Uops Bedq Rev 1

Revision Indication

uop UOP LLC • 25 East Algonquin Road • Des Plaines, Illinois 60017-5017 • USA

ENGINEERING DESIGN INFORMATION

Project : 942066 - A.4 SHEET 1

BASIC ENGINEERING DESIGN QUESTIONNAIRE

Form EDI-02-18

REV DATE BY APVD REV DATE BY APVD

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BEDQ REVISION TABULATION Project

BEDQ Sheet Number

Current Revision Number by Sheet

1 2 3 4 5 6 7 8 9 10

1 - 10 1 1 1 1 1

11 - 20 1 1 1 1 1

21 - 30 1 1 1 1 1 1

31 - 40 1 1 1 1 1 1 1

41 - 50 1 1 1 1 1 1

51 - 60 1 1 1

61 - 70 1 1 1

71 - 80 1 1 1 1 1 1 1

BEDQ APPENDICES

1

2

3

4

5

6

7

8

9

10

Appendix Sheet Number

1 81 1

2 82-83 1

3 84 1

4 85

5 86-92

Note: (1) The revision number of this sheet is the revision number of the BEDQ. (2) Each sheet of the BEDQ is revision 0 unless otherwise indicated above.

** Default selection

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Table of Contents

1. Coordination..................................................................................................................................................... 5

1.1 INTRODUCTION AND INSTRUCTIONS FOR USE ................................................................................... 5 1.2 GENERAL INFORMATION .................................................................................................................. 6 1.3 COORDINATION PROCEDURE........................................................................................................... 7 1.4 ELECTRONIC DISTRIBUTION OF SPECIFICATIONS **......................................................................... 13 1.5 COMPUTER AIDED DRAFTING (CADD) FILES ................................................................................. 15 1.6 HARD COPY DISTRIBUTION OF SPECIFICATIONS ............................................................................. 16 1.7 UNIT, EQUIPMENT, AND INSTRUMENT NUMBERING .......................................................................... 18 1.8 SYSTEM OF MEASUREMENT .......................................................................................................... 21

2. Design Philosophy .......................................................................................................................................... 22

2.1 HAZOP ....................................................................................................................................... 22 2.2 CRITICAL SERVICE ROTATING EQUIPMENT ..................................................................................... 22 2.3 VACUUM DESIGN .......................................................................................................................... 22 2.4 DESIGN TEMPERATURE AND PRESSURE......................................................................................... 23 2.5 TANKAGE ..................................................................................................................................... 23 2.6 HEAT RECOVERY.......................................................................................................................... 24 2.7 TYPICAL EQUIPMENT LAYOUT........................................................................................................ 24 2.8 UNIT TURNDOWN.......................................................................................................................... 24 2.9 TOXIC CHEMICAL HANDLING.......................................................................................................... 25 2.10 NOISE LEVEL LIMITATIONS ............................................................................................................ 26 2.11 METALLURGY ............................................................................................................................... 27 2.12 STEAM SYSTEM ............................................................................................................................ 27

3.Utility Information ....................................................................................................................................... 28

3.1 STEAM SYSTEM ............................................................................................................................ 28 3.2 CONDENSATE RETURN SYSTEMS .................................................................................................. 28 CONDENSATE RECOVERY...................................................................................................................... 28 5.0 28 3.3 PROCESS WATER AND BOILER FEEDWATER................................................................................... 29 3.4 COOLING WATER.......................................................................................................................... 30 3.5 FUEL OIL SYSTEM......................................................................................................................... 31 3.6 FUEL GAS SYSTEM ....................................................................................................................... 32 3.7 ELECTRICAL POWER ..................................................................................................................... 35 3.8 PLANT AND INSTRUMENT AIR......................................................................................................... 36 3.9 NITROGEN.................................................................................................................................... 36 3.10 CAUSTIC ...................................................................................................................................... 37 3.11 SPENT CAUSTIC ........................................................................................................................... 37 SPENT CAUSTIC TREATING UNIT.............................................................................................................. 37 3.12 HOT OIL SYSTEM.......................................................................................................................... 38 3.13 Amine.............................................................................................................................. 38

4. Site Information ............................................................................................................................................. 39

4.1 WINTERIZING TEMPERATURE......................................................................................................... 39 4.2 LOW AMBIENT TEMPERATURE ....................................................................................................... 39 4.3 HIGH AMBIENT DESIGN TEMPERATURES ........................................................................................ 39 4.4 UNIT ELEVATION........................................................................................................................... 39

5. Equipment ...................................................................................................................................................... 40


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5.1 FIRED HEATERS ........................................................................................................................... 40 5.2 VESSELS ...................................................................................................................................... 46 5.3 TRAYS AND PACKING .................................................................................................................... 52 5.4 SHELL AND TUBE HEAT EXCHANGERS ........................................................................................... 53 5.5 AIR COOLED HEAT EXCHANGERS .................................................................................................. 58 5.6 PUMPS ......................................................................................................................................... 60 5.7 COMPRESSORS ............................................................................................................................ 63 5.8 PRESSURE RELIEF VALVES ........................................................................................................... 65

6. Instruments..................................................................................................................................................... 69

6.1 BASIC PROCESS CONTROL SYSTEM .............................................................................................. 69 6.2 LOGIC SYSTEMS ........................................................................................................................... 69 6.3 INSTRUMENTATION UNITS OF MEASUREMENT................................................................................. 71 6.4 TEMPERATURE INSTRUMENTS ....................................................................................................... 72 6.5 LEVEL TRANSMITTERS AND MAGNETIC LEVEL INDICATORS.............................................................. 74 6.6 CONTROL VALVES ........................................................................................................................ 75 6.7 TOTALIZATION EQUIPMENT ............................................................................................................ 75 6.8 ANALYZERS .................................................................................................................................. 75 6.9 ELECTRICAL POWER ..................................................................................................................... 75 6.10 SITE CONDITIONS - INSTRUMENTS ................................................................................................. 76 6.11 MISCELLANEOUS .......................................................................................................................... 77 6.12 ADDITIONAL REQUIREMENTS ......................................................................................................... 77

7. Miscellaneous ................................................................................................................................................ 78

7.1 BATTERY LIMIT REQUIREMENTS..................................................................................................... 78 7.2 BATTERY LIMIT ISOLATION............................................................................................................. 80 7.3 WASTEWATER COLLECTION .......................................................................................................... 81 7.4 INSULATION .................................................................................................................................. 81

APPENDIX 1.........................................................................................................Error! Bookmark not defined.1

APPENDIX 2 ............................................................................................................................... 832-83 APPENDIX 3.................................................................................................................................................... 854

APPENDIX 4.................................................................................................................................................... 865

APPENDIX 5...................................................................................................................................................... 86


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1. Coordination

1.1 Introduction and Instructions for Use

This Basic Engineering Design Questionnaire (BEDQ) solicits technical information from the Owner for UOP to prepare the Engineering Design Specifications. The Engineering Design Specifications will be prepared in accordance with UOP's Standards and normal design practices unless otherwise agreed. Changes in the BEDQ, after the start of a project, may result in a change in the agreed-upon schedule and/or engineering charges. The BEDQ should be filled out as completely as possible by the appropriate technical personnel within the Owner's organization.

• If no data is available, insert "No Data." • If the item is not applicable to the scope of work, insert "NA". • If no preference or criteria exists, insert an "X" in the appropriate checkbox (** Default

selection). • If codes, standards, or design practices other than those expressed herein are required,

insert an “X” in the appropriate checkbox and describe the alternate design criteria on the lines provided or in an appendix.

• If a page or section has a large X over the text, this section does not need to be

completed.

The explanatory text of the BEDQ shall not be changed. Use additional sheets as appendices if more space is required. All appendices must be referenced in the appropriate sections of the BEDQ. Appendices are numbered and each appendix shall be limited to one and only one subject. Lengthy appendices, customer standards, etc. should be transmitted as electronic files if possible. The BEDQ has been divided into convenient topical sections to be easily distributed to different specialists for completion. When the BEDQ data is complete, it should be sent to UOP as soon as possible for review. Resolution of uncertainties and questions is required prior to executing an Engineering Agreement and starting design engineering.

After all questions are resolved, the BEDQ is released and all parties receive an official, approved copy.


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1.2 General Information

a. Name and Location Indicate Owner’s name, project title, plant location, shortened name or acronym (e.g., International Business Machines = ”IBM”), and any other specific information as it should appear on UOP project specifications and drawing title blocks.

Name: Essar Oil Limited

Refinery Division

Location: Vadinar, Jamnagar

Gujarat

India

b. Scope of Facilities

Indicate the process units and offsite facilities to be included in this project. Project number(s) will be assigned by UOP. Note: Unit names should match names in Engineering Agreement.

Proj. # Unit Name

942066 VGO Unionfining Unit

943493 Distillate Unionfining Unit (DHDT)

944268 Distillate Unionfining Unit (Kerosene)

944269 Kerosene Merox Unit

c. Standard Specifications, Codes and Practices

UOP's engineering design incorporates UOP Standard Specifications and the general codes and standard practices used in the United States. Adaptation of UOP's engineering design to the Owner's standard specifications, local codes and practices will be done by the Detailed Design Contractor, unless contractually agreed otherwise. If the Owner requires UOP to consider the inclusion of other specifications, codes or practices, list them below and provide two copies of each (in English) as part of this questionnaire.


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1.3 Coordination Procedure a. Correspondence to Owner relating to this project should be directed as follows:

Owner Contractual Correspondence

Company Name: Essar Oil Limited

Street Address:(1) K.K. Marg

Essar House, P.O. Box No. 7945

Mailing Address:(2) Mahalaxmi

City, Province/State, Country: Mumbai 400034 India

Attention: Mr. Robert Kuiperi - Sr. VP. - Commercial

Telephone No: 91-22-6660-1100

Fax No: 91-22-2495-4674

E-mail: [email protected]

Owner Technical Correspondence(4)

Company Name: Same as above

Street Address:(1)

Mailing Address:(2)

City, Province/State, Country:

Attention: Mr. D.K. Shukla, Sr. VP. - Commercial, Mr. S..K. Pal, VP. - Commercial,

Telephone No: 91-22-6660-1100

Fax No: 91-22-2495-4674

E-mail: [email protected], [email protected]

(1) Provide for courier delivery. Courier services will not deliver to post office box addresses. (2) Provide if different from street address. (3) If delivery of bound Schedule A books is to a different address or recipient, provide information as

required. (4) If address is the same as above, write “same as above”.


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Owner Project Specifications/Bound Schedule A Books(3) (4)

Company Name: Same as on previous sheet

Street Address:(1)

Mailing Address:(2)


Attention: Mr. S.K. Pal, Sr. VP. - Commercial

Telephone No: 91-22-6660-1100

Fax No: 91-22-2495-4674 or 91-22-2496-0434


Owner Invoices (4)


Street Address:(1)

Mailing Address:(2)


Attention: Mr. Robert Kuiperi, Sr. VP. - Commercial

Telephone No: 91-22-6660-1100

Fax No: 91-22-2495-4674





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b. Correspondence to Contractor relating to this project should be directed as follows:

Contractor Contractual Correspondence

Company Name: To be provided later

Street Address:(1)

Mailing Address:(2)


Attention:

Telephone No:

Fax No:

E-mail:

Contractor Technical Correspondence(4)

Company Name: Same as above

Street Address:(1)

Mailing Address:(2)


Attention:

Telephone No:

Fax No:

E-mail:




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Contractor Project Specifications/Bound Schedule A Books(3) (4)


Street Address:(1)

Mailing Address:(2)


Attention:

Telephone No:

Fax No:

E-mail:


required. (4) If address is the same as on the previous sheet, write “same as on previous sheet”.


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c. Correspondence to UOP relating to this project should be directed as follows:

Contractual Correspondence

UOP LLC (Des Plaines)

Company Name: UOP LLC

Street Address: 25 East Algonquin Road

Mailing Address:

City, Province/State, Country: Des Plaines, IL 60017-5017 USA

Attention:

Telephone No:

Fax No:

E-mail:

UOP Ltd. (Guildford)

Company Name: UOP Ltd.

Street Address:

Mailing Address: "Liongate", Ladymead

City, Province/State, Country: Guildford, Surrey, GU1 1AT, England

Attention:

Telephone No:

Fax No:

E-mail:

Technical Correspondence

UOP LLC (Des Plaines)

UOP Ltd. (Guildford)

Attention: Mr. Daniel Weiler

Telephone No: 847-391-2333

Fax No: 847-391-2758



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d. Correspondence Numbering and Copies If technical correspondence is to be numbered, indicate the numbering system below: Correspondence

From Owner to UOP: _-ES/UOP-31-xxxx

From UOP to Owner: _UOP/ES-31-xxxx

From Contractor to UOP: _-TH/UOP-31-xxxx

From UOP to Contractor: _-UOP/TH-31-xxxx

Numbering will be consecutive without regard to correspondence type (letter, fax or e-mail) Indicate any special instructions relating to correspondence below:

Prefix "E" for e-mail, "F" for fax, "L" for letter by mail/carrier, "T" for transmittal, "M" for minutes of meeting. E-mails, faxes, and letters would be sequentially numbered; eg. E-ES/UOP-31-0001, F-ES/UOP-31-0002. Transmittals would be sequenced separately starting with 0001. Minutes of Meeting would be sequenced separately starting with 0001.

e. Notes of Meetings

The host party will generally be responsible for summarizing, in "Notes of Meeting," any discussions, decisions, etc. which occurred during a meeting. The "Notes of Meeting" will be distributed to the attending parties, using a transmittal cover letter numbered in accordance with the correspondence numbering instructions specified above. If further "Notes of Meeting" requirements are to be considered, indicate below: All technical "Minutes of Meeting" to be sent to owner and contractor.

f. Notes of Telephone Conversation

The originating party will be responsible for summarizing, in a confirming e-mail, fax, or letter, any discussions, decisions, etc. which occurred during a telephone conversation.


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1.4 Electronic Distribution of Specifications **

a. Method of Electronic File Transfer

UOP will furnish the piecemeal release of our specifications across a secure Internet connection using a server named SPOTS (Secure Private On-line Transfer System). The SPOTS server allows the Owner and/or Contractor to download the files, using any available Internet Service Provider (ISP) with reasonable download speeds. In order to assure security the SPOTS server uses a two level approach. On the first level, there are secure sockets that provide a secure path between your web browser and our server. Once the path is established, a Citrix ICA security system is utilized. The combination of these two technologies produces a 40 bit within 40 bit security, which provides a high level of protection while taking advantage of the Internet. IN ORDER FOR SPOTS TO FUNCTION CORRECTLY EACH USER HAS TO ASSURE THAT THEIR NETWORK ALLOWS THE USE OF BOTH SECURE SOCKETS (SSL) AND CITRIX ICA.

The interface itself is simple. UOP provides the Owner and/or Contractor with an IP address that is typed into a web browser connecting to the Internet. The Owner/Contractor will then log in with a provided username and password. The system works with either Internet Explorer or Netscape Navigator and provides a means for UOP to release project documents without the delays usually associated with release and delivery of paper documents. WE RECOMMEND THAT EACH USER TRY THE SYSTEM PRIOR TO A SCHEDULED RELEASE TO ASSURE THAT THEIR NETWORK SETTINGS AND CONNECTION ARE ADEQUATE TO DOWNLOAD THE INTENDED INFORMATION. UOP provides this standard service in place of the hard copy piecemeal release.

SPOTS Contact Information: UOP Attention: Bill Walter Tel. No: 847 – 391 – 2143 Fax No: 847 – 391 – 2758 E-mail [email protected] Owner Attention: Mr. S.K. Pal, Mr. D.K. Shukla Tel. No: 91-22-6660-1100 Fax No: 91-22-2495-4674 E-mail [email protected]; [email protected] Contractor Attention: Tel. No: Fax No: E-mail

b. Types of Electronic Files

1. Application and PDF Files

Files are electronic versions of the specifications. The file when printed will be the same as the hard copy and will be provided in whichever of the following available formats: Excel, Word, PDF, or Microstation.

2. Data Files

Data files are fixed formatted files that supply the data from the specification in a format that can be automatically loaded into a database. UOP will provide these files as either XML or EXCEL along with a definition of the data fields; however, the Owner/Contractor is responsible for mapping and loading into the desired database.


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Data Format and Order

UOP can furnish XML formatted data files for the following specifications.

Specification Number

Title

103 Utility Summary 401 Tubular Exchangers 402 Air Cooled Exchangers 501 Centrifugal Pumps and Drivers

502 Reciprocating Pumps and Drivers 503 Proportioning Pumps and Drivers 506 Sealless Pumps and Drivers 508 Centrifugal Compressors & Drivers 509 Reciprocating Compressors & Drivers 510 Rotary Compressors & Drivers 807 Pressure Relief Valves

UOP can furnish an Excel workbook, containing a spreadsheet of tabulated instrument data for each of the following specifications:

Specification Number

Title

602 Pressure Gauges

603 Pressure Instruments

604 Differential Pressure Instruments

605 Primary Flow Elements (Differential Pressure Type)

606 Thermocouples and Wells

607 Resistance Elements (RTD) and Wells

608 Thermometers and Wells

612 Level Instruments (Displacement or Float Type)

616 Control Valves

623 Control Center Equipment

687 Integral Flow Meters (Differential Pressure Type)


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3. Requirement for Electronic Distribution of Specifications

Please indicate below the requirement for electronic distribution of the intermediate (piecemeal) release of the Engineering Design Specifications.

Issue Application Files to Owner**

Issue Application Files to Contractor**

Issue Application Files and Data Files to Owner

Issue Application Files and Data Files to Contractor

Electronic file transfer via SPOTS is not applicable; hard copy release is required.

c. Electronic Distribution of UOP Specification by recipient

Additional electronic distribution of UOP Specifications and other confidential UOP documents to third parties with appropriate confidentiality agreements should be through a secure virtual private network connection similar to the SPOTS connection used by UOP.

1.5 Computer Aided Drafting (CADD) Files UOP can furnish Microstation CADD files (.dgn format) for Process Flow Diagrams, Piping and Instrument Diagrams, mechanical/structural diagrams, and most vessel and internals drawings in MicroStation (.dgn format) as part of our Electronic Distribution of Specifications as described in Section 1.4. Microstation is UOP’s CADD Standard. If required, UOP can provide a translated copy of the drawings in an alternative format. Some minor differences in the graphical display of the drawings may be lost in the translation of the Microstation files but can be provided for your use. Therefore, these alternate formats should not be considered an official release of our drawings. If CADD files are required in an alternate format, please indicate the timing for this distribution, and CADD file format:

a. Timing for the Distribution of CADD Files in alternate format

CADD files in an alternate format are not required** CADD files in an alternate format are required with the initial release of drawings CADD files in an alternate format are required with the bound copies of the Engineering Design

Specifications. CADD Files in an alternate format are required with initial release of drawings

b. Alternate File Format (Please select only if different than Microstation (.dgn file format))

Auto CADD (.dwg file format, please indicate version required – versions 10 thru 2005 only) 2000 or lower

Initial Graphics Exchange Specification (IGES) Data Exchange Format (.dxf file format)

Auto CADD


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c. Method of Transmission

UOP will release these files using the SPOTS server described in section 1.4, above. If the information is required via an alternate media such as a CD ROM, please describe below:

All drawings to also be transmitted in pdf., Microstation and AutoCad formats for SPOTS. CD Rom required with final Schedule A release.

1.6 Hard Copy Distribution of Specifications

a. Piecemeal Copies

UOP does not release both printed and electronic versions of the piecemeal distributions. If the electronic transfer of piecemeal releases is not acceptable, UOP will release up to a total of four printed piecemeal copies of the Engineering Design Specifications. If the electronic transfer of piecemeal releases is not acceptable, please indicate below how many piecemeal copies are required. Number of copies required Piecemeal

Issued to Owner 0

Issued to Contractor 0

Others (see below) 0

b. Bound Copies

At the conclusion of the basic engineering, UOP will furnish up to a total of four bound copies of the Engineering Design Specifications.

Number of copies required Bound

Issued to Owner 8

Issued to Contractor 0

Others (see below) 0


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Other User(s):

Company Name:

Street Address:(1)

Mailing Address:(2)


Attention:

Tel.No:

Fax No:

E-mail:

(1) Shipping services will not deliver to post office box addresses. (2) Provide if different from street address.

c. Drawings

UOP’s Standard largest drawing is size A1. UOP will provide Piping and Instrument Diagrams as one-half size with only one A1 full-size copy furnished unless specifically instructed otherwise. Indicate any special requirements below:

Use UOP Standard Numbering.


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1.7 Unit, Equipment, and Instrument Numbering UOP unit, equipment, and instrument numbering system will be used, unless instructed otherwise. If a different equipment numbering system is preferred, indicate preference below and provide two copies of detailed instructions (in English) defining the numbering system required. The UOP numbering system is made up of a four part designation in the form of “T-CIP” where: “T” - unit number per Section 1.7a below “C” - equipment or instrument classification per BEDQ Sections 1.7b “I” - equipment or instrument number (1,2,3 . . . for each equipment type) or (001,002, 003 . . .

for each instrument type) per BEDQ Sections 1.7 c & d “P” - spare or parallel equipment identifier (A, B, C . . . etc.) a. Unit Numbering:

The UOP numbering system is by process unit. The UOP system uses a 3 or 4 digit numerical prefix followed by a hyphen. For example:

UOP Naphtha Hydrotreating Process Unit (200-)

Platforming Process Unit (300-)

Use UOP unit numbering system ** Use Owner unit numbering system as described below or in an appendix:

Unit Numbers as follows: Unit 13700 VGO Unionfining Unit 1 Unit 13800 Distillate Unionfining Unit 1 Unit 24100 Kerosene Merox Unit 13900 Kerosene HDT


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b. Equipment Classification

UOP uses a 1 to 3 character identifier for each equipment classification per the following table: -B Boilers -C Compressors, Blowers, Fans (including Drivers) -E Exchangers: Shell & Tube, Hair Pin -EA Exchangers: Air Cooled -H Heaters: Fired, Electric, Storage Tank -J Ejectors, Jets -ME Miscellaneous: Including Filters, Flame Arresters, Conservation Vents,

Mixers, Silencers, Packaged Units -P Pumps (including Drivers) -PRV Pressure Relief Valves -R Reactors -SN Sample Number; Sample Point Identification Number -T Cooling Towers -TK Storage Tanks, LPG Spheres, Bullets -V Vessels: Including Columns, Drums, Receivers, Miscellaneous Injection

Tanks -YYY Instruments: Refer to Section 1.7d

Use UOP equipment classification table ** Use Owner equipment classification system as described below or in an appendix:

See Appendix 2 for EOL equipment classification considered for the projects.


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c. Equipment Numbering UOP uses a 1 or 2 digit number, starting with 1 for each type of process equipment. For example: Stripper - XXX-V1 Splitter - XXX-V2 Charge Heater - XXX-H1 where XXX represents the unit number prefix.

Use UOP equipment numbering table ** Use Owner equipment numbering system as described below or in an appendix:

See Appendix 2.

d. Instrument Numbering The UOP instrument numbering system will be by category with all function items in a category sequentially numbered, starting with 001. Instrument function symbols will be in accordance with the Functional Identification of Instruments table on the P&ID Legend. All function items for a process service and associated instrument loop will be have the same number. A dash is used in the prefix and as a delimiter. For example: XXX -FT-001 XXX -FIC-001 XXX -FY-001 XXX -FV-001 XXX -PT-001 XXX -PI-001 XXX -LSH-001 XXX -LAH-001 XXX -TE-001 XXX -TI-001 XXX -TI-002 XXX -TI-003 where XXX - represents the unit number prefix. The instrument number of items identified with the same function description in a process service will have a suffix of A, B, C, etc., as required.

Use UOP instrument numbering system ** Use Owner instrument numbering system as described below or in an appendix:

See Appendix 3 for numbering system. Use UOP standard identification table for instruments.


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1.8 System of Measurement

UOP Engineering Design Specifications will be prepared in accordance with the requirements of the Engineering Agreement. Engineering Design Specifications will be issued in the chosen system of measurement, with the exception of piping sizes, pipe classes, UOP Standard Specifications and UOP Standard Drawings which will use the English system of measurement.

The following table indicates the internationally accepted dimensional units for common properties in each system of measurement. If special instructions relating to the chosen system of measurement are required, these instructions must be clearly marked on the appropriate table below. However, no alteration will be permitted to the internationally defined base conditions for liquids and gases. In the desired column of units below, change any individual unit first. Then choose one of the systems of measurement at the top of the column:

MKS English ** MKS SI

Temperature °F °C °C

Pressure (gauge) psig kg/cm²(g) kPa(g) Pressure (absolute)

psia kg/cm²(a) kPa(a)

Mass lb kg kg

Volume ft³ m³ m³

Length ft m m

Alternate Length in mm mm

Liquid Relative Density sp gr T°F/60°F sp gr T°C/15°C sp gr T°C/15°C Liquid Absolute Density °API or lb/gal @ 60°F kg/m3 at 15°C kg/m3 at 15°C

Vapor Flowing Density lb/ft³ kg/m³ kg/m³

Flowing Quantities

Mass lb/h kg/h kg/h

Vapor ft³/s m³/h m³/h Liquid

US gpm m³/h m³/h

Standard Quantities Vapor

106 std ft3/day at 60°F and 14.696 psia

normal m3/h at 0°C and 1.033 kg/cm2(a)

std m3/h at 15°C and 101.325 kPa(a)

Liquid bpd at 60°F std m3/h at 15°C std m3/h at 15°C

Enthalpy Btu/lb kcal/kg kJ/kg

Heat Rate mm Btu/h mm kcal/h MW

Electrical Power Hp kW kW

Viscosity cP cP cP Note: Units of measurement for instrumentation are defined in BEDQ Section 6.3.


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2. Design Philosophy 2.1 HAZOP

Safety is a key element in the design of UOP technologies. Design safety is continuously reviewed and improved through customer feedback, experience, and formal hazard reviews, such as HAZOPs. Although hazard reviews have been conducted on prior UOP designs, HAZOP sessions and reports are not included in the Schedule A. If you are interested in additional UOP hazard analysis (HAZOP) services or information about these services, contact your UOP representative.

2.2 Critical Service Rotating Equipment

Critical service steam or power driven equipment is defined as equipment in that service which must be maintained in the event of power failure, in order to protect personnel, equipment, or catalyst. UOP Engineering Design Specifications for drivers of rotating equipment will follow this definition as much as possible.

UOP design criteria are acceptable ** Alternate design criteria are:

Essar requires UOP to design equipment which needs steam out by LP steam for vacuum conditions.

2.3 Vacuum Design

UOP specifies vacuum design conditions for all equipment that normally operates under vacuum conditions, or is subject to startup, shutdown and/or regeneration evacuation. UOP also specifies vacuum design conditions for vessels and heat exchangers which normally operate liquid full and can be blocked in and cooled down, and for fractionators and associated equipment that can undergo a vacuum condition through the loss of heat input. UOP uses winterizing temperature (see Section 4.1) to determine requirement for vacuum design due to loss of heat input to a column. The vacuum design requirement does not apply to the cold side of heat exchangers in cooling water or seawater service. UOP does not design for vacuum due to blocking in after steamout or any other operator mis-operation.


Essar requires UOP to design equipment which needs steam out by LP steam for facuum conditions


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2.4 Design Temperature and Pressure

UOP normally uses the following general design guidelines as well as operational and technology specific guidelines to specify design temperatures and pressures. Design pressures are based upon estimated unit hydraulics.

• Set design pressure a minimum of 25 psi (1.75 kg/cm2) above maximum normal operating pressure

with 50 psig (3.5 kg/cm2 (g)) as a minimum design pressure for low pressure equipment. • Set design temperature a minimum of 50°F (28°C) above maximum normal operating temperature

with 250°F (120°C) as a minimum design temperature for low temperature equipment. • Set design pressure at 110% of maximum normal operating pressure when operating pressure is

above 250 psig (17.5 kg/cm2(g)).

• Set design pressure for equipment that can be blocked in down stream of pump, equal to estimated pump shutoff pressure; i.e. maximum suction pressure generally under relieving conditions plus 1.25 times the pump rated differential pressure.

UOP design criteria are acceptable** Alternate design criteria are:

2.5 Tankage

Offsite tankage will be the responsibility of the Detailed Design Contractor, unless otherwise defined in the UOP scope of work. The requirement for gas blanketing of feed storage tanks will be indicated in the UOP Engineering Design Specifications where required to eliminate oxygen contamination.

Where tanks are required as part of the process design package, UOP will specify them according to the applicable codes as follows: Atmospheric Storage Tanks – API-650 Pressurized Storage Tanks

– Low Pressure ( Design Pressure <= 15 psig) – API-620 – High Pressure ( Design Pressure >15 psig) - ASME Section VIII

UOP will follow its normal practices for determining size, type, appurtenances, etc. Tanks will not necessarily be specified according to design criteria provided in Section 5.2, Vessels, of this BEDQ. Please list any specific requirements below: Nitrogen shall be used for blanketing tanks.


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2.6 Heat Recovery UOP selects and specifies steam generation and heat recovery facilities based upon process and economic considerations. UOP specifies steam generation equipment per ASME Section 1, “ASME Boiler and Pressure Vessel Code.”


2.7 Typical Equipment Layout

UOP Engineering Design Specifications for new process units will include UOP Standard Specification 9-51 (Plot Plan Design Criteria for Process Units), Project Specification 999 (Typical Equipment Layout), and a Typical Equipment Layout Drawing indicating a suggested arrangement of process equipment typically found in the subject unit. The equipment shown may differ from that of the specific unit. UOP will also provide a single review of the plot plan developed by the Detailed Design Contractor. This review is limited to process considerations only.

2.8 Unit Turndown

a. Short-term, Temporary Turndown

UOP reviews process unit hydraulics and fractionator tray layouts for short-term, temporary turndown operation. Indicate desired turndown capacity based on the governing case for each piece of equipment:

60% of unit design throughput ** 50 % of unit design throughput

50


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b. Long-term, Planned, Extended Turndown

UOP generally does not design process units or equipment for long-term, planned, extended, turndown operation. Long-term planned turndown typically involves equipment modification or addition and is considered a separate design case involving extra engineering man-hours, which shall be defined in the Engineering Agreement. Indicate the requirement for long-term, planned, extended turndown.

Long-term, planned, extended turndown is not a design requirement ** Long-term, planned, extended turndown at is a design requirment % of unit design throughput is required

NR Indicate modification that will be expected/allowed for the long-term, planned, extended turndown operation (e.g. trimmed pump impellers, fractionator tray blanking strips, parallel control valves, etc.):

2.9 Toxic Chemical Handling UOP Engineering Design Specifications will incorporate the design and equipment provisions listed below in order to reduce emissions of benzene, a known carcinogen, and other potentially hazardous chemicals. a. The minimum requirement for using closed, flow-through sample container systems is all process

streams containing any of the following:

• 0.1 % (weight) or more of benzene or any chemical considered carcinogenic as determined by any of the organizations listed in note 2.

• 1% (weight) or more of toxic chemicals as determined by UOP • 25% (weight) or more C6 through C9 aromatics

b. The minimum requirement for using a closed, aromatics collection system is all process streams containing any of the following: • 1 % (weight) or more of benzene or any chemical considered carcinogenic as determined by

any of the organizations listed in note 2. • 25% (weight) or more C6 through C9 aromatics A closed, aromatics collection system applies to the following equipment:

- Vessel drains; - Control valve drains; - Gauge glass/level instrument drains; - Pump drains; - Other equipment where sparing and/or valving are provided for routine maintenance and

equipment removal.


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c. See Section 5.6.c for pump seal requirements for handling toxic materials d. Water streams saturated with aromatics are to be directed to suitable locations within the process

whenever possible, or to appropriate other processing or treating facilities in order to minimize aromatic emissions to the environment.

Notes (for section 2.9): 1. General

Several factors may influence the aromatics exposure levels encountered in a processing facility and cause them to differ from location to location, even though the same process design is used. For example, maintenance, sampling, and "housekeeping" practices, as well as governmental regulatory requirements may vary from plant to plant.

Furthermore, compliance with environmental and occupational exposure regulations for subject facility is the responsibility of the Owner and not UOP. Consequently, if Owner has special regulatory constraints, or has relevant aromatics emission or exposure monitoring data, or other basis to justify different design provisions and desires deviation from UOP policy, please submit such a request and clearly delineate those different design provisions by separate written communication signed by the Project Manager or designated authority. UOP shall reply promptly to this request; however, this does not imply that UOP will automatically accept such deviations to UOP policy.

2. Organizations determining carcinogenicity of substances: U.S. Occupational Health and Safety Administration (OSHA), U.S. Environmental Protection Agency (EPA), International Agency for Research on Cancer (IARC), U.S. National Toxicology Program (NTP), American Conference of Governmental Industrial Hygienists (ACGIH), National Institute of Occupational Safety and Health (NIOSH), and other national organizations as appropriate.

2.10 Noise Level Limitations

The Engineering Design Specifications for equipment and the final plant layout can be impacted by personnel noise level exposure limitations. In general, UOP is guided in this area by applying commonly accepted USA practices and guidelines provided by the Occupational Safety and Health Administration (OSHA). The Detailed Design Contractor is responsible for final purchased equipment noise levels and noise attenuation provisions.


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2.11 Metallurgy

UOP specifies metallurgy based upon that required for process considerations.


2.12 Steam System

Systems may be identified in general terms such as High Pressure (HP), Medium Pressure (MP), Low Pressure (LP), etc., or as nominal pressure levels [e.g. 600 psig, 40 kg/cm2(g), etc.] or in any other suitable terms. Definitions MINIMUM describes the lowest steam pressure and temperature expected in the process area header during normal operation. NORMAL describes the average or typical steam pressure and temperature expected in the process area header during normal operation. MAXIMUM describes the highest steam pressure and temperature expected in the process area header during normal (non-relieving) operation. DESIGN describes pressures and temperatures used for the mechanical design of piping and equipment - excluding steam generation equipment designed under the provisions of the American Society of Mechanical Engineers (ASME) Boiler and Pressure Vessel Code, Section I. These conditions are particularly important if matching existing equipment or design is done by others. How This Information is Used Steam consuming equipment connected to a steam header will in general be specified based upon the minimum steam conditions and reviewed for satisfactory operation anywhere between the maximum and minimum steam header conditions. Normal steam conditions will be used for utility estimates, heat and weight balances, etc. Steam generating equipment connected to a steam header will, in general, be specified based upon the maximum steam conditions and reviewed for satisfactory operation anywhere between the maximum and minimum steam header conditions. Design conditions will be considered to establish relief valve set pressures and mechanical design.


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3. Utility Information

3.1 Steam System a. Process Area Header Conditions during normal operations in the Process Area.

Steam System

Operating Pressure: kg/cm²(g)

Operating Temperature: °C

Mechanical Design

Conditions:

Incremental

Value: Identification*

Min

Norm

Max

Min

Norm

Max Press:

kg/cm²(g) Temp:

°C $/MT

HHP Steam 21.2

HP Steam 37 37.5 38 390 395 400 42/FV 415 20.6

MP Steam 12 12.3 12.5 240 260 275 14.2/FV 290 19.4

LP Steam 3.5 4.0 4.5 sat. 190 230 6.5/FV 245 18.2

*List sequentially from highest pressure level to lowest pressure level. Labels may be changed as necessary. b. Define any limitations on the availability of steam.

3.2 Condensate Return Systems

Destinations for two-phase condensate from steam traps or control valves at steam heated exchanger outlets.

Steam Source Designation

Condensate Destination or Designation

Grade Level Battery Limit

Pressure: kg/cm²(g)

Incremental Value:

Refinery HP Steam Header Condensate flashed to recovery 5.0

Refinery MP Steam Header Condensate flashed to recovery 5.0

Refinery LP Steam Header Condensate returned to system 0.5

Destinations for all liquid condensate from steam surface condensers or condensate pumps.

Condensate Destination

Grade Level, Battery Limit Pressure: kg/cm²(g)

Incremental Value: ____

Condensate Recovery 5.0


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3.3 Process Water and Boiler Feedwater

DM Water Supply (1), (4)

Deareated Treated Boiler Feedwater (2), (3), (4)

Potable Water

Description BFW

Supply Header Maximum N/A

Operating Normal 5.0 52.0 5.0

Pressure: kg/cm²(g) Minimum

Supply Header Maximum N/A

Operating Normal <50 105 ambient

Temperature: °C Minimum

Mechanical Pressure: kg/cm²(g) 10.0 68.0 10.0

Design Conditions: Temperature: °C 400 150 65

Metallurgy of Existing System

pH >9.0

Total Hardness as CaCO3: wt ppm NA <0.02 mval/kg

Total Alkalinity as CaCO3: wt ppm N/A

Chloride as Cl: wt ppm <0.1

Total Dissolved Solids: wt ppm Desal Water

Suspended Solids: wt ppm

Conductivity: micromhos/cm <1.0


Chlorine: wt ppm (1) Must be from a service where the potential of hydrocarbon contamination is nil. (2) Can the listed boiler feedwater be used for direct contact steam desuperheating? The

recommended maximum total dissolved solids is 5 ppm; the recommended maximum conductivity is 20 micromhos/cm at 68°F (20°C).

Yes No

(3) Provide information (pressure, temperature, etc.) on alternate source of water for desuperheating if

boiler feed water is not acceptable. (4) Mechanical design pressure is estimated maximum discharge pressure of supply pumps at shutoff

conditions.


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3.4 Cooling Water

Description Circulating Cooling

Water Once Through Cooling

Water Source Sea water (salt) (4) (4)

Process Battery Limit Supply Pressure: kg/cm²(g) (1) 4.5

Pressures at Grade: Return Pressure: kg/cm²(g) (1) 3.5

Exchanger Inlet Water Temperature: °C

32

Maximum Exchanger Outlet Water Temperature: °C 44

Exchanger Water Side Pressure: kg/cm²(g) 10.0

Mechanical Design Conditions: Temperature: °C (2) 65.0

Metallurgy of existing system (3) CS with cement lining


Flow rate available over present use: m³/h

Total Suspended Solids (TSS), wt ppm

(1) These conditions are not necessarily the conditions at the inlet or outlet connections of equipment. (2) The minimum mechanical design temperature specified by UOP is 250°F (120°C). (3) See BEDQ Section 5.4,h, Shell and Tube Heat Exchangers metallurgy. (4) Indicate type of cooling water (salt, fresh, brackish, etc).


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3.5 Fuel Oil System

a. Fuel Oil System Data

Property Operation Mode

Blended FCC Slurry and LOC

Supply Header Maximum 15

Operating Normal 12 Pressure: kg/cm²(g) (1) Minimum

Return Header Maximum

Operating Normal 2.5 Pressure: kg/cm²(g) Minimum


Operating Normal 200 Temperature: °C Minimum (2), (3)

Mechanical Design Pressure: kg/cm²(g) 22

Conditions: Temperature: °C 240 Incremental Value, ____

Fuel Oil Properties °Specific Gravity 1.044 Net Heating Value: kcal/kg (4) 9300

Viscosity: cSt at 50 °C (5) 34.8 cSt at 100 °C 3.8 Vapor Pressure: kg/cm²(a) at °C

Flash Point: °C 79 Pour Point: °C 32

Sulfur: wt% 0.5

Nitrogen: wt ppm Vanadium: wt ppm 1.0 Sodium: wt ppm

Nickel: wt ppm 1.0 Iron: wt ppm

Ash: wt%

Other wt% or (wt ppm) Impurities: wt% or (wt ppm)

Particulates (6): See Fuel Oil System Notes, BEDQ Section 3.5,b.


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b. Fuel Oil System Notes

The Contractor is responsible for the circulating oil header design. UOP Project Specifications are based on the following:

(1) Fuel oil supply header is controlled at a minimum pressure of 145 psig [10 kg/cm2(g)].

(2) A fuel oil temperature is maintained consistent with a viscosity of 20 cSt maximum at the

burner.

(3) Estimated fuel oil temperature drop is 10°F (5°C) in individual heater supply lines including heat losses from flanges and flexible hoses.

(4) The net heating value will be calculated by UOP based on API value provided.

(5) Providing one viscosity value at 210°F (100°C) is acceptable.

(6) The circulating fuel oil shall have passed through a strainer with screen perforation size

of 80 mesh. 3.6 Fuel Gas System

a. Fuel Gas System Data

Property Operation Mode

Refinery Fuel Gas (Design Case)

Natural Gas

(Design Case)

Sat Gas LPG

(Check Case)

Supply Header Maximum 5.0

Operating Normal 4.0

Pressure: kg/cm²(g) Minimum 3.5


Operating Normal 40

Temperature: °C Minimum

Mechanical Design Pressure: kg/cm²(g) 10

Conditions: Temperature: °C 150

Incremental Value:

Net Heating Value: * kcal/kg

Specific Gravity (Air = 1.00):

Total Sulfur: vol ppm 100 200 30

Nitrogen: wt ppm

Chloride: vol ppm

Other Vol%

Impurities: Vol%


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* Net heating value will be calculated by UOP based on gas composition provided.

b. Fuel Gas Composition

c. Fuel Gas System Requirements

The UOP Schedule A includes a specification for a fuel gas preparation system. UOP considers this system essential to good long term performance with low NOx burners. The system minimizes the potential of coke formation and scale plugging of burning tips and subsequent performance and burner maintenance problems.

Composition Operation Mode

(Volume %) Refinery Fuel Gas Natual Gas Sat Gas LPG

H2O 0.1

O2

N2 0.5

CO

CO2

H2S 50 vppm 100vppm 50vppm

H2 18.1 0 0.8

C1 46.5 98.8 0.3

C2= 5.0

C2 23.0 0.7 4.4

C3= 0.5

C3 4.2 26.6

C4= 0.1

iC4 1.6 15.0

nC4 1.0 52.7

C5=

iC5

nC5 0.1

C6+

Total 100 100 100


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The UOP system consists of a liquid knockout drum followed by a fuel gas coalescer, and a fuel gas heater. In the UOP specification, the detailed engineering of this system is left to the contractor, since the details will depend on the geographical placement of heaters relative to each other and the potential existence of existing fuel gas preparation facilities which could be extended to serve the new or revamped units.


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3.7 Electrical Power

a. Voltage:

Motor Power Range:

kW

(Provide motor power from lowest to highest)

Nameplate Voltage:

Phase:

Frequency:

(Hertz)

From: Through: >0.18 <=160 415 VAC 3 50

>160 6600VAC 3 50

UOP specifies motors with less than 1 horsepower (0.75 kW) as single phase, 120 volts (60 Hertz systems) or 220 volts (50 Hertz systems).


as indicated above

b. UOP specifications are based on a reliable electrical power system.

UOP design criteria are acceptable ** If the system is not considered reliable, indicate the average number of power failures per year:

Indicate any special provisions needed to compensate for the lack of system reliability.

c. Indicate any unusual environmental considerations for motor enclosures and insulation, such as

tropical, salt, low/high ambient temperatures, dust, etc.

Tropical - high humidity (salt & dust)

d. Indicate the incremental value of electrical power: 6.5* US cents per kW-h.

*RS 3.00

e. Electrical power information for the instrument power distribution system is provided in BEDQ Section 6.9, Electrical Power.


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3.8 Plant and Instrument Air a. Process Area Header conditions during normal operations.

Plant Air Instrument Air

Available Extra Capacity, m³/h as required as required

Will System Furnish Oil-Free Air? yes

Dew Point, (at header conditions): °C saturated -40

Minimum Operating Pressure: kg/cm²(g) 6.0 6.0

Normal Operating Pressure: kg/cm²(g) 7.5 7.0

Maximum Operating Pressure: kg/cm²(g) 8.5 8.0

Mechanical Design Pressure: kg/cm²(g) 12.0 12.0

3.9 Nitrogen

a. Is nitrogen available from a refinery header? Yes No

b. If yes, provide header pressures:

Minimum Operating Pressure: kg/cm²(g)

Normal Operating Pressure: kg/cm²(g) 7.5

Maximum Operating Pressure: kg/cm²(g) 9.0

Mechanical Design Pressure: kg/cm²(g) 12.0

c. Composition (Volume %) - Please confirm nitrogen composition as given below can be provided.

Available ** Alternate

N2 99.5% minimum 99.0 O2 20 ppm maximum* <5 CO 20 ppm maximum <5 CO2 20 ppm maximum <5 Other Carbon Compounds 5 ppm maximum 5

Chlorine 1 ppm maximum 1 H2O 5 ppm maximum 5 Hydrogen 20 ppm maximum 20 Noble Gases Remainder, ppm 49.9 N20 Ppm <20 5 Compounds Ppm <20 Total 100% 100%

*Note some Technologies will require a lower oxygen content or an independent source not connected to any other users.


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Provide any additional information on availability of nitrogen.

3.10 Caustic

Caustic Strength: wt% 20

Process Area Grade Level Battery Limit Supply Pressure: kg/cm²(g)

4.0

Process Area Grade Level Battery Limit Supply Temperature: °C

ambient

Mechanical Design Pressure: kg/cm²(g) 7.0 Conditions: Temperature: °C 65

Define any limitations on the availability of caustic.

3.11 Spent Caustic

Destination: spent caustic treating unit Destination Pressure: kg/cm²(g) 5.0


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3.12 Hot Oil System

Description

Supply Header Operating Pressure, (at grade): kg/cm²(g)

Return Header Operating Pressure, (at grade): kg/cm²(g)

Supply Header Operating Temperature: °C

Mechanical Design Pressure: kg/cm²(g)

Conditions: Temperature: °C

Commercial Product Name or Description

°API

Pour Point: °C

Flash Point: °C

Viscosity: cP at °C

Viscosity: cP at °C

Auto-Ignition Temperature: °C

Vapor Pressure: kg/cm²(a) at °C

Thermal Conductivity: kcal/(h-m-ºC)

Coefficient of thermal expansion: ppm/ºC

Specific Gravity at °C

3.13 Amine

Type: MDEA Concentration 40% wt in water solution mol CO 2/mol Amine mol H 2S/mol Amine Pressure (kg/c m2) Temperature ( 0C) Lean .003 .007 28 45 Rich 0.41 27 Resulting


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4. Site Information

4.1 Winterizing Temperature The extent of winterizing protection depends upon the severity of the local climatic conditions for a particular site. The extreme case of the lowest minimum temperature is not normally selected. In general, a winterizing temperature is selected for protection after rejection of a percentage of the lowest hourly temperature recordings in the coldest month or a percentage of the daily minimum temperature recordings for a year. Recordings are normally based on a period of years and not those of a single year. This temperature will be used to determine the objective heat tracing requirements for pour point and freeze protection. At a winterizing temperature of 32°F (0°C) or lower, protection for water freezing will be provided. Winterizing Temperature: 5 °C

4.2 Low Ambient Temperature The low ambient temperature is defined as the lowest mean atmospheric temperature for a 24 hour period. This temperature will be used for mechanical design considerations including determination of the Minimum Design Metal Temperature (MDMT) as required by the ASME Boiler Pressure Vessel Code, Section VIII, Division I. The MDMT may affect the final material selection, equipment design, and impact testing requirements. The MDMT must appear on the stamp or nameplate of all equipment that carries an ASME U-1 stamp. Provide as a whole number (no decimals). Low Ambient Temperature: 5 °C

4.3 High Ambient Design Temperatures a. Indicate dry bulb temperature to be used for air cooled exchanger design. UOP Practice is to use

the dry bulb temperature that is not exceeded more than 5% of the time during the four warmest months of the year:

41 °C

b. Indicate dry bulb temperature and relative humidity to be used for air blower and air compressor

design:

41 °C and 96 % relative humidity 4.4 Unit Elevation

Indicate the elevation of the refinery site above sea level: 31.5 m


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5. Equipment 5.1 Fired Heaters

a. Heat Recovery Options

(1) General Service Heaters

For general service heaters, UOP will typically design a flue gas outlet to process inlet temperature approach of 75°F (42°C). This results in an approximate fuel efficiency of 85% to 87% based on a process inlet temperature of 400°F to 470°F (204°C to 243°C).

UOP typically specifies air preheat systems when the simple payoff is less than about 3 years and the process heat duty is approximately 70 x 106 Btu/hr (18 x 106 kcal/hr) or greater.


(2) Large Reactor Charge Heaters (Platforming, Oleflex, Cyclar etc.)

High pressure steam generation systems will be specified with a nominal fuel efficiency of 90%.


Fired heaters will have 93% efficiency with APH.


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(3) Small Reactor Charge Heaters (Hydroprocessing, Isomar, Tatoray etc.)

Reactor heaters may be integrated with reboiler stream to obtain an approximate fuel efficiency of 85% to 87% without air preheat. UOP typically specifies air preheat systems when the simple payoff is less than about 3 years and the combined process heat duty is approximately 70 x 106 Btu/hr (18 x 106 kcal/hr) or greater.


b. Air Preheat Systems Combustion Air: UOP considers combustion air to be supplied by a fan, even when the air preheater is bypassed. Fan failure will result in shutdown of the heater. UOP will not specify provisions for automatic switchover to natural draft burner operation. A spare combustion air fan will be specified. A cold air bypass will be provided for stack temperature control and for heater operation at 100% of normal duty with the air preheater bypass. UOP specifies a single induced draft fan, since the stack is considered to serve the purpose of a spare. If the induced draft fan fails, the air preheater bypass will open to divert flue gas to the stack. Is it acceptable to combine more than one heater service in a common air preheat system?

Common air preheat systems are acceptable ** Separate air preheat systems are required

Common air preheat systems are acceptable Provide any additional requirements below:

Acceptable as a philosophy, but to be reviewed with ESSAR

c. Burners

(1) Burner Selection

In high temperature [process outlet temperatures greater than 700ºF (370ºC)] heater services with austenitic coils or small duties less than about 5 x 106 Btu/h (1.3 x 106 kcal/h), UOP may restrict the selection to gas firing only and select the type of burners and firing arrangement.


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However, for general service, indicate your preference:

Gas burners only ** Combination oil and gas burners

Gas burners only A pilot burner will be specified for each burner. UOP specifies flame rod type flame detectors for all burners. Other types of detectors are not recommended. Indicate your preference for flame detection equipment:

Flame Rods for forced and/or natural draft burners** Other type of flame detection equipment. Specify:

Indicate any additional requirements for the design and selection of burners:

(2) Nitrous Oxides (NOx ) Emissions

The table below shows the typical NOx emission levels (corrected to 3% O2 in flue gas (dry basis) from different types of burners. Changes in fuel composition, the presence of hydrogen, or air preheat temperature will affect the NOx emission levels.

Gas Firing at 15% Excess Air

Standard Burner 110 ppmv (225 mg/Nm3) Ambient Air 152 ppmv (312 mg/Nm3) Air Preheat Staged Air Burner 77 ppmv (158 mg/Nm3) Ambient Air 106 ppmv (218 mg/Nm3) Air Preheat Staged Gas Burner 61 ppmv (124 mg/Nm3) Ambient Air 83 ppmv (171 mg/Nm3) Air Preheat Ultra Low NOx Burner 39 ppmv (80 mg/Nm3) Ambient Air 53 ppmv (110 mg/Nm3) Air Preheat

Oil Firing at 25% Excess Air

Standard Burner 280 ppmv (575 mg/ Nm3) Ambient Air 386 ppmv (793 mg/ Nm3) Air Preheat Staged Air Burner 210 ppmv (431 mg/ Nm3) Ambient Air 290 ppmv (595 mg/ Nm3) Air Preheat

Typical burner emissions are based on methane gas firing or No. 6 oil fuel firing. Air preheat temperature is approximately 465°F (240°C).


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Staged gas burner is the low NOx choice for fuel gas only firing. Staged air burner is the Low NOx choice for combination firing.

Ultra Low NOx burners have poor flame quality and could adversely affect the heater operation (flame impingement, after burning) and result in higher maintenance. This option shall only be used for strict NOx regulation.

Note that the use of Low NOx or Ultra Low NOx burners can increase the size of the furnace or change the style of heater design. Specify maximum NOx emission level corrected to 3% O2 in flue gas (dry basis).

Gas Fired ppmv mg/m³ Oil Fired ppmv mg/m³

For NOx emission control, indicate your preference:

Low NOx burners are required ** Ultra Low NOx burners are required

Low NOx burners are required Provide any additional requirements below:

(3) Excess Air

Burners, convection sections and stacks will be designed for 15% excess air for gas firing and 25% excess air for oil firing. Burners as specified will be suitable for operation at lower excess air levels. Specifying the heater for lower excess air levels can limit the unit capacity due to the hydraulic limitation in the convection section and heater stack.


(4) Indicate any special requirements relating to flue gas emissions, such as SOx,

particulates, etc.

To meet the overall Refinery emission limit of 1T/hr SOx.


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(5) When FCC catalyst fines are present in the fuel oil, special hardened metallurgy will be

specified to prevent severe erosion to the oil guns.

FCC catalyst fines are not present ** FCC catalyst fines are present

Provide any additional requirements below:

FCC catalyst fines are present

d. Type of Tubes in Convection Section

UOP specifies finned tubes in both fuel gas and fuel oil firing. Studded tubes may be cleaned more effectively than finned tubes but studs may increase overall heater cost approximately 6%. Indicate type of tubes to be used in convection sections:

Gas Firing Only Oil or Combination Firing

Finned Tubes ** ** Studded Tubes N/A

Additional requirements are

Use studded tubes only in convection system

e. Soot Blowers

UOP specifies fully retractable soot blowers with sequential controllers for convection sections with finned or studded tubes for fuel oil firing.



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f. Heater Stacks

Individual stacks supported from each heater are required. ** Groups of heaters shall be ducted to a common central stack. One common central stack is required for all fired heaters.

Individual stacks supported from each heater are required.

UOP practice is to specify heaters with individual stacks. The use of a common stack for a group of heaters will normally be determined in the contractor’s detailed engineering phase when the detailed plot plan is finalized.

Indicate the required minimum stack height above grade: 60 m

Provide any additional instructions below.

Will review with ESSAR the use of common stacks

g. UOP specifies the use of ceramic fiber insulation for heater internal linings in the radiant section

for gas firing. Ceramic fiber can be used for No. 2 fuel oils and lighter. UOP does not recommend the use of ceramic fiber for heavier fuel oils or fuel oils with high levels of sulfur or heavy metals components. Indicate when the use of ceramic fiber insulation is required:

Fuel gas firing only ** Fuel gas or oil firing Ceramic fiber is not acceptable

Fuel Gas or oil firing h. UOP specifies skin thermocouples on Unicracking, Distillate Unionfining, and Oleflex charge

heater coils and on other services where thermal cracking, heavy fouling, or flow maldistribution may occur. UOP will provide a spare thermocouple through the same opening that can be connected should the primary thermocouple fail during operation.

UOP design criteria are acceptable ** Indicate if skin thermocouples are required in any other services. Spare thermocouples shall not be provided.

Skin TC's are required for all furnaces and space will be specified for critical service.


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i. UOP specifies the following instruments and connections:

(1) Draft gauge and connections: at burners, radiant section exits, above and below stack dampers (2) Flue gas sampling connections: at radiant section exits and below stack damper (3) Oxygen/combustibles analyzer and connection: at radiant section exits (4) Temperature measurement and connections: at radiant section exits and below stack damper

UOP design criteria are acceptable ** Indicate quantity and location of any additional instrument connections.

j. Indicate any additional requirements for the design and selection of fired heaters.

5.2 Vessels

a. Vessel Dimensions

Most vessels will be dimensioned to inside diameters using multiples of 6 inch and 100 mm increments for English and metric units, respectively. Some vessels 2’-6” (800 mm) or smaller and drop legs (drawoff boots) on horizontal vessels may be dimensioned in nominal pipe diameters. Normally, 2:1 elliptical heads will be specified. Hemispherical heads will be considered for some catalyst-containing vessels in high pressure services.



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b. Vessel Size Limitations

Specify any vessel size limitations required by local codes or transportation considerations that may impact upon unit design. This will include any known diameter or length limitations for shipping clearances of shop fabricated vessels and any height limitations for erected vessels.

There are no known size or weight restrictions ** Restrictions are as indicated below:

Outside diameter: 18.5 m

Overall Length: m

Height: m

Weight: kg c. Vessel Connections

Connections on vessels will be flanged. Large diameter connections (30” and larger) may be beveled for welding. Minimum connection size will be 1 inch. If this is not acceptable, provide additional requirements.


Minimum connection size should be 2".

(Note: Thermowell nozzle details are defined in BEDQ Section 6.4, Temperature Instruments.) For vessels constructed in accordance with a pressure vessel code, UOP normally specifies Class 150 flanges as a minimum. Exceptions are for thermowells and level instrument pipe column vessel connections which are specified with Class 300 minimum flanges. If there is a different minimum flange class requirement for specific nozzle sizes, indicate the minimum class and the nozzle sizes to which it is to be applied. Also indicate if there is a different minimum flange class requirement for specific services.

All instrument flanged connections to the pressure vessel shall be class 300 minimum.


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Should the above minimum flange classes be applied to additional equipment other than vessels?

(1) Shell and tube exchangers No** Yes (2) Air cooled exchangers No** Yes (3) Fired heaters No** Yes

Yes Yes Yes Indicate any additional requirements for vessel connections:

d. Vents and Drains

Vessels (or adjacent piping) will be provided with vents and drains in accordance with the following table:

Vessel Diameter Vent and Drain Size 15′ - 0" (4500 mm) and less 2" Over 15′ - 0" (4500 mm) through 20′ - 0" (6000 mm) 3" Over 20′ - 0" (6000 mm) 4"



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e. Manway Sizes and Placement The minimum manway size will be 18 inches inside diameter (of lining where applicable).

Vessels 2’6” (750mm) or smaller inside diameter may be specified with flanged heads. Larger size manways will be specified if required to accommodate internals.

18” ID manways (minimum) ** 20” nominal manways (minimum) Alternate manway size: 24" nominal

24" nominal In trayed columns, manways will be provided on the top head, below the bottom tray, at feed trays, at any other tray at which removable internals are located, and at intermediate points so that the maximum spacing of manways in the trayed section does not exceed 60 feet (18 meters). Columns specified with MD type trays require 24” (nominal) manways located at the side of the vessel.


Handhole if provided to be minimum 6".

On unlined horizontal vessels, a manway will be provided on the side of the vessel at or below the horizontal centerline. If the bottom half of the horizontal vessel is lined, the manway will be located on the upper side or the top of the vessel.



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~ ~

f. Ventilation Nozzles

UOP specifies horizontal vessels 10 feet (3000 mm) or over in tangent length with a blanked off ventilation nozzle on the top of the vessel near the end opposite the manway. UOP also specifies vertical vessels 10 feet (3000 mm) or over in tangent length with a blanked off ventilation nozzle on the top head unless two or more manways are specified at the top and bottom of the vessel respectively. Ventilation nozzles will be sized as follows:

Vessel Tangent Length

Ventilation Nozzle Size

10′ - 0" (3000 mm) through 15′ - 0" (4500 mm) 4" Over 15′ - 0" (4500 mm) through 25′ - 0" (7500 mm) 6" Over 25′ - 0" (7500 mm) 8"


g. Steamout Connections

UOP specifies steamout connections on vessels which are to be steamed out as part of the normal startup or shutdown operation. Steamout nozzles shall be the same size as vent and drain nozzles. The minimum size steamout nozzle will be 2". 2" Steamout nozzles will be provided with a gate valve and blankoff; steamout nozzles 3" and larger will be hard piped as indicated below. Steamout nozzles will be located on the heads of horizontal vessels and in the bottom section of vertical vessels.


All steam out connections will be hard piped as per sketch for 3" steamout.

~ ~

¾” P

2” Steamout (blank-off) 3” Steam


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h. Level Instrument Installation

UOP specifies vessel liquid level transmitter and visual level indicator installation on 2”diameter pipe columns attached to vessels with Class 300 (minimum) flanges. However the Class 300 (minimum) flange requirement does not apply to individual transmitters or indicators mounted on pipe columns or direct-connected to vessels. Each pipe column is limited to 15 feet (4600 mm) in length. Two or more overlapping pipe columns are specified for level transmitter or visual level indicator spans greater than 15 feet (4600 mm) in length. Each individual level transmitter and each individual visual level indicator is specified with upper and lower isolation gate valves. Pipe columns are specified without any isolation valving.

UOP design criteria are acceptable ** Alternate design criteria are as defined below or in an appendix:

Class 300 (minimum) flanges also required for liquid level transmitters and visual indicators directly connected to vessels.

i. Pressure Instrument Installation

UOP specifies pressure instrument installation on level instrument pipe columns where possible.


Separate nozzle required for pressure instrument installation

j. Indicate any additional requirements for the design of vessels:


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5.3 Trays and Packing

a. Tray Types

UOP normally specifies sieve trays for general fractionation service. Alternately, UOP may

specify multiple downcomer (MD) trays, valve trays or packing for specific services.


Valve trays to be specified.

b. Tray Metallurgy

In non-corrosive services UOP specifies carbon steel trays and, where applicable, Type 410

chromium alloy valve parts. In services where corrosive conditions exist during normal operation, UOP specifies alloy trays and alloy valve parts.


c. Tray Numbering

Trays will be numbered from top to bottom. ** Trays will be numbered from bottom to top.

Top to Bottom d. Tray Turndown

UOP normally specifies fractionator trays for the same turndown as indicated for the process units

(refer to BEDQ Section 2.8, Unit Turndown). However, in some services, the reflux rates and reboiler duties may not be turned down in proportion to the unit turndown when higher tray loadings are required to maintain desired efficiency.



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e. Tray Layouts

UOP may specify three-pass and four-pass trays where deemed appropriate.


f. Indicate any additional requirements for the design and selection of trays and packing:

UOP to use normal deisgn margins.

5.4 Shell and Tube Heat Exchangers

a. UOP specifies hairpin type exchangers (double pipe or multitube) where appropriate.


b. UOP normally specifies a nominal straight tube length for fixed tubesheet or floating head type

exchangers. For U-tube exchangers, the maximum nominal length (from tube ends to bend tangent) will be limited to the straight tube length.

Indicate the preferred nominal tube length:

20 feet ** 6.1 meters Other tube length: 6.0 m

6.0


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c. For killed carbon steel and low alloy (up to and including 5 Cr-1/2 Mo) tubes, indicate:

(1) Preferred outside diameter ¾ inch ** 19.05 mm

1 inch 25.4 mm

19 mm 20 mm

25 mm Other: mm

(2) Minimum wall thickness* 0.083 inch** 2.11 mm

0.109 inch 2.77 mm

2.0 mm 2.5 mm

3.0 mm Other: mm

(3) Alternately, killed carbon steel and low alloy tubes may be 25.4 mm

OD with a minimum wall thickness of 2.77 mm .

d. For high alloy (above 5 Cr-1/2 Mo and up through austenitic stainless steel) tubes, indicate:


1 inch 25.4 mm

19 mm 20 mm

25 mm Other: mm


0.083 inch 2.11 mm

1.5 mm 2.0 mm

2.5 mm Other: mm

(3) Alternately, high alloy tubes may be 25.4 mm OD with a minimum wall

thickness of 2.11 mm .


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* For high pressure applications, the required thickness may be increased.

e. For non-ferrous (Admiralty, Cu-Ni, etc.) tubes, indicate:


1 inch 25.4 mm

19 mm 20 mm

25 mm Other: mm


0.083 inch 2.11 mm

1.5 mm 2.0 mm

2.5 mm Other: mm

(3) Alternately, non-ferrous tubes may be 25.4 mm OD with a minimum wall

thickness of 2.11 mm . f. For super high alloys (Incoloy, Titanium, etc.) tubes, indicate:


1 inch 25.4 mm

19 mm 20 mm

25 mm Other:

mm

(2) Minimum wall thickness 0.049 inch** 1.25 mm

0.065 inch 1.65 mm

1.5 mm 2.0 mm

2.5 mm Other:

mm

(3) Alternately, super high alloy tubes may be

25.4 mm OD with a minimum wall

thickness of 1.25 mm .


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g. Based on available bundle pulling and lifting equipment, indicate the maximum bundle size:

Maximum Bundle Diameter

60 inches ** 1500 mm

48 inches 1200 mm

Other: mm 1500

Maximum Bundle Weight

44,000 lbs. ** 20,000 kg

22,000 lbs. 10,000 kg

Other: kg 20000

Note: These limitations will not apply to vertical combined feed exchangers, vertical reboilers or fixed tubesheet type exchangers.

h. Indicate metallurgy for treated and inhibited fresh cooling water service:

Killed Carbon steel ** Other:

Indicate metallurgy for other fresh water cooling services:

Admiralty materials ** Other:

(Refer to BEDQ Section 3.4, Cooling Water.) UOP specifies any of the following metallurgies for sea water or brackish water cooling services. Indicate preferred metallurgy:

UOP to specify ** 90-10 Cu-Ni Aluminum brass 70-30 Cu-Ni Titanium Other:


i. Indicate typical fouling factor for fresh water cooling:

0.0020 h-ft2-°F/Btu (0.0004 h-m2-°C/kcal, 0.00035 m2-°C/W ) ** Other: 0.0002 h-m²-ºC/kcal

0.0002 Indicate typical fouling factor for sea water or brackish water cooling:

0.0020 h-ft2-°F/Btu (0.0004 h-m2-°C/kcal, 0.00035 m2-°C/W) ** Other: 0.0003 h-m²-ºC/kcal

0.0003


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j. UOP specifies U-tubes when the fouling factor on the tubeside is less than 0.002 h-ft2-°F/Btu

(0.0004 h-m2-°C/kcal) or if required by the process fluid on the shell side, such as hydrogen and HF acid services. For fouling services [tubeside fouling ≥ 0.002 h-ft2-°F/Btu (0.0004 h-m2-°C/kcal)] and cooling water services in the tube side, floating head construction will normally be specified.


k. UOP specifies square pitch when the shell side fouling factor is equal or greater than 0.002 h-ft2-°F/Btu (0.0004 h-m2-°C/kcal), low shell side pressure drop services, boiling services, or the strength welded tube to tubesheet joint is required. Triangular pitch may be specified for certain clean services when the shell side fouling factor is less than 0.002 h-ft2-°F/Btu (0.0004 h-m2-°C/kcal).


l. UOP specifies a block valve on the cooling water inlet piping and no valving on the cooling water

return piping.


Butterfly valves on the inlet and return piping with provisions for back flashing as shown in Appendix.

m. UOP does not specify shell and tube heat exchanger performance temperature measuring

equipment in the Engineering Design Specifications. UOP will, however, inform the Contractor of the Owner’s requirements on the Piping and Instrument Diagram legend. The specific location and assignment of item numbers will be done by the Contractor. Indicate the extent of exchanger performance temperature measuring equipment desired.

Exchanger temperature measurement points are not required ** Provide one temperature measurement point for each heat exchanger service Provide one temperature measurement point for each heat exchanger shell

Provide one temperature measurement point for each heat exchanger shell Indicate the type of heat exchanger temperature measuring equipment desired.

Thermowells only Local thermometers Board-mounted temperature indicators

Board-mounted temperature indicators


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n. UOP may, in appropriate cases, specify alternative types of heat exchangers, such as plate and

frame, welded plate, spiral, plate-fin, etc. heat exchangers. o. UOP will assume that a thermosyphon reboiler will be oriented horizontally in most

circumstances. Vertical thermosyphon reboilers and stab-in reboilers will be used when process requirements allow their use.


p. Indicate any additional requirements for the design and selection of shell and tube exchangers.

Provide isolation and bypass facility if appropriate. UOP to determine and review with Essar on case to case basis during P&ID Review Meeting.

5.5 Air Cooled Heat Exchangers

a. UOP normally specifies the maximum use of air cooled heat exchangers.

For all air cooled heat exchange, UOP specifies the process outlet temperature at a minimum of 20°F (11°C) above the design dry bulb temperature. Indicate the preferred process outlet temperature for all air-cooled heat exchange.

20°F (11°C) above design dry bulb temperature ** °C above design dry bulb temperature

24 When air cooled heat exchange is followed by water cooled exchangers, UOP specifies the process outlet temperature breakpoint between air and water cooling at a minimum of 25°F (14°C) above the design dry bulb temperature. Indicate the preferred process temperature breakpoint for air cooled heat exchange followed by water cooled exchange.

25°F (14°C) above design dry bulb temperature ** °C above design dry bulb temperature

24 (The design dry bulb temperature is indicated in BEDQ Section 4.3,a.)

b. Indicate preference for draft fans.

Forced draft ** Induced draft


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c. When close temperature control of the process fluid outlet temperature is required or when the

power consumption for an item exceeds 50 HP (37 kW), UOP may specify one half of the fans with variable speed fan motor drives.

UOP design criteria are acceptable.** Specify auto-variable (AV) type fan blade pitch control instead of variable

speed fan motors for close temperature control or energy conservation. Alternate design criteria are:

UOP design criteria are acceptable d. Indicate preference for nominal tube length:

30 feet ** 9.15 meters Other tube length: m

9.9 e. Small air cooled exchanger duties will be combined in common bays if possible. When

appropriate, tube lengths shorter than the nominal length will be allowed in separately mounted, independent air coolers.


f. When winterizing is required, UOP will normally specify louvers plus steam coil, or for more

severe cases, internal or external air recirculation plus steam coil.


g. UOP does not specify air cooled exchanger performance measuring equipment in the Engineering

Design Specifications. UOP will, however, inform the contractor of the Owner's requirements on the Piping and Instrument Diagram legend. The specific location and assignment of item numbers will be done by the Contractor. Indicate the extent of air cooled exchanger performance temperature measuring equipment desired.

e. **

UOP design criteria are acceptable ** Provide one temperature measurement point on the combined inlet for each exchanger service Provide one temperature measurement point for each bundle outlet Alternate design criteria are:


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Indicate the type of exchanger temperature measurement equipment desired.

Thermowells only Local thermometers Board-mounted temperature indicators

h. Indicate any additional instructions relating to the design and selection of air cooled exchangers.

5.6 Pumps

a. UOP will specify pumps in conformance with the following standards:

ASME Pumps

UOP specifies pumps in conformance with ASME B73.1 M (commonly referred to as “ASME pumps”) in hydrocarbon and non-hydrocarbon (e.g. water or caustic) services , which do not exceed any of the following limits:

Maximum discharge pressure 275 psig 19.3 kg/cm2(g) Maximum suction pressure 75 psig 5.3 kg/cm2(g) Maximum pumping temperature 300ºF 150ºC Maximum rotative speed 3600 rpm 3600 rpm Maximum rated total head 400 ft 120 m

For ASME hydrocarbon services UOP will specifiy 316 SS pump casings and mechanical seals designed to API 682 2nd edition. API Pumps In all services not covered by ASME pumps (as detailed in the above paragraph), UOP specifies pumps in conformance with American Petroleum Institute (API) Standard 610. These are commonly referred to as “API Pumps.”

UOP design criteria are acceptable ** ASME Pumps are acceptable only for non-hydrocarbon service. Alternate design criteria are:


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b. UOP specifies installed spares in most continuous process pump services.

For intermittent pump services, UOP specifies no spare, an installed spare, or a warehouse spare as appropriate.


Provide warehouse spare for intermittent service. However for the critical duty spare pumps with warehouse provision should be discussed during the Meeting with UOP.

c. UOP normally specifies dual mechanical seals for pumps in light hydrocarbon, hazardous or carcinogenic fluid services. Hazardous and carcinogenic materials are defined as follows: • 0.1 % (weight) or more of benzene or any chemical considered carcinogenic as determined by

any of the organizations listed in note 2. • 1% (weight) or more of toxic chemicals as determined by UOP • 25% (weight) or more C6 through C9 aromatics

UOP specifies pressurized dual or unpressurized dual seals based on process considerations. UOP specifies non-contating gas lubricated seals where applicable. UOP normally specifies single mechanical seals wherever otherwise possible.


d. UOP specifies sealless pumps, when appropriate, for some critical services such as explosive

mixtures or sub-atmospheric pressure suction conditions.



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e. UOP specifies an open-loop centralized oil mist lubrication system for new process units with more than five pumping services to maximize equipment availability and Mean Time Between Repair (MTBR).

Open loop oil mist** Closed loop oil mist Other

Forced or bath lubrication system

f. UOP specifies motor drivers for most pump services. For critical services (see BEDQ Section

2.1), UOP normally specifies back pressure steam turbine drivers for at least one of the pumps in spared services in accordance with API Standard 611.

For steam turbines in pump services, UOP normally specifies the inlet steam to be at an intermediate pressure level and exhaust to the low pressure level indicated in BEDQ Section 3.1.


g. UOP specifies pumps on the basis of unsheltered, outdoor installation.


h. For certain low flow, high head services, UOP will normally specify vertical, high speed, single

stage pumps (Sundyne).


i. Indicate any additional requirements for the design and selection of pumps:


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5.7 Compressors

a. UOP specifies centrifugal compressors in conformance with API Standard 617 except for light

duty air compressors. UOP specifies axial compressors for large air blower services and other large capacity services such as Oleflex reactor effluent compressors and Cyclar product recovery compressors. Axial compressors will be specified in conformance with applicable sections of API Standard 617. Due to their high reliability, centrifugal and axial compressors will not be spared, but spare rotors will be specified. In addition to shop testing required by API 617, UOP project specifications for axial or centrifugal compressors may specify a shop performance test.


b. UOP specifies reciprocating compressors in conformance with API Standard 618 except for light

duty air compressors. UOP specifies sufficient spare capacity to permit maintenance of one machine while the plant remains on stream. Spare capacity selection will be determined for each application based upon process requirements, critical service, economics, and proven vendor capability. Indicate preference for number of machines or percentage of total service to be specified for each machine.

UOP sparing philosophy is acceptable ** Two 100% machines are preferred Three 50% machines are preferred Alternate design criteria are:

Alternate design criteria are: 3 machines, 2 running (60%) and 1 standby. All are motor driven.

c. UOP specifies screw compressors in special instances when determined to be advantageous over

alternate choices. Screw compressors will be specified in conformance with API Standard 619. Due to their high reliability, dry screw compressors will not be spared, but spare rotors will be specified.



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d. UOP specifies unpressurized dual dry gas shaft seals for centrifugal compressor casings in hydrocarbon services.


e. UOP specifies reciprocating compressors with motor drives. Centrifugal and screw compressor driver

selection will be evaluated for each application based upon process requirements, critical service, utilities, capital costs, and any customer preference.


Total or partial condensing steam turbine drives shall be avoided unless specifically approved by Essar

f. Indicate preferred type of turbine exhaust steam surface condenser:

Air cooled Water cooled Air cooled

g. UOP specifies air blowers and air compressors in accordance with climatic conditions indicated in BEDQ Section 4.3.b.

h. UOP specifies compressors on the basis of unheated, sheltered, outdoor installation.


i. Indicate any additional requirements for the design and selection of compressors:

Recycle Gas - No spare, back pressure turbine (HP to LP).


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5.8 Pressure Relief Valves

a. UOP normally specifies a single pressure relief valve for each service unless a single valve cannot provide the required capacity or multiple valves are preferred for a particular service. In steam generation service, dual valves are specified in accordance with the requirements of the ASME Boiler and Pressure Vessel Code, Section I.


b. UOP normally does not specify spare pressure relief valves.


Spare relief valves are to be provided for all safety valves except the thermal relief valves on fire case only relief valves. In case of multiple valves, one spare to be provided.

If installed spare pressure relief valves are required, UOP will specify inlet and outlet block valves, except in steam service as governed by the ASME Boiler and Pressure Vessel Code, Section I. Inlet and outlet block valves for on-line relief valve shall be locked open (LO) or car sealed open (CSO) in conformance with refinery policy. Indicate preference:

On-line relief valve block valves to be locked open (LO) On-line relief valve block valves to be car sealed open (CSO)

c. UOP normally specifies separate inlet and outlet piping connections for multiple pressure relief valves

(including spares) located on a vessel, or on the process piping.


Multiple PSVs if required to be connected to common header.


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d. When determining general electrical power failure relieving rates, UOP assumes the resultant loss of cooling water.


e. UOP may specify pilot operated pressure relief valves for services where:

1) significant inlet piping pressure losses are expected 2) the process operating pressure is close to the relief valve set pressure 3) the relief valve set pressure is below 15 psig [1 kg/cm2(g)] 4) a specific application requires design features unique to a pilot operated relief valve 5) they are the best economic choice


f. UOP assumes that all process unit pressure relief valves in both vapor and liquid service (except non-

flammable, non-toxic fluids such as steam, air, nitrogen, or water) discharge to a common relief header.

UOP design criteria are acceptable ** Alternate design criteria are: (e.g. separate vapor and liquid relief headers)

g. When calculating heat input due to an external fire, UOP designs according to API RP521and API

Standard 2000.

UOP design criteria are acceptable ** Indicate any alternate, more conservative design criteria (e.g. National Fire Protection

Association [NFPA or other])


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h. When calculating heat input due to an external fire, UOP normally does not take credit for thermal

insulation.

UOP design criteria are acceptable ** If an insulation credit should be taken, indicate the type of insulation, minimum environment

factor to be used and details concerning its installation (e.g. stainless steel banding and jacketing).

i. The total back pressure in the relief header can affect PRV sizing, valve type and metallurgy selection,

relief header sizing, and/or the process design of vessels which are vented to the relief header. Total back pressure consists of two components: superimposed and built-up, each of which affect the relief system design in different ways.

• Superimposed back pressure is the constant pressure which exists at the PRV outlet before the

valve opens, and it is typically due to purge gas flow, water seal static head, molecular seal, etc. This superimposes a back pressure at the outlet of all PRVs and on all process equipment vents which discharge into the relief header.

- If a conventional (non-balanced) PRV is routed to the relief header, superimposed back

pressure directly increases its “effective” set pressure. - If a PRV discharges flashing liquid to the relief header, the superimposed back pressure fixes

the degree of auto-chilling and may affect metallurgy selection for the PRV and/or discharge piping.

• Built-up back pressure develops at the PRV outlet when it opens and material flows into the relief

header. Built-up back pressure can affect PRV sizing, selection of valve type (conventional, balanced bellows, or pilot-operated), and/or sizing of the relief valve discharge line and headers. If built-up back pressure is too high it may also affect equipment design pressure.

• Total back pressure at the PRV outlet is the sum of superimposed and built-up back pressures.

When a valve discharges to a relief header and it protects equipment with a design pressure of 50 psig [3.5 kg/cm2(g)] or higher, UOP assumes back-pressure in the relief header as shown below:

Header Name Main Relief Header Pressure Superimposed back pressure 3 psig* 0.2 kg/cm2(g)* Built-up back pressure in main relief header 15 psi* 1.1 kg/cm2*

*UOP will then allow a minimum of 7 psi [0.5 kg/cm2] additional built-up back pressure in the PRV discharge pipe & relief sub-header through to the main relief header.

UOP design criteria are acceptable ** UOP design criteria are not acceptable. See completed table below.


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If these are not acceptable, complete the table below with values expected during a general (refinery wide) electrical power failure or a cooling water failure. Note: If separate relief headers are used for high pressure, liquid, or acid gas services, indicate separately the header name and the header back pressures to be used in UOP’s PRV specifications.

Header Name Wet Flare Pressure Units kg/cm2(g) Superimposed back pressure 0.1 Total back pressure in main relief header

1.1

j. Indicate any additional requirements for the design and selection of pressure relief valves:

UOP to specify smokeless flare


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6. Instruments

6.1 Basic Process Control System

The depiction of instrumentation functions on the UOP Piping and Instrument Diagram (P&ID) will generally be in accordance with The Instrumentation, Systems, and Automation Society (ISA) symbolism and guidelines. The specific symbols shown are for microprocessor-based control systems Microprocessor-based control systems include shared displays using digital data storage and retrieval techniques, with associated peripheral and interconnecting equipment. This is commonly known as a Distributed Control System (DCS). An example of a pressure indicator is shown below:

Normal alarm functions are implemented using the data acquisition and shared processing equipment of the control system.

Critical alarms are designated on the P&ID by the “flag” symbol . Critical alarms are considered to be of high importance and are associated with a process condition or a special circumstance that requires immediate operator action. Examples are shutdown alarms, shutdown pre-alarms, and critical equipment alarms. Critical alarms use a unique display and audible tone to clearly distinguish them from normal alarms. Critical alarms are usually set apart from other alarms by a unique color, grouping, or graphical display on the DCS and/or displayed on a separate, “backlighted-nameplate” annunciator panel located above or adjacent to the operator station. The basis for UOP specifications shall include critical and normal alarms displayed on the DCS. The choice of the actual critical alarm display type shall be determined by the Owner and/or Contractor.

6.2 Logic Systems

UOP specifies the required level of interlock and automation required based on the classifications given below. UOP design is based on operating experience, economic judgment, industry recommended practice, and Process Hazard Analyses (PHA). Logic System specifications are classified by the following categories: a. Safety Instrumented Systems

Safety Instrumented Systems (SIS) are used to protect personnel and the environment. UOP designs for SIS will follow the guidelines of the following standard:

PI101

PT101

PA

L


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♦ ANSI/ISA-84.00.01-2004 (IEC-61511-1:Mod) — Functional Safety: Safety Instrumented Systems for the Process Industry Sector.

Safety Integrity Level Selection UOP will recommend a Safety Integrity Level (SIL) based on UOP process and design knowledge and operating experience that will provide a process fatal accident rate (FAR) of 1 in 10,000 years. The SIL needed to obtain that level of risk is defined in terms of Probability of Failure on Demand (PFD), which is a measure of system success (see SIL Table below).

Safety Integrity Level (SIL)

Probability of Failure on Demand

Average Range (PFD avg)

1 10-1 to 10-2 2 10-2 to 10-3 3 10-3 to 10-4

The owner is responsible for the final selection of the SIL.

The Owner has the option to increase the SIL for a given system. UOP is prepared to specify the increased SIL equipment in the Schedule “A”, if required by the Owner. However, this may impact both the cost and the schedule of the project.

b. Interlock Systems

Interlock Systems (IS) are used to protect the process and/or associated equipment and to provide a level of automation.

c. Sequential Logic Control Systems

Sequential Logic Control Systems (SLCS) are used for repetitive, batch type sequencing of valves and controllers, and provide a level of automation.

d. Proprietary Logic Systems

Proprietary Logic Systems (PLS) are used to ensure the safe, reliable operation of UOP licensed processes.


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Each category has individual requirements for input devices, logic solvers, and final control elements. UOP specifies the required level of safety availability and reliability, based upon system type.

UOP design criteria are acceptable ** Alternate design criteria ( i.e. increased SIL equipment ) are:

(Note: Local government codes may place additional requirements on the Logic Systems.)

Although UOP conforms to the requirements outlined in the ANSI S84 standard, the documentation supporting UOP’s review of the technology’s SIS is not included in the Schedule A. If you are interested in additional safety instrument system services or information about these services for your specific process instrumentation, contact your UOP representative.

6.3 Instrumentation Units of Measurement

The units of measurement selected will be used for control center display purposes. The UOP instrument Project Specifications will use these units of measurement where appropriate. The base conditions used in the UOP instrument Project Specifications for volume flow measurement will be in accordance with accepted international standards as defined in Section 1.8, System of Measurement, of this document. Non-standard base conditions will not be used in the UOP instrument specifications. Differential Range Units Differential pressure ranges generally will use the same units of measurement as pressure. Flow Units

Liquid Flow Units Vapor Flow Units Hydrocarbon sm3/h Steam kg/h Process Water sm3/h Gases Nm3/h Utility Water sm3/h Chemicals kg/h Other Process kg/h


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Other Units

Pressure: KG/cm2(g) Absolute Pressure in Vacuum Service:

Inches Hg ** (English default)

mm Hg ** (metric default)

Other:

Temperature: °F ** (English default) °C ** (metric default) Viscosity: cP Other :

For liquids choose one (and enter preferred units if necessary):

Specific gravity ** Density, kg/m³ Density:

For gases choose one:

Specific gravity (air = 1.0) Molecular weight ** Differential Range Units for Flow Measurement Select range calibration units for flow measurement:

Inches H2O ** mm H2O ** Other: (English default) (metric default)

6.4 Temperature Instruments

a. Elements

UOP specifies ISA Type E thermocouples for general services (highest EMF output of any standard thermocouple for measurement sensitivity) and ISA Type K thermocouples for high temperature services. Type K thermocouples are most commonly specified for >1200 °F (650°C) services; however UOP may specify Type K for lower temperature services as required. UOP normally does not recommend ISA Type J thermocouples because of the susceptibility of iron wire to oxidation corrosion adversely affecting measurement accuracy and operating life. UOP specifies PT-100 Resistance Temperature Detectors (RTD’s) for low differential temperature and/or high sensitivity applications. UOP specifies 3-wire PT-100 RTD’s. (Two-wire RTD’s may be used, provided the length between the tip and the transmitter is less than 2 meters.) Select the types of primary temperature measurement elements preferred: General Service (select one) High Temperature (select one)

ISA Type E ** ISA Type K ** ISA Type J RTD, Pt-100 [<850°F (450°C)]

ISA Type E 0


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b. Temperature Transmitters

UOP requires temperature transmitters for narrow-range control and sensitive temperature measurement applications in the 200°F (100°C) calibration range. A 16-bit analog-to-digital (A/D) conversion over the entire thermocouple/RTD calibration range in the DCS may be used instead of transmitters. The use of a DCS with lower than 16-bit resolution, without temperature transmitters, will result in reduced temperature control performance. Miscellaneous plant temperature indicator points are those points that do not require a narrow temperature indication range. UOP does not indicate temperature transmitters for these points on the P&ID, or specifify them as they will be the responsibility of the detailed design contractor. Temperature transmitters may be located in the control center, or satellite houses, or in the field as long as the ambient temperature limits for the transmitter are not exceeded. For locations with large ambient temperature changes. Select the location of temperature transmitters:

Control centers or satellite houses ** Field mounted Field mounted

c. Thermowells

Select the minimum thermowell flange (and nozzle) size. Vessel nozzle size must be consistent with BEDQ Section 5.2,c, Vessel Connections. Thermowell Flange Size for Vessels

Thermowell Flange Size for Piping

1 inch I.D.** 1 inch I.D.** 1½ inch 1½ inch 2 inch 2 inch in in

2 1.5 Select the minimum thermowell flange class: Thermowell Flange Class for Vessels

Thermowell Flange Class for Piping

Cl. 300 ** Cl. 300 ** Cl. 150 Cl. 150

Cl. 150 Cl. 300

Where applicable, for services such as heater firebox, heater ductwork, cooling water, etc., UOP will use 1 inch NPT for screwed thermowells. Where applicable, for storage tanks, UOP will use 1 inch 150 RF flanged thermowells


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6.5 Level Transmitters and Magnetic Level Indicators

UOP generally specifies external displacement type level instruments, but where feasible can specify external guided wave radar level instruments instead of external displacement type level instruments. Select preferred level instrument:

external displacement ** external guided wave radar

a. External Displacement

UOP specifies external displacement type level instruments with displacer lengths of up to 60 inches (1524 mm). For longer level ranges UOP specifies differential pressure type level instruments.

Select the maximum length for external displacement type level instruments:

60 inches (1524 mm) ** 120 inches (3048 mm)

Select external displacement type level instrument connection size:

1½ inches ** 2 inches

Select minimum external displacement type level instrument flange class:

Cl. 150 ** Cl. 300 b. Magnetic Level Indicators (Also applicable to magnetic level transmitters)

UOP generally specifies gauge glass type level gauges for local indication, but for some services UOP specifies magnetic level indicators.

Select magnetic level indicator connection size:

1 inch ** 1½ inches 2 inches

Select minimum magnetic level indicator flange class:

Cl. 150 ** Cl. 300

c. External Guided Wave Radar

Select external guided wave radar level instrument connection size:

1½ inches ** 2 inches

Select minimum external guided wave radar level instrument flange class:

Cl. 150 ** Cl. 300

See BEDQ Section 5.2,h, Level Instrument Installation for installation details of level transmitters and visual level indicators.


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6.6 Control Valves

Select minimum flange class for control valves:

Cl. 300 ** Cl. 150 Cl. 300

6.7 Totalization Equipment

UOP normally does not specify, for totalization purposes, metering devices other than orifice plates. Owner required metering devices (in addition to the orifice plate) can be shown on the P&ID with the note “By Contractor,” and will be the responsibility of the detailed design contractor. Indicate any additional Owner requirements for totalization of process streams which are to be shown on the UOP P&ID and identified as “By Contractor”.

Type of Primary Flow Measurement Device

Requirements for Pressure and/or Temperature Compensation

Liquid Feed Streams orifice required

Liquid Product Streams orifice required

Vapor-Phase Feed Streams orifice required

Vapor-Phase Product Streams orifice required

If additional metering devices for totalization purposes are required, indicate whether the additional metering devices should be added only to the UOP complex envelop for feed and product streams, or should be added to each individual process unit’s feed and product streams:

UOP complex envelop ** Each individual process 6.8 Analyzers

UOP specifies continuous stream analyzers where required for process monitoring and control. Any additional analyzers required by the Owner will be shown on the P&ID with the note “By Contractor” and specifications for the analyzer will be the responsibility of the detailed design contractor.


These will be reviewed on a case by case basis and those mutually agreed as necessary will be specified by UOP (Indicate any specific services and analysis type for which additional continuous stream analyzers are to be shown on the UOP P&ID and identified as “By Contractor”.)

6.9 Electrical Power

Normal instrument power for control systems, alarm systems, analytical devices, electrohydraulic actuators, antisurge controllers, etc., should be supplied from an uninterruptible power supply.


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Indicate the normal regulated single phase AC voltage for instrument power supplies: Volts: 240 VAC Hertz: 50

Select the nominal voltage level for field mounted solenoid valves:

24 VDC ** 48 VDC 125 VDC 110 VDC

110 VDC Select the nominal voltage level for field mounted process shutdown switches, position switches, etc.:

24 VDC ** 110 VDC

110 VDC 6.10 Site Conditions - Instruments

a. Ambient Temperature

Indicate the ambient temperature conditions to be used for instrument design purposes only. These conditions provide a basis for design of insulation, heating and/or cooling systems, etc. The lowest temperature listed in BEDQ Section 4.1, Winterizing Temperature, or Section 4.2, Low Ambient Temperature, will be used as the default low ambient temperature. The highest dry bulb temperature listed in BEDQ Section 4.3,a or b, High Ambient Design Temperatures, will be used as the default high ambient temperature.

Ambient Temperatures:

Low ambient temperature: 5 °C High ambient temperature: 48 °C

b. Environmental Conditions

(1) Tropical Conditions

If Tropical conditions are selected, UOP will include the following note in the Instrument General Requirements:

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. Packaging and “tropicalization” subject to approval by the licensee.

(2) Marine Conditions

If Marine conditions are selected, UOP will include the following note in the Instrument General Requirements:

All field equipment shall be suitable for operation in a corrosive, salt laden, marine atmosphere.


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(3) Desert Conditions If Desert conditions are selected, UOP will include the following note in the Instrument General Requirements:

All equipment shall be suitable for operation in a dusty environment subject to frequent sand storms and ambient temperatures exceeding 104°F (40°C). Contractor shall install sun shielding equipment when recommended by the vendor, or when anticipated conditions require it.

Indicate environmental considerations for the design of field instrumentation:

Tropical Marine Desert

Other (write entire note to be used): Tropical

6.11 Miscellaneous

a. Utility Header Instrumentation

UOP does not identify or specify instrumentation for single Unit or multiple Unit utility headers. This instrumentation will be the responsibility of the Detailed Design Contractor.

b. Minor Instrumentation

UOP does not specify instrumentation details or item numbers for minor equipment such as local pressure gauges, sight flow indicators, restriction orifices, or gauge glass type level gauges. However, these items will be indicated in proper location on the Piping and Instrument diagram. The Detailed Design Contractor is responsible for selection of this equipment. The UOP Engineering Project Specifications include general information which the Contractor is expected to use as a guide. Where special metallurgy, special accessories, or other circumstances dictate, additional details are included in the UOP Specifications.

6.12 Additional Requirements

Indicate any additional requirements for the design and selection of instruments:

Requirement of not providing bypasses or isolations to control valves of sizes 8" or above to be reviewed at the P&ID meeting.


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7. Miscellaneous 7.1 Battery Limit Requirements

Provide the following temperature and pressure information for streams entering or leaving the battery limits of the process unit(s) listed in BEDQ Section 1.2,b, General Information. Temperatures are particularly important for incoming streams and for streams going to facilities outside the scope of this project. Pressures should be adjusted to the conditions at battery limit and at grade. a. Indicate the following battery limit information for streams, including hydrocarbon and chemicals,

supplied to the process unit(s) by others. If this information is not available, UOP will indicate the required battery limit pressure on the Piping and Instrument diagram for streams from facilities outside the scope of this project.

UOP Unit Battery Limit Conditions

Incoming Stream Description

Source


Temp.:

SEE APPENDIX 5

b. Indicate the following battery limit requirements for outgoing vapor streams exiting from the UOP process unit(s).

UOP Unit Battery Limit Conditions

Outgoing Vapor Stream Description

Destination


Temp.: °C

SEE APPENDIX 5

(Note: “UTS” = UOP to specify)


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c. Provide battery limit conditions for outgoing liquid streams.

Preferred Information Alternate

Information

Outgoing Liquid Stream Description

Destination (1)

Battery Limit Temp: °C (2)

Destination System


(3)

Destination Elevation

Relative to UOP Battery Limts:

m (4)

Piping Distance

from UOP Battery

Limits to Destination:

m (5)

UOP Battery Limit


(6)

SEE APPENDIX 5

(Note: “UTS” = UOP to specify) (1) Indicate specific equipment name where possible (e.g., Naphtha Splitter, Gasoline Blending Tank, etc.). (2) Indicate preferred rundown temperature or “UTS”. Battery Limit Temperatures will normally range

between 100 to 175ºF (38 to 80ºC) depending upon vapor pressures, flash points or other fluid properties. High pour point fluids requiring battery limit temperatures over 175ºF (80ºC) will be discharged at a temperature of 250ºF (120ºC) or greater.

(3) Indicate the highest system operating pressure at the “destination.” (4) Indicate the elevation of the destination relative to grade level at UOP battery limits. Use positive

numbers for elevations above UOP battery limits and negative numbers for elevations below UOP battery limits. Some examples might be: • Storage Tank grade elevation • Naphtha Splitter feed nozzle elevation relative to UOP battery limits.

(5) Indicate the estimated length of the pipe run from UOP Battery Limits to the Destination. (6) Alternate (less desirable) definition of UOP Battery Limit Pressure based on a fixed value {e.g., 50 psig

[3.5 kg/cm2(g)]} or a fixed rule [e.g., vapor pressure plus 50 psi (3.5 kg/cm2)].


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7.2 Battery Limit Isolation

UOP normally specifies means to double block, blind, and bleed process lines between process units and/or storage. As a minimum, block valve, blind, and bleed will be specified at battery limits when a second valve is located within the process unit. If the second block valve is not present within the process unit, a double block, blind, and bleed will be specified at the battery limits. The following are UOP's standard practices for specifying battery limit isolation:

a. UOP normally specifies battery limit isolation for all process lines leaving a UOP designed unit.

UOP DesignedUnit

To Other ProcessUnit or Storage

Locate at BatteryLimits

*

BatteryLimits

b. Process lines arriving at a UOP designed unit, from facilities or process units outside UOP’s scope

of design, will be specified with battery limit isolation.

UOP DesignedUnit


*

BatteryLimits

c. Process lines arriving at a UOP designed unit, from another UOP designed unit, will have no

battery limits isolation shown since isolation valving will be located in the upstream unit.

First UOPDesigned Unit

Second UOPDesigned Unit

BatteryLimits


*

*This valve may be available as part of a control valve assembly or provided for other process reasons and would be used as part of the isolation system.


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d. Indicate any instructions relating to battery limit grouping of units (if other than individual process units) for isolation and shutdown purposes.

e. Battery limit isolation requirements for utilities will be the responsibility of the Detailed Design Contractor.

f. Indicate any additional requirements for battery limit isolation.

7.3 Wastewater Collection

a. UOP assumes separate systems for oily process water and rainwater runoff. Process drain funnels are assumed to discharge to the oily process water sewer unless otherwise noted. Separate chemical sewer systems will be indicated if required.

b. UOP Engineering Design Specifications will incorporate process drain funnels having a water seal

control or an optional closed drain system with closed venting to an emission control device per USA Environmental Protection Agency (EPA) regulations, in order to reduce volatile organic compound emissions from wastewater collection systems.

UOP design criteria are acceptable ** Alternate design criteria, including justifications, are:

7.4 Insulation

UOP will issue Standard Specifications for insulating hot and cold services as applicable. The Standard Specifications will indicate insulation requirements for energy conservation and will provide instructions regarding insulation for personnel protection

UOP design criteria are acceptable ** Alternate design criteria, including justifications, are:


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APPENDIX 1 USE UOP STANDARD NUMBERING


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APPENDIX 2

EQUIPMENT NUMBERING System The equipment, which will be used for this project, must be identified according to the following identification:

XXXYY – 0ZZ B C Where XXX XXX: Unit Number

YY : As per Equipment Designation Table below ZZ : Two (2) digits Equipment sequence number (01…99) B : Identification for multiple pieces per service Only one (1) piece B = “blank” Two (2) pieces (one spare) B = A/S Three (3) pieces (one spare) B = A/B/S Three (3) pieces (no spare) B = A/B/C etc. C : C = “X” if equipment is supplied by vendor

Example: Within this unit a centrifugal pump is specified to guarantee a proper reflux to a fractionation column. It is the third centrifugal pump specified in this section. This pump service has two (2) pieces. One piece is running the other is spare. This equipment will have the following number: 137P-003 A/S for VGOU 1 Unit

Equipment Designation Table

Equipment Designation

Equipment Description Equipment Designation

Equipment Description

AD Pit, sump, basin FI Flotation machine/equipment F Fired heater FJ Magnetic and high intensity separator

BB Thermoforn kiln FK Gravity concentration machine BC Air heater FL Screen, grizzly B Steam boiler, steam superheater FM Thickener, hydroseparator

BG Water treating equipment (non-ion exch) FO Ion exchange equipment BH Steam desuperheater, steam line separator FQ Pelletizer, balling drum, comp, briq. machine BP Line burner P&PM&PG

P&PB

Pump with motor (centr., recip, rotary) and gearbox Pump & turbine

BQ Incinerator K&KM&KG

K&KB

Compressors and blowers with motor and gearbox Compressor and turbine

BR Waste heat boiler GC Refrigeration equipment and accessories CA Stack (heater) MX Agitator, mixers CB Stack (flare, vent) M Electric generator & driver CD Dust/ fume collector GF Centrifuge C Tower/ column GG Engine (diesel, gasoline, steam)

CT Trays/ packing GH Extruder R Reactor GI Expander E Heat exchanger (shell & tube, tube bundle) GM Special DC electric motor E Heat exchanger (submerged bundle, coil

box) HM Sprinkler system

EA Heat exchanger (aircooled) IF HVAC (heating, ventilation, air conditioning) E Heat exchanger (double pipe) JC Elevator (passenger, freight) J Jet ejector system, barometric condensor JD Elevator (bucket), conveyor (belt, screw, pneum)

EF Cooling tower JF Loading, unloading and reclaiming equipment V Educator, deaerator, coalescers JG Bagging and packaging equipment

EH Crystallizer, vacuum evaporator KA Instrument air dryer


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EI Electric heater KC Measuring, detection and sampling equipment E Heat exchanger (plate type) PS Roll crusher V Process vessels and drums PT Impact crusher, hammer mill T Process tanks & storage tanks PU Grinding mill (rod, ball, peddle), wet grinder

FC Cyclone separators, classifiers PV Grinding mill (autogenus) FT Filter, screen, clarifiers PW Pulverizer FD Forced draft fan PX Casting machine FE Storage bin, hopper PY Weighing equipment FG Line filter, strainer, silencer, flame arrester PA Equipment as package units FH Belt, rotary, rotary air lock and vibr.

feeder ID Induced draft fan


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APPENDIX 3

INSTRUMENT NUMBERING System: The instrumentation, which will be used for this project, must be identified according to the following identification:

XXXYYY – 0ZZZ B Where XXX : Unit Number

YYY : As per Instrument Identification Table below ZZZ : Three(3) digits instrument sequence (loop) number (001…999) B : Instrument Suffix for indicating multiple materials in one sequence number (default = “blank”) e.g. : Multiple level gauges “A” and “B” valve in split range control

Example : Within this unit a flow controller with an indication is specified to guarantee a proper reflux to a fractionation column. It is the third flow controller specified in this unit. This instrument will have the following number:

137FIC-0003 for VGOU Instrument Identification Table System: ABC Where A : Measured variable letter

B : Modifier letter(s) C : Passive (“P) or Output (“O”) function letter(s) Letter First Position(s) Succeeding Positions Measured Modifier “P” Funct. “O” Funct. Modifier A Analysis Alarm “User” “User” B Burner Status C “User” Control D “User” Differential E Voltage Sensor F Flow Ratio G Position Gauge H Hand High, Open I Current Indicator J Power K Time Time Panel L Level Low, Closed M “User” N “User” “User” “User” “User” O “User” Orifice P Pressure Q Quantity Integrate R Radiation Record S Speed Switch T Temperature Transmit U Multivar. Multifucnt Multifunct V Vibration Valve W Weight Well X “User” “User” “User” “User” Y Event Convert Z Safety


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APPENDIX 4

SEA COOLING WATER HEAT EXCHANGER BACKFLUSHING SCHEM E

MIN MIN

MIN MIN¾" D

¾" VMIN

SEA COOLINGWATER RETURN

SEA COOLINGWATER SUPPLY

TI

PSVSIZE:SET AT:

Fo

r B

ac

kfl

us

hin

gFacing

TI

TI

¾" D

¾" V

Fo

r B

ac

kfl

us

hin

g


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APPENDIX 5


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Uops Bedq Rev 1

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