste Heat Recoveries. Refer to H-0316. (2) : 50 mg/Nm3 shall be applied for RFCC Flue gas at SK-2301. 11

ENVIRONMENTAL REQUIREMENT FOR NOISE

11.1

Environmental Noise Limit 70 dB(A) at the boundary of the Plant for the normal operation (*) (*) Industrial and commercial district / Holiday and night

11.2

Absolute Noise Limit Maximum 120 dB(A) at any time and place in the work area (**) (**) excluding calamities

11.3

General Work Area Noise Limit 85 dB(A) (***) (***) If it appears unavoidable and Owner accepts that the General Work Area Noise Limit will be exceeded, the area will be proclaimed as a Restricted Area.

_ _ _ __ R_A_| D N I _ _ | _ 3 P-200 15-SE

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BASIC DESIGN PHILOSOPHY

The purpose of this section is to define basic project requirement and design philosophy for the Sohar Refinery Project as a basis for development of individual unit and system designs. 12

PROCESS DESIGN PHILOSOPHY AND INFORMATION

12.1

Unit turndown Unit turndown shall be 50 % of design throughput, unless otherwise specified in individual unit design basis.

12.2

Heat Recovery Steam generation and heat recovery facilities shall be incorporated based on process and economic considerations.

12.3

Design Margin Design margins of each equipment shall be as follows, unless otherwise specified in individual data sheets : (1)

12.4

Pumps Charge pumps Product pumps Reflux pumps

: : :

Flow rate Flow rate Flow rate

10 % 10 % 20 %

(2) (3) (4) (5)

Compressors Fired heater Heat exchangers Vessels/Columns

: : : :

Flow rate 10 % Duty 10 % No margin No margin Column diameter and tray designs shall be based on a maximum 82% of Jet Flooding.

(6)

Hydraulics

:

No margin (To check the controllability of control valves at 110 % of normal flowrate, unless other margins are specified in the individual data sheets of related equipment. )

Design Pressure Positive Design Pressure shall be no less than the expected maximum operating pressure (Also, see Para. 13.7(5) below). If the maximum pressure cannot be expected, it shall be 1.1 times the normal operating pressure (gauge pressure) or the normal operating pressure + 1.8 bar, whichever is greater. Negative Design Pressure shall be no more than the expected minimum vacuum operating pressure. If the minimum negative pressure cannot be expected, it shall be according to Para.12.9. Apply the ASME 10/13 rule to derive the minimum design pressure of the low pressure side of tubular heat exchangers as per Category 1 item 9.13.

12.5

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Design Temperature Hot Design Temperature above 0 °C shall be no less than the expected maximum operating temperature. If the maximum temperature cannot be expected, it shall be the normal operating temperature + 15 °C rounded to nearest 5 °C as standard. If a material change is expected due to this requirement, the appropriate design temperature shall be proposed for SRP approval.

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Cold Design Temperature Below 0 oC shall be less than the expected minimum cold operating temperature. If the minimum temperature cannot be expected, the minimum temperature shall be recommended and specified during engineering phase. 12.6

Steam Purge Condition Steam purge condition :

12.7

3.5 barg @ 150 oC

Aromatics Handling Plant shall be designed in order to reduce emissions of hazardous components like benzene, hazardous aromatic, etc. The design requirements presented shall be applicable for all process streams containing 1 wt% or more benzene or 25 wt% or more C6-C9 aromatics. These requirements are :

12.8

(1)

Closed, flow-through sample containers are to be used.

(2)

A Closed, aromatics collection system is required, to which the following are to be applied: Vessel drains Control valve drains Gauge glass/level instrument drains Pump drains

(3)

Providing dual seals and suitable barrier fluid systems for pumps for Aromatics. double or tandem depending upon process requirements.

(4)

Water saturated with hazardous component(s) shall be fed to suitable locations within process or to appropriate other facilities in order to minimize hazardous component emissions to the environment.

Seal will be

Standard Corrosion allowance (1)

Standard corrosion allowance for internal surface of pressure vessel (except lined vessel) are : for carbon steel, for low alloy steel, for stainless steel, for non-ferrous material,

(2)

3.0 3.0 0.0 0.0

mm mm mm mm

Standard corrosion allowance for each side of vessel internal (except lined vessel), such as tray, are : for carbon steel, for low alloy steel, for stainless steel, for non-ferrous material,

1.5 1.5 0.0 0.0

mm mm mm mm

Note : For spheres, refer to S-000-1354-002, General Specification for Sphere. 12.9

Vacuum design A vacuum design shall be carried out for any of the following equipment according to the specified vacuum type, unless otherwise specified: (1)

_ _ _ __ R_A_| D N I _ _ | _ 3 P-200 15-SE

(2) (3)

All equipment that normally operates under vacuum conditions, or is subject to startup, shutdown and/or regeneration evacuation : Full Vacuum Vessels which normally operate liquid full and becomes a vacuum condition when the vessel can be blocked in and cooled down : Full Vacuum Fractionators and associated equipment that can undergo a vacuum condition through the loss

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of heat input : Half or Full Vacuum No vacuum design due to blocking in after steam out or any other operator mal-operation is required. If some devices, such as vacuum breaker, are installed, the vacuum design conditions may be omitted as per SRC’s instruction H-0416. 13

EQUIPMENT DESIGN PHILOSOPHY & INFORMATION

13.1

Vessels (1)

Dimension indication should be inside diameter & tangential lines' distance

(2)

Head shape should be ASME 2:1 elliptical heads normally & hemispherical heads for high pressure vessels

(3)

Size limitation for transportation of shop fabricated vessels. Diameter and Length limitation should be determined by EPC Contractor.

(4)

Connection on equipment should be basically flanged and maybe beveled for welding of large diameter connections, for 30” and larger.

(5)

Small nozzle installed directly on equipment (a) Minimum connection size : 1 inch (*) (b) Flange rating : same as the rating of the connecting part of equipment even for 1 inch or smaller * : 2 inch for lined nozzle, unless otherwise specified. The above criteria, a) & b) shall also be applied for tanks, shell & tube exchangers, air coolers, and fired heaters.

(6)

Separate steam-out connection on vessel shall be provided. drain nozzles, and minimum size will be 2 inches.

(7)

Manhole (a) (b)

(c)

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Minimum manhole size : 20 inches inside diameter - 24 inches inside diameter minimum for fixed bed reactors. - For vessels less than 900 mm inside diameter, Shell flange will be provided. Manhole in trayed columns To be provided in the top head, below the bottom tray, at the feed tray, and at intermediate points specified by standard spacing of manholes, if practical. Maximum distance between manholes in the tray section shall be 10 meters. Manhole installation on horizontal vessel head is acceptable.

(8)

Nozzle for instrument Refer to Para.14.1, 14.2 and 14.3.

(9)

Drain and vent (a)

Size shall be same as vent &

Size Vessel Diameter 4500 mm and less Over 4500 thorough 6000 mm Over 6000 mm

Drain Size, inch 2 3 4

Vent Size, inch 2 3 4

(b) Ending of nozzle - Drain ■ Plugged or Capped. ( ≤ ANSI CL.600 and ≤ 1 1/2”) ■ Flanged with blind. ( ≥ ANSI CL.900 or ≥ 2”)

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Vent ■ Plugged or Capped. ( ≤ ANSI CL.600 and ≤ 1 1/2”) ■ Flanged with blind. ( ≥ ANSI CL.900 or ≥ 2”) □ Capped. Installation of drain nozzle on vessel's bottom line may be acceptable.

(c) (10)

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Capped.

□ -

SHEET : 21

Ventilation nozzle on horizontal vessels should be provided on the top of the vessel near the end opposite the manway. Ventilation nozzle on vertical vessels should be also provided on the top head of the vessels unless two or more manways are specified at the top and bottom of the vessel respectively. Vessel Tangent Length, mm 3000 through 4500 mm Over 4500 thorough 7500 mm Over 7500mm

Ventilation Nozzle inch 4 6 8

Size,

- Ending of Ventilation nozzle ■ Plugged. ( ≤ ANSI CL.600 and ≤ 1 1/2”) ■ Flanged with blind. ( ≥ ANSI CL.900 or ≥ 2”) (11)

Liquid drop legs should be welded to the vessel when their inside diameter is more than 300 mm. (The legs to be lined by the same material as for the vessel, where the vessel is lined..)

(12)

Liquid Residence Time Liquid minimum residence time guidelines listed below should be used unless otherwise specified in each data sheet. The minimum residence times are based on from normal liquid level to empty. Service Tower Bottom Feed Surge Drum Reflux Drum Feed to Storage Feed to Another Column/Unit Water Boots

13.2

Minimum Residence Time ,minutes 2 5 2 (*) 3 (*) 5

(*)

For total flowrate, i.e. Reflux rate plus Product Rate.

(13)

Connections for safety valves, pressure and temperature instruments, and drains, to be on piping instead of on piece of equipment as far as relevant. Refer to Category 1 item 7.21.

Tray & Packing (1)

Numbering of tray shall be from bottom to top.

(2)

Material of tray Carbon steel trays and carbon steel or alloy valve parts for non-corrosive during normal operation. Alloy trays and alloy valve parts for corrosive services during normal operation.

(3)

Tray Design Allowance Tray design should be based on maximum 82 % of Jet flooding.

_ _ _ __ R_A_| D N I _ _ | _ 3 P-200 15-SE

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Tanks (1)

Purge connection is generally not required.

(2)

Manholes Size & No. shall be determined as per International Standards.

(3)

Drain and vent (a)

(b)

(c) 13.4

SHEET : 22

Size & No. Drain Nozzle Nominal Diameter (meter) < 12 12 to 45 46 to 61 > 61

No. 1 2 3 4

Ending of nozzle - Drain

Flanged with blind.

- Vent

Open

Installation of drain nozzle on liquid draw line is not acceptable.

Shell & tube heat exchangers (1)

Preferable Nominal straight tube length Nominal for design :

6.1 m (20”)

(2)

Tube diameter & wall thickness (a) for carbon steel and low alloy (up to and including 5Cr-1/2Mo) - Preferred diameter 25.0 mm - Min. wall thickness 2.77 mm (b) for high alloy (above 5Cr-1/2Mo and up through austenitic stainless steel) - Preferred diameter 25.0 mm - Min. wall thickness 2.11 mm (c) for non-ferrous (Admiralty, Cu-Ni, etc.) - Preferred diameter 25.0 mm - Min. wall thickness 1.65 mm (d) for titanium - Preferred diameter 25.0 mm - Min. wall thickness 1.25 mm

(3)

Limitation of tube bundle based on available pulling and lifting equipment Maximum allowable bundle dia. : Maximum allowable bundle weight :

1500 mm 16000 kg

(Note) (Note)

Note: To be confirmed during detailed engineering, considering the actual bundle pulling equipment as a part of maintenance equipment. (4)

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Material for sea water cooling water service, Aluminum brass, 70-30 Cu-Ni, 90-10 Cu-Ni, or titanium for non-corrosive service, cold service, and non-amine service. 70-30 Cu-Ni or titanium for corrosive service and amine service.

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(5)

Required fouling factor for sea water service to be 0.0004 m2hroC/kcal

(6)

Standard exchanger tube type

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U-tube type may be adopted when tube side fouling is less than 0.0004 hr.m2°C/kcal and floating head type shall be adopted when tube side fouling is 0.0004 hr.m2°C/kcal or greater. (7)

Square pitch to be used when shell side fouling is 0.0004 hr.m2°C/kcal or greater.

(8)

Application of double pipe or multi-tube exchangers may be acceptable.

(9)

Application of stabbed-in, vertical thermosiphon, horizontal thermosiphon, or kettle type reboiler may be acceptable.

(10)

Velocity Limitation in tube for sea water services : Tube Material Aluminum Brass

Velocity Limitation (m/s) 1.0 – 2.4

70-30 Cu-Ni

1.2 – 2.9

90-10 Cu-Ni

1.2 – 2.0

Titanium

2.0 – 4.0 (2.5 is preferred)*

Note * : Refer to H-0135. (11)

Preference of fluid flowing (a) (b) (c) (d)

13.5

□ □ □ □

Shell side Shell side Shell side Shell side

42 oC

Ambient temperature for air cooled heat exchanger design:

(2)

Process outlet temperature for air cooled heat exchanger design : 53 oC (Ambient Temperature plus 11 oC)

(3)

Application of air cooled heat exchanger is preferred over water cooled heat exchange. - Preferred process temperature breakpoint is 56 °C (Ambient Temperature plus 14 oC) when the air cooler is followed by water coolers.

(4)

Preference for draft type forced draft

□

induced draft

Temperature should be controlled by auto-variable type blade pitch control on 50 % of the fans in the air bay, when temperature control is required.

Heaters (excluding Reformer) (1)

3 P-200 15-SE

Tube side Tube side Tube side Tube side

(1)

(5)

_ _ _ __ R_A_| D N I _ _ | _

■ ■ ■ ■

Air cooled heat exchangers

■

13.6

Sea Water : Corrosive fluid : Dirty fluid : High Pressure fluid:

Firing of heater ■

Gas burner only

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Oil burner only Gas & Oil burner

Requirement of pilot burner ■

(3)

SHEET : 24

for each burner

(Natural Gas Firing)

Target heater fuel efficiency based on the net heating value (LHV) shall be as follows : F-1101 F-2001 F-3201 F-4201

81 % 79 % 83 % 79 %

Note : As per Volume 4.2.4 of Technical Proposal dated 1 July 2002. (4)

Requirement for stack general Requirement for stack height shall be determined in accordance with S-000-1356-001, General Specification for Fired Heater.

(5)

13.7

Instrument connections (a) Draft gauge connections : below conv. sect.+ above & below stack damper (b) Flue gas sampling connections : below stack damper (c) Oxygen analyzer connection : below conv. sect. (d) Temperature measurement connections : below conv. sect.+ below stack damper

Pumps (1)

Driver type Electric motors are basically provided for most of the pumps. There is a case that a main pump has an electric motor and the spare pump has a steam turbine, and vice versa. The type of driver will be determined by operating philosophy and equipment criticality. The steam turbine will be generally a back -pressure type and be designed and fabricated in accordance with API Standard 611.

(2)

Sparing Most of the pumps in continuous service shall have an installed spare pump for each pump item. A common spare pump may be considered for non-critical service. For intermittent services, no spare or a warehouse spare may be provided as appropriate.

(3)

Application of special type pump An integrally geared high-speed vertical in-line pump may be provided for low flow and high head services.

(4)

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Pump seal type and system Mechanical seals are provided for the centrifugal and rotary pumps for hydrocarbon services. The pumps handling non-toxic water and vertical submerged type pumps may have a gland packing seal. A tandem seal (un pressurized dual seal) is generally recommended for the pumps handling flushing hydrocarbons containing aromatics as specified in Section 12.7 and/or LPG. Use of tandem seal will be specified in the individual pump data sheet. API 682 seal is applied for the mechanical seals of API 610 centrifugal pumps. Refer to para. 12.7 (3)

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Pump Shutoff Pressure The assumed shutoff pressure of centrifugal pumps shall be the max suction pressure plus 120 % of the differential pressure at rated capacity as minimum. Where; max suction pressure = design pressure of suction vessel + pressure drop across internal + static head at high liquid level

13.8

Compressors (1)

Driver type Compressors may have either electric motor or steam turbine driver depending on overall plant economics, electric power reliability and/or plant utility balance. The type of driver will be specified in the individual data sheet.

(2)

Sparing Due to their high reliability, centrifugal and axial compressors will not be spared. For reciprocating compressors, sufficient spare capacity will be specified to permit maintenance of one machine while the plant remains on stream.

(3)

Application of special type compressor A screw compressor may be provided as appropriate. Screw compressor will not be spared. API 619 is applied for the screw gas compressors.

(4)

Cooling method for turbine exhaust steam surface condenser when applied. Sea water is used as a cooling media of the steam surface condensers.

(5)

Bearing temperature and vibration monitoring equipment for large size rotating equipment The equipment requiring machine condition monitoring systems is referred to S-000-1377-005 (Specification for Vibration Monitoring System)

(6)

Compressors will be specified on the basis of unheated, sheltered, outdoor installation.

14

INSTRUMENT DESIGN PHILOSOPHY & INFORMATION

14.1

Temperature instrument (1)

Temperature measurement for heat exchanger inlet and outlet except for process monitoring and control, (a)

when process fluid is flowing, - measuring point □ not required. ■ for each heat exchanger service (not each shell) - measuring instrument ■ board temperature indicators ■ local thermometers, unless Licensor indicated in Licensor’s P&ID. □ thermowell only

(b)

when

sea cooling water (SW) is flowing, ■

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local thermo meter for outlet. (Inlet side temperature indicator will be provided on supply header.)

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Thermowell nozzle size and connection type (a)

For vessels minimum size : connection type : * :

1.5" I.D. flanged

(*)

Ensure 1.5 inch min. inside diameter for alloy lined nozzle etc. by using larger diameter. Refer to Category-1 Item 5.7.

(b)

For piping minimum size : connection type : *: Refer to Category-1 Item 5.7.

(3)

For vessels For piping

: :

same as line class of piping on the vessel same as piping line class

Level instrument (1) (2)

Displacement type level instrument maximum allowable length : Nozzle for instrument -

If the nozzle is installed directly on the vessel, nozzles shall be conformed the minimum size and rating described in para 12

*2 :

Flange rating of instrument nozzle when it is installed on pipe column or bridle to be same as line class of piping on the vessel. Refer to Category 1 item 5.53.

Pressure Instrument Nozzle size and connection (a)

(b)

(2)

3 P-200 15-SE

1-1/2 inch 3/4 inch 2 inch (*2) 2 inch (*2) 3/4 inch

*1 :

(1)

_ _ _ __ R_A_| D N I _ _ | _

upto 1524 mm

Nozzle for instrument for level controller shall be independent from that for level gauges (LG). Nozzle size

for displacement type level instrument : for level gauge (*1) : for pipe column : for bridle : for differential pressure type level transmitter (*1):

14.3

(*)

Thermowell flange class (minimum) (a) (b)

14.2

1.5" I.D. flanged

For vessels minimum size connection

: :

1 inch (refer to para. 13.1) flanged

For piping minimum size connection

: :

3/4 inch Threaded(NPT)

Diaphragm Type Pressure Instrument Diaphragm type pressure instrument should be specified to the following services: -

Severe corrosive circumstance, i.e. acid gas Slurry services High pour point services, i.e. AR where salt deposition are expected

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Control Valve (1) (2)

14.5

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Control valve bodies flange class to be same as piping line class. Refer to Category 1 item 5.53. Minimum body size to be 1inch.

Pressure relief valves (PRV) and Flare Load (1)

Basis for design (a) Basis for calculation of relieving load : API RP-520 & 521 (b) Basis for accumulation of pressure vessel : ASME SEC. VIII, where applicable (c) Basis for accumulation of boiler: ASME SEC. I, where applicable (d) Basis for calculation of inlet line pressure loss and back pressure of safety valve : API RP-520 & 521

(2)

Application A single pressure relief valve shall be provided for each service unless : (a) multiple valves are necessary because the required capacity cannot be provided in a single valve or are preferred for a particular service; (b) dual valves are required in accordance with ASME Boiler and Pressure Vessel Code, Sect. I, etc.

(3)

Spare of pressure relief valve to be provided, except in non-critical services.

(4)

Pilot operated PRV may be specified where: - significant inlet piping pressure loss are expected. - the process operating pressure is close to the relief valve set pressure - the relief valve set pressure is below 1 barg - a specific application requires design features unique to a pilot operated relief valve - a pilot operated PRV is the most economical at the location

15

MATERIAL SELECTION PHILOSOPHY

15.1

Plant Life Plant life is specified to be 20 years.

15.2

Basis for Material Selection Materials and corrosion allowance shall be determined considering the following mode of material degradation during operation. Minimum corrosion allowance for piping made of carbon steels and alloy steels shall be 1.5mm.. (1)

Corrosion (a)

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High-temperature sulfur service Sulfidic corrosion is experienced in equipment and piping handling hydrocarbon containing high-temperature organic sulfur. Formation of sulfide scale and metal loss occurs at higher temperature. Corrosion resistance is improved by adding chromium to steel, and 5Cr-0.5Mo steel or carbon steel clad with 13Cr steel are applied to high-temperature sulfidic environments.

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(b)

High-temp. H2S service Sulfidic corrosion is also experienced in environments containing high-temperature H2S. Addition of chromium is also beneficial in reducing corrosion in high-temperature H2S environment. Corrosion rate of steels in high-temp. H2S environment should be evaluated by isocorrosion curves presented by A. S. Couper and J.W. Gorman. Where carbon steel and Cr-Mo steel cannot be applied due to high corrosion rates, austenitic stainless steel of stabilized grade shall be applied as solid material or cladding material.

(c)

High-temperature hydrogen service In high-temperature hydrogen environments, steels may subject to internal decarburization and/or surface decarburization. This internal decarburization is called hydrogen attack and may cause severe ductility loss. Addition of chromium and/or molybdenum are beneficial in improving the resistance to hydrogen attack. API Recommended Practice 941, fifth edition shall be employed to select proper materials for high-temperature hydrogen service.

(e)

Amine service Rich amine is basically corrosive. Carbon steel can, however, be used throughout the process, because protective layer of FeS on carbon steel is made, with the following exceptions where austenetic stainless steel shall be applied. l Heat exchanger tubes on which surface boiling or acid gas flashing takes place l Piping where protective layer of FeS is anticipated to be destroyed due to high velocity of fluid. As for cracking in the service, refer to item (2), (c).

(d)

Sea water service Tube materials for sea water cooler shall be determined on the following basis: Table

Guideline for selecting materials of sea water cooler

Materials Tube Al Brass Cupro-nickel Titanium (2)

Tubesheet & channel Carbon steel clad with Aluminum Bronze Plate Carbon steel clad with CuNi Carbon steel clad with Ti

3 P-200 15-SE

Limiting temp., deg C

Not applicable

232

Applicable

316

Applicable

Embrittlement or cracking (a)

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Sea water

Service Ammonia or hot sulfides service

Sulfide stress cracking(SSC) Sulfide stress cracking(SSC) may occur in carbon steel and its welds which are applied to sour service, if hardness is not controlled below certain threshold value. NACE MR0175-02 defines the SSC regions where cracking may occur unless cares for SSC should not be taken, and specifies the hardness limit to be controlled. Materials selection and the necessity of PWHT shall be determined by NACE MR0175-02.

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Hydrogen induced cracking(HIC) HIC is other mode of cracking, resulting from hydrogen absorbed during operation. As mentioned above, SSC may occur at hardened areas, whereas, HIC may occur especially in base metal of rolled steel plate which is subjected to sour service. HIC resistant steel whose resistance to cracking is confirmed, should be applied to the service.. Nowadays, HIC resistant steels are available in Japan USA, Europe and so on, and being applied to vessels and welded pipe. However, no official guideline exists which defines the environment which requires HIC resistant steel. Equipment and piping requiring HIC resistant steel, shall be determined based on the process conditions and past failure experiences on HIC. Amine stress cracking Amine stress cracking may occur in HAZ carbon steel which is in contact with lean or rich amine solutions. Reducing residual stress is beneficial for avoiding cracking, and accordingly, PWHT or stress relieving are to be performed to reduce residual stress in welds or bends to avoid cracking in the service. Exception can be made for amine storage tank taking low design temperature(not more than 70oC) and low design pressure(atmospheric pressure) into consideration.

Reference (1) (2) (3)

16

SHEET : 29

A. S. Couper and J.W. Gorman ;NACE 1970, Paper No.67 API Recommended Practice 941 fifth edition, Jan., 1997 NACE MR0175-02

BURNER MANAGEMENT SYSTEM REQUIREMENTS

The fired heater of non-licenced unit and licenced unit shall be provided with the following burner management system to avoid the unstable operation and be consistent with Mina Al Fahal (MAF) Refinery system. 16.1

High High or Low Low Pressure of Main Fuel Gas To prevent unstable burning or being blown off due to extra low or high pressure respectively of main fuel gas, an emergency isolation sequence is provided for high high or low low pressure of main fuel gas.

16.2

Low Low Pressure of Pilot Natural Gas To prevent unstable burning or being blown off due to extra low pressure of pilot natural gas, an emergency isolation sequence is provided for low low pressure of pilot natural gas.

16.3

High High Level of Fuel Gas K.O. Drum To protect furnace from liquid carryover in fuel gas, which may seriously damage, an emergency isolation sequence is provided for high high level of fuel gas K.O. drum.

16.4

High High Pressure of Fire Box To prevent unstable burning or being blown off due to extra high pressure of fire box, an emergency isolation sequence is provided for high high pressure of fire box.

17

OTHER INFORMATION

17.1

Battery Limit requirements

_ _ _ __ R_A_| D N I _ _ | _ 3 P-200 15-SE

Temperature and pressure information for streams entering and leaving the battery limits of the process unit are provided in the "Design Basis of process unit".

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Sohar Refinery Company SOHAR Refinery Project Basic Engineering Design Data

17.2

JOB CODE: 0-3100-25 DOC NO: S-000-1222-001 rev. R SHEET : 30

of

30

Interface Conditions with OPP and Other Third Parties As per Third Party Interface Points List (S-000-1221-001)

_ _ _ __ R_A_| D N I _ _ | _ 3 P-200 15-SE

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