CONFIDENTIAL N DESIGN CRITERIA Shot fo. ART-01-120-A-CD-5001 Date: 23-JUN-15 1de71 1 UNIT: SUPERVISION CLIENT: PEMEX REFINACION LOCATION: TULA, HIDALGO. PROJECT: “APROVECHAMIENTO DE RESIDUALES REF. MIGUEL HGO.” PROJECT PEMEX No.: 1 23-JUN-15 APD - APROBADO PARA DISENO 0 03-MAR-15 APD - APROBADO PARA DISENO REV. DATE DESCRIPTION +» BEMEX PROCESS DESIGN CRITERIA (PDC) DEPTO.: PROCESO Num,: ART-01-120-A-CD-5001 ‘ermacon ICA FLUOR| & APPROVAL: | REV: | DATE: | SHEET: FLUOR, |= JGPSIRB KKN 1 23JUN-15 | 1 de 71 PROCESS REFNACION ORICA FLUOR™ 02-4014 RO-2401 "ART-01-120-A-CD-500% docx Distribution Code: A002 REPRODUCED, ANDIOR USED FOR A DIFFERENT PURPOSE FOR WHIGH IT WAS PREPARED WITHOUT PRIOR WRITTEN AUTHORIZATION FROM PEMEX Page 191 of 282No. ART-01-120-A-CD-5001 CONFIDENTIAL Date: 23-JUN-15 DESIGN CRITERIA Sheet 2de71 RECORD OF REVISIONS Rev. Date Description 0 03-MAR-15_ | APD - Aprobado para disefio 1 23-JUN-15__| APD — Aprobado para disefio Excerpts and paragraphs in this document translated from the PEMEX standards are included for reference only and should be applied strictly according to the source document quoted. PROCESS "ART-01-120-A-CD-5001_1.docx Distribution Code: A002 REPRODUCED, ANDIOR USED FOR A DIFFERENT PURPOSE FOR WHIGH IT WAS PREPARED WITHOUT PRIOR WRITTEN AUTHORIZATION FROM PEMEX REFNACION ORICA FLUOR™ 02-4014 RO-2401 Page 192 of 282No. ART-01-120-A-CD-5001 CONFIDENTIAL Date: 23-JUN-15 DESIGN CRITERIA Sheet! 3de71 Rev. 1 PREFACE This Process Design Criteria (PDC) document provides general guidelines and pr ocedures for specifying major equipment and/or systems that will be used for all phases of design for the Aprovechamiento de Residuales de la Refineria Miguel Hidalgo en Tula Project (ART). It ensures that standard and consistent design oriteria are used by all project design teams, namely Pemex, ICA Fluor, Fluor, Technology Licensors, and various Contractors and Vendors. This PDC also serves as an important alignment and communication tool among the various project participants, namely Pemex, ICA-Fluor, Fluor, Technology Licensors, Contractors and Vendors. For this reason, this document has to be issued in the early stages of the project. However, the normal course of project activities and design development may result in changes to the various design data covered by this document especially for revamp units. To maintain the validity of this document, these changes will be issued via subsequent revisions after pre-agreed by PEMEX, Fluor and ICA-Fluor. In the case where Licensors and/or Contractors have more stringent design criteria than those contained in this document, the Licensor specifications may be used as necessary subject to PEMEX review and approval. The document is intended to be used for new units or new installations within revamped units. The decision to replace equipment in a revamped unit which may not meet the specific requirements of this document should be based on the Engineering judgment of the Lead Process Engineer and should be reviewed with PEMEX as appropriate. PROCESS "ART-01-120-A-CD-5001_1.docx Distribution Code: A002 REPRODUCED, ANDIOR USED FOR A DIFFERENT PURPOSE FOR WHIGH IT WAS PREPARED WITHOUT PRIOR WRITTEN AUTHORIZATION FROM PEMEX REFNACION ORICA FLUOR™ 02-4014 RO-2401 Page 193 of 82No. ART-01-120-A-CD-5001 Date: 23-JUN-15 DESIGN CRITERIA Sheet! 4de71 Rev. 1 CONFIDENTIAL TABLE OF CONTENTS Section Description Page 1.0 INTRODUCTION .. 2.0 DESIGN PHILOSOPHY 2.1 Desion PRESSURE. a 2.1.1 Vessels, Reactors and Columns 9 2.1.2 Heat Exchangers, Pumps and Compressors 10 2.1.3 Atmospheric and Pressurized Storage Tanks uw 2A Piping. rornsnnnnnenenenenenninannenenn sinnninoninneninnnnnnninineninnnnnnnnenne UL 2.2 DesioN TEMPERATURE 3B 22.1 Lower Design Temperature 4 2.2.2 Minimum Design Metal Temperature. 15 2.3. EXTERNAL DESIGN PRESSURE AND STEAM-OUT CONDITIONS. 15 23.1 Guidelines for External Design Pressure sr snes 1S 23.2. Guidelines for Steam-out Conditions 5 2.4 MATERIAL SELECTION, 20 2.4.1 Equipment and Piping Design Life Guidelines. 20 2.4.2 Equipment and Piping Corrosion Allowance sen sn sn sree 20 2.4.3 Special Services 2 2.5 INSULATION AND WINTERIZRTION nnn nn nn nn hn seonnes 3 3.0 EQUIPMENT DESIGN GUIDELINES . 3.1. Vessets, REACTORS AND CoLUMMS, 25 3.1.1 General Requirements 25 3.1.2 Design Pressure summoner 7 snnnannnnnnennnnnnn 2S 3.1.3 Design Temperature. . . . 26 3.14 Equipment Isolation os os os - 26 3.15. Column Sizing 26 3.1.6 Design Considerations. 26 3.1.7 Vessel and Column Internal Details. : rT BAB Skirt Height sonnnonenennnrnnnnnnnenenenn sstnnnnineninnnnnnanannnneee snnee BT 3.19 Nozzles, Boots and Manways cy 3.1.10 Hold-Up and Surge Times. 33 3.1.11 Tank Storage Times 37 3.1.12 Other Maintenance Provisions 37 3.2. HEAT EXCHANGERS 38 3.2.1 General Requirements 38 3.2.2 Shell and Tube Exchanger Design Criteria 39 3.2.3. Air Cooler Design Criteria 2 33. Peo Hearras 4s 3.3.1 General Requirements ru. sete sere sete a sone 3.3.2 Heater Process Specification Criteria... o o nn sone 3.3.3 General Heater Design Criteria, 46 3.3.4 Coil Design 46 3.3.5 Bumer Design. 46 3.3.6 Fuel Supply System. . . . . . a7 PROCESS "ART-01-120-A-CD-5001_1.docx Distribution Code: A002 REPRODUCED, ANDIOR USED FOR A DIFFERENT PURPOSE FOR WHIGH IT WAS PREPARED WITHOUT PRIOR WRITTEN AUTHORIZATION FROM PEMEX REFNACION ORICA FLUOR™ 02-4014 RO-2401 Page 194 of 282No. ART-01-120-A-CD-5001 Date: 23-JUN-15 CONFIDENTIAL DESIGN CRITERIA Sheet: 5 de 71 Rev. 1 3.3.7 Snuffing Steam 7 3.3.8. Stack and Dampet$ ror sonnnninnninnsnioninannisnnsinannensnenne 87 339 AirPreheaters, Waste Heat Boers, and Air Ducts 48 3.3.10 Instrumentation 48 3.4 Pues: 50 3.4.1 General Requirements - - 50 3.4.2 Pump Rated Capacity CriteTi..unnunnsnnsnionnansnnansne suansenaninnnennnonsne 5 3.4.3. Rated Head 51 3.4.4 Suction Pressure 52 3.4.5 Available NPSH 52 3.4.6 Minimum Flow su. ss — — snes 5B 3.4.7 Maximum Differential Heed for Centrifugal Pumps. 54 3.4.8 Maximum Discharge Pressure for Centrifugal PUMPS. a a snes 5 3.49 Maximum Discharge Pressure for Reciprocating Pumps 55 3.4.10 Drivers 55 3.4.11 Mechanical Seals 55 3.4.12 Pump Start-up andfor Re-AcceleratiON susuonsnnsnnsnnsnnnn soannnnnnninninanninnnennsonnns 56 3.4.13 Sparing Philosophy. os os . . 56 35 Compressors, 37 35.1 General Requirements 37 35.2. Sparing Philosophy 59 353 Drivers sn a . sn 59 35.4 Installation. ss ss sn 38 355 Reciprocating Compressor Cylinder and Packing Lubrication 60 35.6 Reciprocating Compressor Capacity Regulation System 60 3.5.7 Compressor Start-up and/or Re-Acceleration, 60 40 PIPING. 41 General 6 42. PireSizes 61 43. LINE SiaNG Caren 6 44 Sapte Connections. 61 4.5 Desion Tewerrarune 6 5.0 INSTRUMENTATION. 5A GENERAL. son sn sen snes snes sone 6B 5.2. CONTROLVALVES ann 63 5.3 Conmot Vaive Biock ano BvPass Vas 63 5.4 LEvELINSTRUMENTS. 64 5S Reucr Vawves. 64 5.6 EMERGENCY ISOLATION VALVES snnsnnnnninnnnnnanannnennnnnnn snnnninnnmninsnnnnnnnnenne 68 6.0 DRAWING FORMAT 65 6.1 PROCESS FLOW DIAGRAMS (PFOS). 6 6.2 PIPING AND INSTRUMENT DIAGRAMS (PIDs) 6 7.0 SAFETY AND ENVIROMENTAL CONSIDERATIONS. TA SREEW son vs vs sn a sn somes 68 TAA. Flare and Relief Systems 68 7.1.2 Hazardous Substances and Areas. se nn nn nn sooner 6B PROCESS "ART-01-120-A-CD-5001_1.docx Distribution Code: A002 REPRODUCED, ANDIOR USED FOR A DIFFERENT PURPOSE FOR WHIGH IT WAS PREPARED WITHOUT PRIOR WRITTEN AUTHORIZATION FROM PEMEX REFNACION ORICA FLUOR™ 02-4014 RO-2401 Page 195 of 282No. ART-01-120-A-CD-5001 Date: 23-JUN-15 CONFIDENTIAL DESIGN CRITERIA Sheet! oe 71 naa ss Tha re Protection TAS. ont loyout es 72. bomen ® 8.0 GENERAL LICENSOR GUIDELINES. PROCESS "ART-01-120-A-CD-5001_1.docx Distribution Code: A002 REPRODUCED, ANDIOR USED FOR A DIFFERENT PURPOSE FOR WHIGH IT WAS PREPARED WITHOUT PRIOR WRITTEN AUTHORIZATION FROM PEMEX REFNACION ORICA FLUOR™ 02-4014 RO-2401 Page 196 of 282No. ART-01-120-A-CD-5001 CONFIDENTIAL Date: 23-JUN-15 DESIGN CRITERIA Sheet! 7de71 Rev. 4.0 INTRODUCTION This document is intended to provide general guidelines and procedures for specifying major ‘equipment and/or systems and piping for the Pemex Project “Aprovechamiento de Residuales de la Refineria Miguel Hidalgo en Tula" (ART). The objective of this document is to provide guidance on basic process design criteria to ensure consistency in the process design made by all project design teams (Pemex, Fluor, ICA Fluor, Licensors, Contractors, and Equipment Vendors) during all phases of the ART Project. Guidelines should be incorporated into the Licensor/Contractor basic engineering work as appropriate. This document contains key design concepts based on O ficial Mexican Standards (NOM), Mexican Standards (NMX), PEMEX Reference Standards (NRF), other PEMEX standards and/or industrial standards and practices Many of the criteria discussed in this document are presented in more detail in the NOM's, NMX's or NRF’s, which must be referred to by the Licensors and Contractors for more detail information with respect to the design philosophy, regulations, standards, codes, and specifications. In the event of any discrepancies between this document and the standards referenced above, the NOM’S, NMX’S, or NRF’S should take precedence. PROCESS "ART-01-120-A-CD-5001_1.docx Distribution Code: A002 REPRODUCED, ANDIOR USED FOR A DIFFERENT PURPOSE FOR WHIGH IT WAS PREPARED WITHOUT PRIOR WRITTEN AUTHORIZATION FROM PEMEX REFNACION ORICA FLUOR™ 02-4014 RO-2401 Page 197 of 282No. ART-01-120-A-CD-5001 CONFIDENTIAL Date: 23-JUN-15 DESIGN CRITERIA Sheet Bde71 2.0 DESIGN PHILOSOPHY This section discusses general design philosophy applicable to all equipment, systems and piping ‘on the Pemex Project “Aprovechamiento de Residuales de la Refineria Miguel Hidalgo en Tula (ART). Specific design criteria for Equipment, Piping and Instrumentation are discussed in more detail in Sections 3, 4and5, respectively. Additionally, the Drawing Format and S afety and Environmental Considerations are presented in Sections 6 and 7. During the course of design development, pertinent job bulletins specifying other requirements such as starl-up and shutdown philosophy and emergency isolation valves may be issued to supplement this document as necessary. 2.1 Design Pressure In designing equipment, piping and instrumentation systems, adequate pressure and temperature margins should be specified for the most stringent coincident operating conditions and the mechanical design level to ensure mechanical integrity of the system, Additionally, most systems will also have safety relief valves to protect the systems against abnormal conditions, such as blocked discharge, fire and instrument failures. In specifying the design pressure of the system, it should be noted that operating pressure as specified in NRF-028-PEMEX-2010, Section 6.26, is the gauge pressure on the upper part of the vessel at which the vessel operates normally, which should not exceed the Maximum Allowable Working Pressure (MAWP), and is usually maintained at an appropriate margin below the relief pressure of the equipment, so that it prevents frequent releases. Maximum Allowable Working Pressure (MAWP) and Maximum Operating Pressure (MOP) are defined as the process operating condition that would give the highest coincident fluid pressure and temperature calculated for steady balance operation. MAWP js calculated by Mechanical Engineering based on the specified design pressure after actual components used to fabricate the equipment are selected. The design pressure should be ‘equal to or less than the MAWP. Design pressure is the pressure that the process engineers specify for the system and equipment to provide appropriate margin above the maximum operating pressure to ensure mechanical integrity of the system as defined in Table 2.1 The design pressure should consider the following conditions’ ‘+ Normal operations, which may include anticipated variations in fractionation requirements, charge stock composition and other process variations as well as blocked out modes of operation. ‘+ Other operating conditions, which may include catalyst regeneration, start-up, short-term operating conditions, etc. © Steam-out ‘+ Minimum temperature, i.e., ambient temperature, auto-refrigeration systems Vacuum conditions - If applicable and governing the material selection or material treatment, Design pressure is generally specified for a system, which may include multiple equipment services and associated instrumentation and piping. As defined in API STD 520/521, a pressure system is a system which, within its boundaries, is open. A typical pressure system may consist PROCESS "ART-01-120-A-CD-5001_1.docx Distribution Code: A002 REPRODUCED, ANDIOR USED FOR A DIFFERENT PURPOSE FOR WHIGH IT WAS PREPARED WITHOUT PRIOR WRITTEN AUTHORIZATION FROM PEMEX REFNACION ORICA FLUOR™ 02-4014 RO-2401 Page 198 of 282No. ART-01-120-A-CD-5001 CONFIDENTIAL Date: 23-JUN-15 DESIGN CRITERIA Sheet! 9de71 Rev. 1 of process equipment, such as columns, heat exchangers, vessels, etc., interconnected by piping with no valves (except locked open valves and check valves in certain situations as approved by PEMEX). A pressure system may be protected by only one relief valve or set of relief valves, provided it is ensured that the system, within its boundaries, remains open under all conditions. Equipment that are part of a pressure system protected by a relief valve discharging into a flare system or combined vent system should have a design pressure of at least 3.5 kg/cm’g. Lower design pressures may be considered if the relief valve releases directly to the atmosphere. Relief valves and flare systems should fully comply with NRF-031-PEMEX-2011 Flare and B urers Systems. Only in cases where the application of pressure relief devices is either impossible or impractical may instrumented protective functions be considered, subject to the approval of PEMEX. The Licensor/Contractor should consider High Integrity Pressure Protection System (HIPPS) in accordance with Section 7.1.4.3 and Appendix E of API Standard 521/ISO 23251. PEMEX requires the Licensor/Contractor to undertake a mass reduction study to determine the application of the HIPPS. Additional details for this study are included within the individual unit design bases. Design pressure guidelines for specific equipment are provided in Table 2.1 and as discussed below. 2.14 Vessels, Reactors and Columns Vessels, reactors and columns should be designed in compliance with the appropriate standards listed below: ‘+ NRF-028-PEMEX-2010 Design and Construction of Pressure Vessels, + NRF-136-PEMEX-2011 Process Towers, Trays and Internals The following is an extract from NRF-028-PEMEX-2010, paragraph 8.1.4: ‘+The internal design pressure should not be less than the most severe pressure at the coincidental temperature expected during upset operation of the vessel or the maximum operating pressure plus 10% or 2.0 kg/cm’g, whichever is greater. + The external design pressure should not beless that the most severe external pressure at coincidental temperature expected during upset operation or maximum operating external pressure plus 10%. If the vessel has compartments or chambers or equivalent, the design pressure should not be less than the internal design pressure as described above or the relieving pressure of the relief device, whichever is greater. + Vessels or vessel components that will be subjected to steam-out or steam service should be des igned for am inimum external pressure of full vacuum and s team temperature see Section 2.3.2 for steam out operations and guide lines. Note that NRF-028-PEMEX-2010, paragraph 8.1.4.3 has beens uperseded by the above requirements for the ART Project. ‘+ Vessels or vessel components that will be subjected to air purging should be designed for a minimum internal design pressure of 7 kg/cm’g at 80°C. It should be noted that air purging is uncommon. Nitrogen purging is normally used instead of air purging for equipment in hydrocarbon services since the combination of air with hydrocarbons may potentially form an explosive mixture, which should be avoided at any time, PROCESS "ART-01-120-A-CD-5001_1.docx Distribution Code: A002 REPRODUCED, ANDIOR USED FOR A DIFFERENT PURPOSE FOR WHIGH IT WAS PREPARED WITHOUT PRIOR WRITTEN AUTHORIZATION FROM PEMEX REFNACION ORICA FLUOR™ 02-4014 RO-2401 Page 199 of 282No. ART-01-120-A-CD-5001 CONFIDENTIAL Date: 23-JUN-15 DESIGN CRITERIA Sheet! toe ‘+ The intemal and external design pressure of pressure vessels with one or more compartments or chambers should be de termined by the most severe pressure- temperature scenarios possible (during start-up, normal operation, opening of vacuum, or pressure relief devices, emergency shutdown, scheduled shutdown, operator error, fire, and others). This design pressure determination should be supported with a risk study based on different possible scenarios. The following should also be considered * All vessels under pressure should be specified with ASME stamp and be designed with a minimum design pressure of 3.5 kg/em’g 2.1.2 Heat Exchangers, Pumps and Compressors Heat exchangers should be designed in accordance with the appropriate standards listed below in conjunction with the appropriate job narrative specification. This section also addresses design pressures for pumps and compressors, which may be part the heat exchanger system. Design Pressure should be in full accordance with paragraph 8,2.2 of NRF-090-PEMEX-2013 Shell and Tube Heat Exchangers, see selected excerpts below: A taasna som sam oreondensabeapor Tal veut extmal desen Presses ‘+ For non-pumped system, design pressure shall be 10% higher than the maximum operating pressure. In any case, the difference between the internal design pressure and maximum operating must be no less than 2.11 kg/em’g. In addition to the guidelines provided in NRF-090-PEMEX-2043, the following general practices are to be considered: ‘+ For pumped system, if heat exchangers or other equipment could be subject to the maximum pump discharge pressure at shutoff (existence of a block valve downstream of the exchanger), the design pressure shall be equal to the maximum head at no flow based on the purchased pump performance curve. During the design phase of the project, pump shutoff head can be estimated as follows: Maximum suction + Normal AP, or Normal suction + Maximum AP, whichever is greater. For booster pumps (two pumps in series), Maximum suction + Maximum AP Notes: 1, Maximum AP = 1.25 times Normal AP (for fixed speed electric motors) 2, Maximum AP = 1.35 times Normal AP (for variable speed electric motors or steam turbine drivers) 3. The maximum differential head at shutoff conditions should be determined based on the maximum anticipated liquid density. Consideration must be given to operation with cold start-up fluids. * For centrifugal compressors, the discharge design pressure of the compressor shall be at least 1.25 times the maximum specified discharge pressure based on API RP 617. This is an approximation of the maximum head at low or no flow condition to avoid the PROCESS "ART-01-120-A-CD-5001_1.docx Distribution Code: A002 REPRODUCED, ANDIOR USED FOR A DIFFERENT PURPOSE FOR WHIGH IT WAS PREPARED WITHOUT PRIOR WRITTEN AUTHORIZATION FROM PEMEX REFNACION ORICA FLUOR™ 02-4014 RO-2401 age 200 of 282No. ART-01-120-A-CD-5001 CONFIDENTIAL Date: 23-JUN-15, DESIGN CRITERIA Sheet! tt det need for relief valve. In cases when there is a relief valve, the design pressure should be at least equal to the specified relief valve set point. ‘+ For reciprocating compressors, the maximum operating pressure (MOP) is equal to the rated discharge pressure in kg/cm’g, which includes pressure pulsations based on API RP 618. A relief valve should be provided at the discharge of reciprocating compressors set at the design pressure, which is at least 110% of the MOP. Based on API RP 618, MOP to consider pulsation amplitude. ‘+ If the exchanger operates under vacuum, the internal design pressure should be set to full vacuum, in which case the minimum design extemal pressure should be full vacuum, ‘+ Inany shell and tube exchanger design where tube rupture can result in overpressure of the low pressure side, consider designing the low-pressure side of the exchanger for at least 10/13 (= 76.92%) of the design pressure of the high-pressure side if such a design eliminates a relief valve. + If the exchanger is subject to steam out or if there is a pos sibility that vacuum conditions may occur during operation or shutdown, the exchanger shall be designed for full vacuum, ‘+ For a shell and tube exchanger, if the cold side is a liquid and there is a possibility of the cold side of the exchanger being blocked in, a thermal relief valve will be provided on the exchanger cold side, set at the cold side design pressure. ‘+ Ifthe hot side is a liquid at low operating pressure and the exchanger can be blocked in onthe hot side and the hot side liquid could conceivably cool enough to draw a partial vacuum, the exchanger should be design for full vacuum. ‘+ For reactor loops, the design pressure of the heat exchangers and other equipment are typically set by the reactor loop design pressure. For establishing design Pressures for equipment and piping in hydro-processing reactor loops, refer to the guidelines provided in API STD 521, Appendix B. The settle-out pressure is the attained pressure of the system when the compressor is shutdown and internal pressure reach ane quilibrium state. Equipment design pressure is the settle-out pressure plus 5% if pilot valves used, or settle out pressure plus 10%. 2.1.3. Atmospheric and Pressurized Storage Tanks Storage Tanks should be designed in accordance with the appropriate standards such as API 650 and API 620 in conjunction with the appropriate job narrative specification The following guidelines are provided for various storage tanks. It is also recommended to consult with Mechanical before specifying the design pressure for storage tanks. ‘+ For Atmospheric Storage Tanks, design pressure shall be 2.5 inches of water (gauge). + For Pressurized Storage Tanks, design pressure shall be 110% of MOP + For Refrigerated Storage Tanks, design pressure shall be MOP. 214 Piping For piping design pressure, the guidelines below shall be followed: PROCESS "ART-01-120-A-CD-5001_1.docx Distribution Code: A002 REPRODUCED, ANDIOR USED FOR A DIFFERENT PURPOSE FOR WHIGH IT WAS PREPARED WITHOUT PRIOR WRITTEN AUTHORIZATION FROM PEMEX REFNACION ORICA FLUOR™ 02-4014 RO-2401 age 20: of 282No. ART-01-120-A-CD-5001 CONFIDENTIAL Date: 23-JUN-15 DESIGN CRITERIA Sheet! 12071 For centrifugal pumps and compressors discharge piping, design pressure shall be at least equal to maximum discharge pressure for all operating conditions ‘+ For centrifugal pumps suction piping upstream of suction block valve, design pressure shall be equal to the set pressure of the suction pressure safety valve plus static head. at maximum liquid level in pump suction system and any additive pressure drop (including trays), or maximum shutoff supply pressure from suction booster pump, whichever is applicable. * For centrifugal pumps, design pressure for discharge piping and suction piping downstream of suction block valve or VAAR, if present, shall be equal to maximum pump discharge pressure based on purchased pump performance curve. ‘+ For centrifugal compressors, the design pressure of the compressor discharge shall be at least equal to the specified relief valve setting; if ar elief valve setting is not specified, the design pressure shall be at least 1.25 times the maximum specified discharge pressure (refer to API RP 617). This is an approximation of the maximum, head at low or no flow to avoid the need for a relief valve. Maximum driver speed shall also be considered in calculating the maximum head, ‘+ Design pressure of piping and equipment protected by a pressure relief valve (PSV) on an interconnected equipment system (i.e., several equipment items protected by a single relief valve) shall not be less than the pressure expected when PSV reaches set pressure. Protected piping and equipment located upstream of the PSV takeoff location shall have a design pressure sufficiently higher than the PSV set pressure to account for maximum system pressure drop between protected piping and P SV location. Protected piping and equipment located downstream of PSV takeoff location shall have a design pressure at least equal to PSV set pressure to account for minimum pressure drop of zero for no flow. + PSV discharge piping shall be designed for at least the maximum back pressure. Consideration should be given to the following conditions in specifying the design pressure of piping ‘+ Starting up operations, including any start-up procedure, operation, or routing ‘+ Shutting down operations, including shutdown procedures, operation, and pump-out ‘+ Switching operations, including any cyclic regeneration, spare pump switching, and ‘coke drum switching ‘+ Regeneration procedures ‘+ Equipment bypassing ‘+ Tumdown operations + Pump shutoff * Control valves in fully open or fully closed position ‘+ Block valves in fully open or fully closed position, except for locked valves ‘+ Blocked outlets "W8 DOCUMENT CONTAMS PROPRIETARY AND CONFIDENTIAL INFORMATION WHICH SHALL NOY SE PuBLisHED DISELOSED To" OTHERS, REPRODUCED, ANDIOR USED FOR A DIFFERENT PURPOSE FOR WHIGH IT WAS PREPARED WITHOUT PRIOR WRITTEN AUTHORIZATION FROM PEMEX REFNACION ORICA FLUOR™ 02-4014 RO-2401 Page 202 of 282No. ART-01-120-A-CD-5001 CONFIDENTIAL Date: 23-JUN-15 DESIGN CRITERIA Sheet! 13de 71 Rev. ‘+ Equipment trip or shutdown ‘+ Misoperation ‘+ Maintenance, repair, or neutralization procedures ‘+ On-stream testing procedures ‘+ Steam-out or purging operations ‘+ Other causes of increased pressure 2.2 Design Temperature Similar to the design pressure, adequate margin should be maintained between the design temperature andthe maximum operating temperature to ensure mechanical integrity of the equipment and piping system The operating temperature is the temperature which prevails inside equipment and piping during any intended operation. In many situations, the temperature differences from those required for the intended operation can occur, The question whether such temperatures should be specified and taken as the operating temperature or the design temperature should be considered individually and the reason for the specification should be stated in the pertaining documents. Typically, the maximum operating temperature is the highest temperature which corresponds to the upper temperature control range provided for flexibility of the intended operation. The design temperature (DT) is typically 28°C higher than the maximum operating temperature at the specified design pressure. The DT is the highest temperature at which equipment may be subjected to at the design pressure. The DT is used for mechanical design (e.g., determination of minimum wall thickness and other physical characteristics) of equipment and piping Consideration should be given to the following conditions in specifying the design temperature of piping and equipment: ‘+ Normal operating conditions such as fractionation requirements, charge stock composition and other process variations ‘+ Blocked out modes of operation ‘Minimum temperature, i.e., ambient temperature, auto-refrigeration + Vacuum conditions ‘© Fouling of heat exchangers + Loss of utility such as cooling water or instrument air ‘+ Starting up operations ‘© Shutting down operations ‘+ Switching operations including any cyclic regenerations and coke drum switching + Regeneration procedures * Equipment bypassing + Turndown operations © Control valve failures in fully open or fully closed position ‘+ Block valves in fully open or fully closed position, except for locked valves PROCESS "ART-01-120-A-CD-5001_1.docx Distribution Code: A002 REPRODUCED, ANDIOR USED FOR A DIFFERENT PURPOSE FOR WHIGH IT WAS PREPARED WITHOUT PRIOR WRITTEN AUTHORIZATION FROM PEMEX REFNACION ORICA FLUOR™ 02-4014 RO-2401 Page 203 of 282No. ART-01-120-A-CD-5001 CONFIDENTIAL Date: 23-JUN-15, DESIGN CRITERIA Shoot de 71 © Equipment trip or shutdown * Misoperation ‘+ Maintenance, repair, or neutralization procedures + Steam-out or purging operations ‘+ Other causes of increased temperature For equipment and piping subject to steam-out, a minimum design pressure of full vacuum at steam temperature shall be specified, see Section 2.3.2 guidelines for steam out guide lines operations. If MOT for large columns is greater than 235°C, consideration should be given for providing multiple design temperatures by dividing column into two or more zones. For reciprocating compressors, the maximum allowable discharge temperature (MOT) shall not ‘exceed the limits stipulated in API RP 618, Reciprocating Compressors for Petroleum, Chemical, and Gas Industry Services. Typically, the maximum predicted discharge temperature should not exceed 150°C. This limit applies to all specified operating and load conditions (to be provided by the vendor). Special consideration shall be given to services with high-pressure hydrogen or applications requiring non-lubricated cylinders, where temperature limitations should be | ower. Predicted discharge temperatures shall not exceed 136°C for hydrogen-rich services (those with molecular weight of 12 or less). Note that recommended discharge temperature alarm and trip set points are 5°C and 10°C, respectively, over the maximum predicted discharge temperature; but in no case should temperature trip set points exceed 180°C, To prevent auto-ignition, lower temperature set points limits should be considered for air because of its oxygen content, if the discharge pressure exceeds 21 kg/cm’g. Use of synthetic oils, although not intended as a means to increase the allowable discharge temperature, should be considered for additional safely (Ref. API RP 618, paragraph 2.3), Separate combination of design pressure and temperature may be considered to accommodate different modes of operation, e.g. regeneration versus normal operation, taking into consideration rating of the piping for short term condition in conformance with the ASME B31.3 piping code. Design temperature for relief and flare system shall be bas ed on temperature of fluid being relieved, taking into account temperature change across PSV and thermal effects in discharge piping. Discharge piping shall be designed for the expected temperature of the piping during relief, For very high relief temperatures for fire cases, maximum design temperature for flare laterals and headers shall not be based on the fire relief case temperature. For these lines, a note shall be added to line list to provide the fire relief temperature for stress analysis use only. 2.2.1 Lower Design Temperature The lower design temperature (LDT) is the lowest temperature at which equipment may be subjected to its design pressures. In establishing the LDT for equipment containing LPG or compressed flammable low molecular weight gas, it should be r ealized that the lower temperature normally coincides with a reduced pressure due to auto-refrigeration Construction materials should be selected to prevent brittle fracture under circumstances such as startup, shutdown, depressurization or other operations. Thus, for material selection purpose the design temperature may be below the LDT. PROCESS "ART-01-120-A-CD-5001_1.docx Distribution Code: A002 REPRODUCED, ANDIOR USED FOR A DIFFERENT PURPOSE FOR WHIGH IT WAS PREPARED WITHOUT PRIOR WRITTEN AUTHORIZATION FROM PEMEX REFNACION ORICA FLUOR™ 02-4014 RO-2401 Page 204 of 282No. ART-01-120-A-CD-5001 Date: 23-JUN-15 15de71 CONFIDENTIAL DESIGN CRITERIA Shoot The LOT is initially selected by the process engineer and finally determined in close consultation with the mechanical design engineer. 2.2.2. Minimum Design Metal Temperature Per NRF-028-PEMEX-2010, Design and Construction of Pressure Vessels, the Minimum Design Metal temperature (MDMT) should not be less than the recorded minimum ambient temperature at the location. For the ART Project, the MDMT is specified as 0°C at the specified design pressure. 2.3. External Design Pressure and Steam-out Conditions 2.3.1 Guidelines for External Design Pressure ‘+ Only equipment and piping that operate under full or partial vacuum during start-up, normal operation, or upset modes or are subject to steam out operation, shall be designed for an external pressure. ‘+ Equipment and piping in the following services will be designed for full vacuum: © Equipment operating under partial or full vacuum during normal operation © Suction drum for a compressor or vacuum pump © Equipment containing steam or stripping steam during normal operation, such as sour water strippers and amine regenerators. ‘* Special consideration shall be given when specifying external design pressure for ‘equipment normally subject to internal pressure but connected to the suction of a compressor or other evacuating equipment. ‘+ Equipment operating a low pressure that may be affected by decrease in ambient temperatures should also be given special consideration, Examples are overhead receivers operating at low pressure and receiving feed from an air-cooled exchanger. ‘+ For water (cooling water, stripped sour water) systems heat exchangers shall be designed for half vacuum at its corresponding design temperature. 2.3.2 Guidelines for Steam-out Conditions ‘+ For systems that will be s ubject to steam-out as part of maintenance or routine operation, the design should be adequate for steam-out operation. NRF-028-PEMEX- 2010, paragraph 8.1.4.3 has been superseded by the following requirements for the ART Project © Medium pressure steam will be used for steam-out operations. Refer to Basic Engineering Design Data (BEDD) document for medium pressure steam conditions. © Equipment and piping subject to steam-out as part of maintenance should be designed for full vacuum @ 225°C and 3.5 kg/cmg internal pressure @ 335°C. 2 Provisions, i.e, connections, nozzles, etc., should be provided to allow for steam ‘out of equipment and piping in hydrocarbon and sour water services. 9 Since vacuum conditions may exist due to steam condensation, the Operating Manual or Guidelines for the plant should state that the vessel is not to be blocked in during steam-out operations even if it is designed for full vacuum as PROCESS "ART-01-120-A-CD-5001_1.docx Distribution Code: A002 REPRODUCED, ANDIOR USED FOR A DIFFERENT PURPOSE FOR WHIGH IT WAS PREPARED WITHOUT PRIOR WRITTEN AUTHORIZATION FROM PEMEX REFNACION ORICA FLUOR™ 02-4014 RO-2401 Page 205 of 282No. ART-01-120-A-CD-5001 CONFIDENTIAL Date: 23-JUN-15, DESIGN CRITERIA Sheet! tede71 stated above. The Operating Manual or Guidelines for the plant should also state that the vessel is not to be blocked, i.e. vents must be fully open during steam out operation, to avoid internal overpressure, especially in those cases where the vessel design pressure is below the medium pressure steam level used during steam-out operations. Steam Out flow must be controlled to hold a maximum pressure around 1 - 1.5 kg/cm‘g internal pressure during the steam out process. 9 The Delayed Coker Unit will carry out steam out operations with different medium pressure steam level; refer to the Basic Engineering Design Data (BEDD) document. PROCESS "ART-01-120-A-CD-5001_1.docx Distribution Code: A002 REPRODUCED, ANDIOR USED FOR A DIFFERENT PURPOSE FOR WHIGH IT WAS PREPARED WITHOUT PRIOR WRITTEN AUTHORIZATION FROM PEMEX REFNACION ORICA FLUOR™ 02-4014 RO-2401 age 206 of 282PROCESS CONFIDENTIAL DESIGN CRITERIA No. ART-01-120-A-CD-5001 Date: 23-JUN-15 Sheet: 17 de 71 Rev. 1 Table 2.1 - Design Pressure for Equipment and Piping” ITEM DESIGN PRESSURE” VESSELS, COLUMNS, REACTORS®™ Max Operating Pressure: <0 kg/em’g™ Full Vacuum and 3.5 kgiom'g Max Operating Pressure: 0 to 2.5 kg/emrg 3.5 kglom’g Max Operating Pressure: 2.5 kg/cm’g and higher 110% of MOP or MOP + 2.0 kg/em2g whichever is higher HEAT EXCHANGERS Max Operating Pressure: <0 kg/om’g™ Full Vacuum and 5.3 kglom’g For Pumped Systems: - Both Sides of Shell and Tube Exchangers - Tubes for Air Cooled Exchangers Notes 2, 4, 5, 6, For Non-Pumped Systems - Both Sides of Shell and Tube Exchangers - Tubes for Air Cooled Exchangers Notes 2, 5, 6 General 110% of MOP or MOP + 2.11 kg/em?g minimum FIRED HEATERS Heater Tubes for Pumped Systems Notes 2, 4,5 Heater Tubes for Non-Pumped Systems Notes 2,5 General 110% of MOP, PUMPS Pump Suction Note 9 Pump Discharge Note 9 CENTRIFUGAL COMPRESSORS Casing and Discharge Piping (Ref: API RP 617) 125% of Max Discharge Pressure © RECIPROCATING COMPRESSORS Casing and Discharge Piping 110% of MOP. STORAGE TANKS © ‘Atmospheric Storage Tanks ” 2.5" Ww. Pressurized Storage Tanks 110% of MOP. Refrigerated Storage Tanks 100% of MOP. PIPING Notes 2, 5, 9 RELIEF AND FLARE SYSTEMS PSV Discharge Piping to Unit Flare KO Drum 7.0 kg/em’g minimum “7 Flare KO Drum and Downstream Piping 3.5 kgicm’g minimum | Notes: This design pressure (also referred to as mechanical design pressure) corresponds to the design pressure at the high point in any system (e.g. upper part of the vessel as specified in NRF-028-PEMEX-2010). The design pressure at the low point in the vessel or piping system shall be equal to the design pressure at the high point plus static head at maximum 1 "ART-01-120-A-CD-5001_1.docx Distribution Code: A002 REPRODUCED, ANDIOR USED FOR A DIFFERENT PURPOSE FOR WHIGH IT WAS PREPARED WITHOUT PRIOR WRITTEN AUTHORIZATION FROM PEMEX REFNACION ORICA FLUOR™ 02-4014 RO-2401 age 207 of 282No. ART-01-120-A-CD-5001 CONFIDENTIAL Date: 23-JUN-15, DESIGN CRITERIA Sheet! 18de 71 Rev. liquid level and any additive pressure drop (including trays). The design pressure is equal to or less than the Maximum Allowable Working Pressure (MAWP) as calculated by the Mechanical Engineer after actual components used to fabricate the vessel are selected. Refer to Section 2.1 for further details 2. For guidelines for External Design Pressure (also referred to as Lower Design Pressure) see Section 2.3, For equipment and piping subject to steam-out, am inimum design pressure of full vacuum at steam temperature shall be specified see Section 2.3.2 for steam out operation and design guide lines 3, Maximum Working Pressure (MWP) or Maximum Operating Pressure (MOP) as referred to in this table is defined as follows: a. The MWP or MOP is defined as the process operating condition that would give highest coincident fluid pressure and temperature calculated for steady balance operation or operations. Such conditions shall include anticipated variations in fractionation requirements, charge stock composition, and other process variations. b. Normal fluid operating pressure shall be determined for top and bottom of vessel and at intermediate sections (as necessary), Pressure for sections at lower elevations shall be top pressure plus any applicable liquid head and additive pressure drop. ©, Alternate operating conditions shall be considered, such as, catalyst regeneration, short time operational upsets, and auto-refrigeration, Auto-refrigeration is a process in which liquid vaporizes and cools during depressurization d. Normal operation, which may include various blocked out modes of operation (blocked operation, start-of-run, end-of-run) or cyclic operations may occur, operating conditions for each operation or cycle phase shall be determined. 4, Refer to Section 2.1.2 for design pressure for pumped systems. 5. For reactor loops, the design pressures of the heat exchangers and other equipment are typically set by the reactor loop design pressures, see Section 2.1.2. 6. Refer to Section 2.1.2 for design pressure for shell and tube exchangers. 7. wag. - internal water pressure, inches gauge. w.v. - external water pressure, inches vacuum. Design tank for a vacuum of 1.5" w.v. 8, Consult with Mechanical Engineer before specifying design pressures for tankage. 9. Refer to Section 2.1.4 for design pressure for pump and compressor suction and discharge Piping. 10. PSV discharge piping shall be designed for at least the maximum back pressure. 11. In the event the flare system is limited such as in a revamp situation, higher design pressure may be specified to minimize the relief load. PROCESS "ART-01-120-A-CD-5001_1.docx Distribution Code: A002 REPRODUCED, ANDIOR USED FOR A DIFFERENT PURPOSE FOR WHIGH IT WAS PREPARED WITHOUT PRIOR WRITTEN AUTHORIZATION FROM PEMEX REFNACION ORICA FLUOR™ 02-4014 RO-2401 Page 208 of 282No. ART-01-120-A-CD-5001 CONFIDENTIAL Date: 23-JUN-15 DESIGN CRITERIA Sheet! 18de71 Table 2.2 — Design Temperature for Equipment and Piping EQUIPMENT DESIGN TEMPERATURE, °C 7 VESSELS, COLUMNS, REACTORS MOT + 28 7 HEAT EXCHANGERS MOT +282 Shell and Tube Exchangers and Air Cooled Exchangers FIRED HEATERS @ Heater tubes MoT +28 PUMPS, MOT +287 COMPRESSORS: MOT + 28 (Minimum 450) 7 STORAGE TANKS MOT +28 7 PIPING MOT + 28 7 RELIEF AND FLARE SYSTEMS PSV Discharge Piping to Unit Flare KO Drum Note 3 Flare KO Drum and Downstream Piping Note 3 Notes: 1. This design temperature (also referred to as mechanical design temperature) should be equal to or lower than the Maximum Allowable Working Temperature (MAWT) to be calculated by Mechanical after actual components used to fabricate the equipment are selected. Refer to Section 2.2 for further details, 2. Maximum Working Temperature (MWT) or Maximum Operating Temperature (MOT) as referred to in this table is defined as follows: a, The MWT or MOT is defined as the process operating condition that would give highest coincident fluid pressure and temperature calculated for steady balance operation or operations. Such conditions shall include anticipated variations in fractionation requirements, charge stock composition, and other process variations. b. Normal fluid operating temperature shall be determined for top and bottom of vessel and at intermediate sections (as necessary). ©, Alternate operating conditions should be considered, such as, catalyst regeneration, short time operational upsets, and auto-refrigeration d. Normal operation, which may include various blocked out modes of operation (blocked operation, start-of-run, end-of-run) or cyclic operations may occur, operating conditions. for each operation or cycle phase shall be determined. 3. Design temperature for relief and flare system shall be based on temperature of fluid being relieved, taking into account temperature change across PSV and thermal effects. in discharge piping. Discharge piping shall be designed for the expected temperature of the piping during relief except for high temperature fire relief scenarios. Refer to Section 2.2 for additional details. PROCESS "ART-01-120-A-CD-5001_1.docx Distribution Code: A002 REPRODUCED, ANDIOR USED FOR A DIFFERENT PURPOSE FOR WHIGH IT WAS PREPARED WITHOUT PRIOR WRITTEN AUTHORIZATION FROM PEMEX REFNACION ORICA FLUOR™ 02-4014 RO-2401 age 209 of 282No. ART-01-120-A-CD-5001 CONFIDENTIAL Date: 23-JUN-15 DESIGN CRITERIA Sheet! 20071 2.4 Material Selection 2.4.1 Equipment and Piping Design Life Guidelines Materials selection and corrosion allowances, in the absence of other directions (i.., Licensor requirements), should be based on the design life guidelines shown in Table 2.4.1. These design life guidelines are generally accepted in the petroleum industry. Per User Basis “Design of new facilities and reconfigured for a minimum 20-year lifespan’. If the 20-year lifespan requirement results in the selection of high cost materials, a deviation to the 20 year life may be acceptable with PEMEX approval. Table 2.4.1: Design Life Guidelines Equipment, Piping and Valves Life Span Years 7 Reactors 30 Pressure Vessels, Columns, Heat Exchanger Shells and Channels 20 Internals (non-removable) 20 Internals (removable) 10 Heat Exchanger Bundles (carbon and low alloy steel) 20 Air Cooler Headers 20 Furnace Tubes (as per API STD 530) 100,000 Hours ™ ‘Atmospheric Tanks 20 Pumps, Compressors 2077 General Service Piping (Carbon and low alloy steel) 20 High Alloy Piping (Stainless Steel and Nickel Alloys), Note 1 20 Valves 20 Notes: 1. Unless otherwise approved by PEMEX. 2. In the case that very high cost is encountered for alloys, lower life span and material selection may be studied. Study should be submitted to PEMEX for their approval 3. Based on design in the creep / rupture range. 4, Excluding normal wear parts. 2.4.2. Equipment and Piping Corrosion Allowance Corrosion allowance (CA) must be adequate to meet the design life guidelines and will be added to the equipment thickness for mechanical strength. The CA will be specified by the Licensor or ICA Fluor metallurgist based on the corrosive conditions the equipment is subject to during normal operation. Typical minimum CA's are provided in Table 2.4.2 for reference. PROCESS "ART-01-120-A-CD-5001_1.docx Distribution Code: A002 REPRODUCED, ANDIOR USED FOR A DIFFERENT PURPOSE FOR WHIGH IT WAS PREPARED WITHOUT PRIOR WRITTEN AUTHORIZATION FROM PEMEX REFNACION ORICA FLUOR™ 02-4014 RO-2401 Page 210 of 282CONFIDENTIAL Heie: SeuUNte et DESIGN CRITERIA Sheet: 21 de 71 Table 2.4.2: Typical Minimum Corrosion Allowance” Pressure Vessels, Heat Exchangers (Except Tubes) and Equivalent Equipment Material Corrosion Allowance (mm) Carbon steels (Notes 1, 6) 3.2 (0.125 inch) Carbon steels for amine and wet H-S services (Notes 1, 6) 3.2 (0.125 inch) Low alloy steels (Notes 2, 6) 3.2 (0.125 inch) Medium alloy steels (Notes 3, 6) 1.6 (0.0625 inch) High alloy steel (Notes 4, 5, 6) 1.6 (0.0625 inch) Non-ferrous materials (Notes 5, 6) 0.5 (0.021 inch) Vessels with clad or weld overlay (Note 6) 3.2 (0.125 inch) Furnace (Tubes & Fittings) Material Corrosion Allowance (mm) Carbon steel and alloys up to 9%Cr — 1%Mo 3.2 (0.125 inch) Low and medium alloy steels (Notes 2, 3) 3.2 (0.125 inch) High alloy steels 1.0 (0.042 inch) Piping Material Corrosion Allowance (mm) All Materials (Note 7) Notes: 1. Includes any type of carbon steel, even carbon-manganese alloy steels and micro-alloy steels. For amine andw et HS services, material selection corresponding corrosion allowance will be based on concentrations of fluid corrosive components and/or velocity criteria as appropriate. 2. Includes Cr - 4% Mo; 1% Cr = 6% Mo; 1%% Cr = ¥4% Mo, 2 14% Cr = 1% Mo and 5% Cr - A Mo alloy steels. Includes 9% Cr - 1% Mo alloy steels. Includes alloy steels with more than 9% Cr, including all types of stainless steel. 5. For special materials that have been selected due to fluid contamination considerations, the corrosion allowance may not be required. 6. Internal parts (removable) in the vessel will be provided with 50% on each side of the corrosion allowance required. Internal parts (non removable) will have the total corrosion allowance on each side. For stainless steel intemal part, the corrosion allowance may not be required 7. Piping CA will be s pecified by the Licensor or Fluor-ICA Fluor metallurgist based on corrosion rate at normal operating conditions and allowable life span of piping as indicated as NRF-032-PEMEX-2012, PROCESS "ART-01-120-A-CD-5001_1.docx Distribution Code: A002 REPRODUCED, ANDIOR USED FOR A DIFFERENT PURPOSE FOR WHIGH IT WAS PREPARED WITHOUT PRIOR WRITTEN AUTHORIZATION FROM PEMEX REFNACION ORICA FLUOR™ 02-4014 RO-2401 Page 211 of 282No. ART-01-120-A-CD-5001 Date: 23-JUN-15 DESIGN CRITERIA Sheet! 22071 CONFIDENTIAL Table 2, imum Corro: 'ypical n Allowance” Pressure Vessels, Heat Exchangers (Except Tubes) and Equivalent Equipment @. Corrosion Allowances for other equipment such reactors, storage tanks, pumps, compressors etc. will be specified by the Licensor or Fluor-ICA Fluor metallurgist based ‘on corrosion rate at normal operating conditions, allowable life span of equipment and/or other selection criteria 9. All corrosion allowance values selected must be confirmed by the Licensor/Contractor that they meet the guaranteed life of the equipment or material 2.4.3, Special Services The Material Selection Document and Process data sheets should carry a note if the vessel is in one of the following special services (Refer to NRF-028-PEMEX-2010 Annex 1 for additional information): + Hydrogen Service © Service with a H partial pressure equal or higher than 7.1 kg/cm’a. © He partial pressure equal or higher than 35.6 kg/cma should be considered in severe hydrogen service. Vessels or components in hydrogen service at temperatures of 200°C or higher, should be considered in severe hydrogen service + Amine Service © Service containing amine with concentrations of 2 wt% or more, under any condition. > MDEA operating above 80°C is considered severe Amine services. © All Vessels, Components or Equipment operating in amine service (non-severe or severe) in carbon steel or low alloy steels should be stress-relieved after welding. ‘+ Cyclic Service (Fluctuations in either temperature or pressure) + Sour Service © Service containing 50 ppm in total weight or more sulfur in aqueous phase. © Service containing 1 ppm in total weight of sulfur or more in aqueous phase and pH below 4. © Service containing 1 ppm in total weight of sulfur or more and 20 ppm in weight of cyanide or more in aqueous phase and pH > 7.6 © Service containing with partial pressure of H2S equal to or greater than 0.003, kg/om’a in gas phase associated to an aqueous phase of a process 0 Service containing an aqueous phase with more than 2 wt% NHsHS. © NACE MR 0103 requirements should apply to all sour services + Lethal Service (Only if specified by PEMEX) * Caustic Service - Service containing NaOH or KOH, at any concentration, and at a temperature over 45°C, ‘+ Hydrofluoric (HF) Acid Service PROCESS "ART-01-120-A-CD-5001_1.docx Distribution Code: A002 REPRODUCED, ANDIOR USED FOR A DIFFERENT PURPOSE FOR WHIGH IT WAS PREPARED WITHOUT PRIOR WRITTEN AUTHORIZATION FROM PEMEX REFNACION ORICA FLUOR™ 02-4014 RO-2401 Page 212 of 282No. ART-01-120-A-CD-5001 CONFIDENTIAL Date: 23-JUN-15 DESIGN CRITERIA Sheet! 23 de 71 Rev. 1 + Sulfuric Acid Service * Chlorine Service + Oxygen Service + Cyanide Service ‘+ Bisulfide Salt Service - Service containing 2 wt% or more of NH,Cl or NH.HS. Equipment and piping in amine, caustic and other services may require post weld heat treatment. Post weld heat treatment (stress relieving) requirements will be determined by the project metallurgist and noted on the unit material selection diagram and process data sheets. 2.5 Insulation and Winterization PEMEX standard NRF-034-PEMEX-2011, High Temperature Thermal Insulation for Equipment, Vessels and Surface Pipe, should be considered as insulation and winterization guidelines. The climate at the plant site is characterized by mild winters. Although the extreme minimum recorded temperature is 0°C, the concern of water freezing in small bore piping and instrument leads exists, The winterization criteria provided below is typical for plants in this climate zone and shall be used for the project. Piping Winterization Requirements: In general, winterization is not needed for normally flowing lines. Where winterization is a concern (Piping dead legs, for example), use the following guidelines. interization is required on normally non-flowing lines 2” and smaller in water (888)BeloW No winterization is required on piping 3° and larger regardless of whether it is or is not a normally flowing line. I PROCESS "ART-01-120-A-CD-5001_1.docx Distribution Code: A002 REPRODUCED, ANDIOR USED FOR A DIFFERENT PURPOSE FOR WHIGH IT WAS PREPARED WITHOUT PRIOR WRITTEN AUTHORIZATION FROM PEMEX REFNACION ORICA FLUOR™ 02-4014 RO-2401 Page 213 of 82No. ART-01-120-A-CD-5001 CONFIDENTIAL Date: 23-JUN-15 DESIGN CRITERIA Shoot 24 de 71 © Winterization (Heat Tracing) is required for acid gas lines and other similar services if condensation due to cold ambient conditions could lead to corrosion or possible operational upset. Free draining and non poc keted lines can be used in place of heat tracing for these services, where possible. + The Merox recirculation NaOH Caustic solution: Winterization (Heat Tracing) is required for drains, vents, PSVs, control valves (shut off and bypass valves ), online and on-vessels instrumentation. For continuous and always flowing lines winterization is not required; | ines with intermittent flow and dead! ines must be provided with winterization (Heat Tracing). + NaOH Fresh Caustic Solution 20%W and less: Winterization (Heat Tracing) is required for drains, vents, PSVs, control valves (shut off and bypass valves), on-line and on-vessels instruments. For continuous and always flowing lines winterization is not required; lines with intermittent flow and dead lines must be provided with winterization (Heat Tracing). + Merox Spent Caustic Solutions: Winterization (Heat Tracing) i s required for drains, vents, PSVs , control valves (shut off and bypass valves), on-line and on-vessels instrumentation. For continuous and always flowing lines winterization is not A\ _ ‘2quired; lines with intermittent flow and dead lines must be provided with winterization (Heat Tracing), ‘+ The lean MDEA solutions: Winterization (Heat Tracing) i s required for drains, vents, PSVs, control valves (shut off and bypass valves), on-line and on-vessels instrumentation. For continuous and always flowing lines winterization is not required; lines with intermittent flow and dead lines must be provided with winterization (Heat Tracing). + The rich MDEA solutions: Winterization (Heat Tracing) i s required for drains, vents, PSVs, control valves (shut off and bypass valves), on-line and on-vessels instrumentation. For continuous and always flowing lines winterization is not required; lines with intermittent flow and dead lines must be provided with winterization (Heat Tracing), Winterization for Equipment: ‘+ Winterizing shall not be provided for equipment in this project, Winterization for Instrumentation: ‘+ Winterizing shall be provided for instrumentation in water services to prevent ambient temperature adversely affecting operation and causing damage. Electric shall be used for tracing of instruments and impulse lines when required, PROCESS "ART-01-120-A-CD-5001_1.docx Distribution Code: A002 REPRODUCED, ANDIOR USED FOR A DIFFERENT PURPOSE FOR WHIGH IT WAS PREPARED WITHOUT PRIOR WRITTEN AUTHORIZATION FROM PEMEX REFNACION ORICA FLUOR™ 02-4014 RO-2401 Page 214 of 282No. ART-01-120-A-CD-5001 CONFIDENTIAL Date: 23-JUN-15, DESIGN CRITERIA Sheet! 25 de 71 3.0 Rev. 1 Steam Tracing versus Electric Tracing In general, steam tracing is preferred over electric tracing for piping. Low pressure steam shall be used for winterization tracing. Winterization by electric tracing may be utilized when a precise temperature control is required or where steam tracing is not practical or acceptable. This generally includes the following services’ + Rorless piping inofsite areas. © Acid piping Per NRF-032-PEMEX-2012 section 8.1.2.1.23, 9 piping with no thermal insulation system and an ‘operating temperature higher than 59°C or lower than -5°C in areas where personnel may come in contact with must have a barrier installed for their protection per NRF-034-PEMEX-2011 The heat losses defined in the NRF-034-PEMEX-2011 are the maximum allowable values of heat loss, if the required heat loses of the Licensor in piping and equipment are less than those shown ‘on the NRF-034-PEMEX-2011 reference, then the Licensor has to calculate his own specific isolation thicknesses, and these calculated thicknesses should not be less than the thickness mentioned in the Pemex specification (NRF-034-PEMEX-2011), In order to perform the thickness calculation, the environmental temperature to consider will be 20°C, Special Requirements PEMEX requires the use of Control Trace steam tracing for vacuum residue, liquid sulphur and tail gas piping. PEMEX requires the use of removable and reusable insulation, according to the calculated thickness andthe requirements specified in the NRF-034-PEMEX-2011. Also the thermal insulation of the lines and main process equipment and services must have ports for thickness measurement according to DG-SASIPA-SI-0204, with removable lid and sealed to prevent moisture penetration. EQUIPMENT DESIGN GUIDELINES 3.1 Vessels, Reactors and Columns 3.1.1 General Requirements. Vessels, Reactors and Columns should be designed in full accordance with the appropriate standards listed below: ‘+ NRF-028-PEMEX-2010 Design and Construction of Pressure Vessels, + NRF-136-PEMEX-2011 Process Towers, Trays and Internals 3.1.2 Design Pressure Refer to Section 2.1.1 for general guidelines. PROCESS "ART-01-120-A-CD-5001_1.docx Distribution Code: A002 REPRODUCED, ANDIOR USED FOR A DIFFERENT PURPOSE FOR WHIGH IT WAS PREPARED WITHOUT PRIOR WRITTEN AUTHORIZATION FROM PEMEX REFNACION ORICA FLUOR™ 02-4014 RO-2401 Page 215 of 282No. ART-01-120-A-CD-5001 CONFIDENTIAL Date: 23-JUN-15 DESIGN CRITERIA Sheet! 26071 3.1.3 Design Temperature (Ref. NRF-028-PEMEX-2010, paragraph 8.1.3) + The Minimum Design Metal Temperature (MDMT) should not be less than the recorded minimum ambient temperature at the location (0°C). The MDMT that is determined for the vessel or for the vessel component should be shown on the name plate, at the coincidental MAWP. The MDMT should be considered for each coincidental MAWP for all possible scenarios. + The maximum and minimum DT should not be higher or lower than the respective minimum and maximum temperature permissible by the material of construction, so that the stress will not exceed the allowable limits at the DT. * Refer to Section 2.2 for general guidelines, 3.1.4 Equipment Isolation Include bypass and the blocks required to isolate the operating equipment for maintenance, without shutting down the plant, where applicable. 3.1.5 Column Sizing In addition to NRF-136-PEMEX-2011, the following general practices are to be considered: + Except for specifically justified applications, valve trays should be specified for columns. Column sizing should be based ona maximum of 85% of jet flood and a maximum downcomer backup of 50% al normal capacity. Vendor standard flooding correlations should be used. It should be noted that some applications such as amine treating may require more stringent flooding criteria due to foaming tendencies or other known operating issues. Derating factors should be applied in accordance with the service following internals vendor recommendations. ‘+ Allowance should be made for system derating factors to reflect actual experience with certain systems that display tendencies towards foaming or other anomalous behavior. ‘+ Minimum inside diameter for trayed columns shall be 800 mm. There is no minimum diameter for packed columns. 3.1.6 Design Considerations The following design guidelines are to be taken into consideration: ‘+ Vessel/column inside diameters will be specified in increments of 50 mm. Tangent-to- tangent lengths will be specified in increments of 100 mm. The use of vendor standard head sizes will be considered where a cost savings can be justified. Vendor should provide support documentation for evaluation and acceptance from PEMEX prior to implementation ‘+ Vessels with small diameters should consider standard pipe sizes for shell material ‘+ Maximum and normal liquid levels and alarm and shutdown levels should be specified from bottom tangent line for columns and vertical vessels, and from the bottom for horizontal vessels. PROCESS "ART-01-120-A-CD-5001_1.docx Distribution Code: A002 REPRODUCED, ANDIOR USED FOR A DIFFERENT PURPOSE FOR WHIGH IT WAS PREPARED WITHOUT PRIOR WRITTEN AUTHORIZATION FROM PEMEX REFNACION ORICA FLUOR™ 02-4014 RO-2401 Page 216 of 282No. ART-01-120-A-CD-5001 CONFIDENTIAL Date: 23-JUN-15 DESIGN CRITERIA Sheet! 27071 ‘+ Height of bottom tray above bottom tangent line should be given for columns. + Tray spacing depends on the service and is to be reviewed on a case by case basis, Typical industry guidelines for minimum tray spacing are provided in Table 3.1.1 for reference. Table 3.1.1: Minimum Tray Spacing ‘Tower Diameter Minimum Tray Spacing (mm 1D) (mm) ‘900 — 4900 610 4900 = 8400 750) > 8400 900) ‘+ Tray spacing less than 610 mm but not less than 450 mm will be considered for clean, non-foaming services. Reduced tray spacing should only be considered in small diameter columns as inspection will require complete tray removal. For special applications tray spacing of less than 450mm may be considered with PEMEX approval. + Tray spacing should be greater than the minimum shown above where required for access to column intemals, vapor disengaging, nozzle interference or other reasons. ‘+The minimum tray spacing at manway locations should be 750 mm ‘+ Minimum distance from top of tray to top tangent should be 750 mm or as required to accommodate the manway, internals, nozzles or other criteria such as vapor liquid disengagement. ‘+ Column trays should be numbered from top to bottom. ‘+ Design should consider earthquake and wind conditions. 3.1.7 Vessel and Column Internal Details Vessel and column internal details should be in full accordance with NRF-0136-PEMEX-2011 Process Towers, Trays and Internals, with respect to: 1) materials, 2) internals design, 3) manufacture, 3) operation, 4) inspection, 5) testing and 5) shipping guarantees 3.1.8. Skirt Height Required skirt heights above grade will be set by process conditions (e.g. pump NPSH). ‘When skirt height is not influenced by process factors, it will be specified at a minimum of 800 mm, or as required to accommodate piping. Dimensions should be rounded up to the nearest 100 mm. 3.1.9 Nozzles, Boots and Manways In addition to paragraph 8.1.10 of NRF-028-PEMEX-2010, the following general practices are to be considered: A. Inlet/Outlet Nozzle Design Considerations The following items should be considered when specifying equipment nozzles: PROCESS "ART-01-120-A-CD-5001_1.docx Distribution Code: A002 REPRODUCED, ANDIOR USED FOR A DIFFERENT PURPOSE FOR WHIGH IT WAS PREPARED WITHOUT PRIOR WRITTEN AUTHORIZATION FROM PEMEX REFNACION ORICA FLUOR™ 02-4014 RO-2401 Page 217 of 282No. ART-01-120-A-CD-5001 CONFIDENTIAL Date: 23-JUN-15, Sheet: 28 de 71 DESIGN CRITERIA Rot * Nozzles should be sized by line sizing criteria or the maximum velocity limitations, whichever is controlling, + Liquid level column connections should be provided on the bottom section of all columns, accumulators, surge vessels, and coalescers. A separate liquid level should be provided for the high level shutdown of compressors as this control should be exclusive to the shutdown protection and must be independent of any measurement or control functions. This requirement shall also apply to any shutdown, such as low level XV closure or any other Emergency Shutdown (ESD) related device, * Bottom liquid level column connections should be in a hor izontal position, and located above the bottom of the vessel to prevent plugging and water pockets. * Hydrocarbon pump suction nozzles should be provided with an elevated vortex breaker if water is present or a bottom flush vortex breaker if no water is present. * Water pump suction nozzles should be provided with bottom flush vortex breaker. * Pump suction nozzles in horizontal vessels should be located in the opposite end of the vessel from the inlet. + Unless otherwise specified, nozzles for liquid suction should be fitted with a vortex. protection device. Also they should be arranged to prevent the ingress of foreign bodies (vertically project beyond the inner wall of the head of the vessel, offset relative to the head of the vessel, etc,) and permit full draining of the vessel. Withdrawal from intermediate draw-off trays should be from a sump directly through an external nozzle. Drawoff piping should have a vertical run immediately after the nozzle. Minimum vertical run length is 3 meters. On a vessel that is equipped with an internal float of any kind, each nozzle at the bottom of the vessel should be protected with a suitable guard designed to prevent a loose float from lodging over the nozzle opening. A vortex breaker may be modified for this service. On vertical vessels supported by a skirt, the use of any flanged assembly inside the skirt should not be permitted. Vessel nozzles on equipment should be specified according to the following typical industry guidelines as shown in Table 3.1.2. PROCESS "ART-01-120-A-CD-5001_1.docx Distribution Code: A002 REPRODUCED, ANDIOR USED FOR A DIFFERENT PURPOSE FOR WHIGH IT WAS PREPARED WITHOUT PRIOR WRITTEN AUTHORIZATION FROM PEMEX REFNACION ORICA FLUOR™ 02-4014 RO-2401 Page 218 of 282No. ART-01-120-A-CD-5001 Date: 23-JUN-15 DESIGN CRITERIA Sheet! 20071 CONFIDENTIAL Table 3.1.2: Maximum Allowable Nozzle Velocities Maximum Nozzle Description Nome Allowable Velocity (mis) z 1 3 14 a 15 Column Bottom Outlet 6 18. e 2.0 107 23 Esra 24 122 Column Feed (Note 1) a Bottom Suction Box | Liquid Falling From Above 03 (Note 2) Liquid from Quiet Zone 06 Liquid Falling From Above |_0.91m 12 (Note 3) 0.76m 09 061m 06 0,30m 0.3 Side Draw to Pumps 0.15m 0.2 (Note 2) Liquid from Quiet Zone 061m 12. (Note 3) 0.46m 0.9 0.30m 06 0.15m 03 om 0.2 Notes: 41, Density in kg/m, density of average mixture at flow conditions. 2. This limitation is set to prevent trapped vapors from getting into the pump. All column side draws must turn down immediately for a minimum of 3 m. The first 3 m of piping should be the same size as the draw-off nozzle. The line can then be reduced to the normal line size, A note to this effect should appear on the P&ID’s. 3,_Minimum liquid height above top of draw-off nozzle, m. The following table defines the connections for instrumentation on vessels and piping to be followed. For additional information regarding instrumentation connection and appurtenances please refer to relevant Control Systems Design Bases. PROCESS "ART-01-120-A-CD-5001_1.docx Distribution Code: A002 REPRODUCED, ANDIOR USED FOR A DIFFERENT PURPOSE FOR WHIGH IT WAS PREPARED WITHOUT PRIOR WRITTEN AUTHORIZATION FROM PEMEX REFNACION ORICA FLUOR™ 02-4014 RO-2401 Page 219 of 282No. ART-O1-120-A-CD-5001 CONFIDENTIAL Date: 23-JUN-15 DESIGN CRITERIA Sheet! 30de 71 Rev_t a conan] Comins “e G ntomento Cones det froceso wer | Recperte (200 ry” | Sat min Tea Ge TOS FST TBikado SWS Roscado NPT - oe SERIE Ge HV STIRS TS SORPT = Fae Traicador Ge Fiver Wagnétes (eonenton | Bridado (7) A latera-tateral), - a) a) om Deere - 3 “arama Ge We Bo Rasa Wipe 6 | F Brida) aaa omc) - Te Se He Be Oa] FETE reine aaa BRT” Grs | BRGRISTT ; Guiada Camara Externa = > Braco Taran RT po Cpactanan | F BOGS TT : Faas os = Camara Cana (ee wes) - Z “rane —o_ Riel Wo DSOSaERGOr F BRETT Te Cones super | - “Transco de vel Woo PreSiSn DASTSNGT| PTT = od Teananir Ge Nive oo PSE BUSTER | Baa a ton Seto de Daag : Pas Ge HNATT Dee ra Seeues ar waves - ‘bromides en tama | ~ f oo TREES TERT STF Tana os POSS SENET SREP Gatragma (4) - Sener Tanai Se Ta ps FSS DST EET = aris Ge Ras bs Wess (aa) [Brena = = fla prema sera ge 9 NPT. 2. La cenewdn de fs plema Ge nivel seré de 2" y posed ser de 3° con conesiones de 2° cuando se instaion varies nstrimenton 3. Loe mandmezos poaran montarse en plemas de nivel pero no se usaré a conexién de venteo. ©. Para conexin superior se requere Tubo guia para instumentos de nivel montados Internamente 7._No se requiere Tubo quia a PROCESS "ART-01-120-A-CD-5001_1.docx Distribution Code: A002 “THs DOCUMENT CONTAINS PROPRIETARY AND CONFIDENTIAL INFORMATION WHICH SHALL NOT BE PUBLISHED, DISCLOSED TO OTHERS, REPRODUCED, ANDIOR USED FOR A DIFFERENT PURPOSE FOR WHICH IT WAS PREPARED WITHOUT PRIOR WRITTEN AUTHORIZATION FROM PEMEX REFNACION ORICA FLUOR™ 02-4014 RO-2401 Page 220 of 82No. ART-01-120-A-CD-5001 CONFIDENTIAL Date: 23-JUN-15 Sheet: 31 de 71 DESIGN CRITERIA Roa The nozzle schedules on the process design data forms shall be marked with the appropiate symbols for the nozzles as shown below. NOZZLE SYMBOLS F Eunetion B Iniets. Outlet Condensate Drain or Draw-off Feed Level Gauge or Gauge Glass Handhole Pumpout Level Instrument Manway Reboiler Connection Pressure Connection Reflux ‘Steam or Sample Connection ‘Temperature Connection (A’so TI, TE, TW) \Vapor or Vent Relief Valve Connection (oversize unless actual size known) 4onvzzracronmooe> << Use E or K when none of the other symbols apply. Do not use I, O, Q, U, X, Y, orZ. S B. Manways and Inspection Openings Manways and inspection openings should be in full accordance with paragraph 8.1.11 of NRF-028-PEMEX-2010 Design and Construction of Pressure Vessels, see selected excerpt below: * All vessels should have at least one manway or opening cover. Only when the dimensions of the vessel do not permit the installation of a manway and doesn't have removable internals should the installation of at least 2 inspection hand holes. of 10 in minimum allowed. + The minimum DN for the manways should be: © 18 inches of nominal diameter for vessels with diameter from 910 to 1015 mm or 20 inches nominal diameter if the vessel has removable internals or at least one hatch at the top for vessel opening. © 20 inches of nominal diameter for vessels with diameter from 1015 to 1520 mm. © 24 inches for vessels with diameter 1520 mm and greater. PROCESS "ART-01-120-A-CD-5001_1.docx Distribution Code: A002 REPRODUCED, ANDIOR USED FOR A DIFFERENT PURPOSE FOR WHIGH IT WAS PREPARED WITHOUT PRIOR WRITTEN AUTHORIZATION FROM PEMEX REFNACION ORICA FLUOR™ 02-4014 RO-2401 Page 221 of 82No. ART-01-120-A-CD-5001 CONFIDENTIAL Date: 23-JUN-15 Sheet: 32de 71 DESIGN CRITERIA pret + Vessels with the intemals that have to be periodically removed (fiters, baskets, others) should have at least a hatch for quick opening + The manways located on the vessel or its section filled with random packing or with other bulk material, as well as the discharge nozzles, should be provided with a retention plate. In addition to paragraph 8.1.11 of NRF-028-PEMEX-2010, the following general practices are to be considered: + Horizontal vessels with compartments should be provided with openings on the separation walls to allow access to the annex compartments. + Columns should be provided with at least the following manways: © Shell lower section © Shell upper section © Flash zone (feed tray) © Each draw-off tray © Vessels with trays should have at least 1 manway for every 10 trays + Packed vertical vessels should have a manway at the top of each packed bed for filling. A manway should also be provided below the packing support of the lowest bed. + Nominal diameter for manway nozzles is 24°. All vessel internals should be specified to fit through 24” nominal manways €. Vent, Drain, Purge and Isolation Provisions The following design guidelines are to be taken into consideration + Provision for maintenance blinds should be made at all equipment nozzles, The use of spectacle blinds vs. paddle blinds/spacers is a function of piping size and flange rating. Blinding points (no permanent facilities) will be used where sufficient piping flexibility exists to insert paddles/spectacle blinds as required for maintenance purposes. Blinds and blinding points should be identified on the PaID's. + Provide all the piping spools so that the spectacle flanges can be properly shift without causing problems on stud bolts, lack of support, etc + Safety relief valve nozzles / takeoffs may be located on the vessel, vessel nozzle, or overhead piping, as a preference located where vapor or gas phase always being present. Major factors affecting pressure safety valve nozzle location are discharge destination, accessibility to the valve, and structural support. + All process vessels should be provided with process vent, process drain and vessel purging connections as follows: © The connections should be sized per typical industry guidelines, according to vessel volume as indicated in Table 3.1.3. PROCESS "ART-01-120-A-CD-5001_1.docx Distribution Code: A002 REPRODUCED, ANDIOR USED FOR A DIFFERENT PURPOSE FOR WHIGH IT WAS PREPARED WITHOUT PRIOR WRITTEN AUTHORIZATION FROM PEMEX REFNACION ORICA FLUOR™ 02-4014 RO-2401 Page 222 of 282No. ART-01-120-A-CD-5001 CONFIDENTIAL Date: 23-JUN-15 DESIGN CRITERIA Sheet! 98071 © Drains, including those for level gauges and level controllers, for butane or lighter ‘compounds should be piped to the flare header or a closed drain system. © Vents for light hydrocarbon service or materials above their flash points should be piped to the flare system or to a closed draining system However additional vents to atmosphere should be provided with blind flange. © All steam out connections will be hard piped. Steam out connections should be located 200 mm above the bottom tangent line on towers and vertical drums and 300 mm above the bottom of horizontal drums. The connections should be provided with a block valve, check valve and blind flange. © All nozzles should be flanged and have @ minimum nominal diameter of 2 inches Table 3.1.3: Vessel Drain, Vent and Steam-out Connection Sizes in Inches Vessel Volume Drain Line ‘Steam-out Process Vent cubic meter Connection Connection Connection 300 6 3 6 3.1.10 Hold-Up and Surge Times The following design guidelines are to be taken into consideration: Hold-up time is defined as the time it takes to reduce the liquid level from normal (NLL) to low (LLL) while maintaining a normal liquid outlet flow without feed makeup. This hold-up time must account for the quality of control and reliability of the upstream facilities as well as the transport means between two facilities. Surge time is defined as the time it takes for the liquid level to rise from normal (NLL) to high (HLL) while maintaining normal feed makeup without outlet flow. Surge time provides a response cushion between inflow and out flow rates, thereby partially insulating each flow against undesirable effects from disturbances to the other. This surge capacity permits operating controls to adjust to the change and allows for response at arate least apt to propagate adverse effects into other sections of the system. In some cases surge time is to prevent a sudden shutdown of the upstream facilities in the case of a reduction of flow to the downstream facilities. The typical industry guidelines for hold-up and surge time provided in Tables 3.1.4 thru 3.1.9 are to be considered: PROCESS "ART-01-120-A-CD-5001_1.docx Distribution Code: A002 REPRODUCED, ANDIOR USED FOR A DIFFERENT PURPOSE FOR WHIGH IT WAS PREPARED WITHOUT PRIOR WRITTEN AUTHORIZATION FROM PEMEX REFNACION ORICA FLUOR™ 02-4014 RO-2401 Page 223 of 282No. ART-01-120-A-CD-5001 Date: 23-JUN-15 34 de 71 CONFIDENTIAL DESIGN CRITERIA Shoot Table 3.1.4: Recommended Hold-Up Time: Feed to Units Hold-Up Time, NLL to LLL Minutes. Wide variation: tank vapor recovery system, batch operations, and unsteady multiple feeds such as a waste water system, condensate, etc. 30-240 Minor short time interruptions; feed from a delayed coker where the coke drums are switched on & off line or similar systems that are switched on & off line @| 20 intervals of < 2 days. Table 3.1.5: Recommended Hold-up / Surge Times: Controlled Feed from Other Units an Hold-UpNLLtoLLL | Surge NLL to HLL (minutes) (minutes) Controlled Feeds From Other Units | cote. | anoiner Gomplex Upstream unit has poor control (Yield variations) 16 2 5-10 Upstream unit has fair control (Unsteady operation on level 10 18 3-78 control) Upstream unit has good control (Steady operation on level orflow | 7.8 10 3-5 control) ‘A unit feed drum should be provided if the upstream unit(s) does not provide the recommended hold-up and surge or if the feed control system is not adequate for the requirements of the downstream unit. When the feed to a unit comes from a number of sources, the feed drum hold-up time may be proportioned by the feed volume and reliability of each upstream facility Example: 20% from Coker 0.2.x 20min. = 4 minutes 50% from Storage 0.5.x 10min. = 5 minutes 30% from Crude Unit __0,3x 15 min, = 5 minutes Total Hold-up Required 14 minutes PROCESS "ART-01-120-A-CD-5001_1.docx Distribution Code: A002 REPRODUCED, ANDIOR USED FOR A DIFFERENT PURPOSE FOR WHIGH IT WAS PREPARED WITHOUT PRIOR WRITTEN AUTHORIZATION FROM PEMEX REFNACION ORICA FLUOR™ 02-4014 RO-2401 Page 224 of 282No. ART-01-120-A-CD-5001 Date: 23-JUN-15, DESIGN CRITERIA Sheet! 364071 CONFIDENTIAL Table 3.1.6: Recommended Hold-up / Surge Times: Equipment Inside a Unit Hold. ei jold-Up NLL to LL | Surge NLL to HLL (minutes) (minutes) Chimney trays 3 1 Condensate Pot 15 1 Feed to a cislillation column 5 2 Feed to a furnace 10 2 Feed to a low head charge pump 5 3 Feed to a high head multiestage pump 10 3 KO drums“ 5 2 Reflux Drum ‘+ Reflux on Flow Control 3 2 + Reflux on Temperature Control 4 2 +_ Reflux on Level Control 5 2 Refrigerant flash drum 2 1 Product direct to off-plot storage tank = w/ pump 5 2 +_wlo pump 2 1 ‘Steam Drum (Horizontal vessel) 15 5 Water Boot 5 3 Notes: 1. For dry KO drums, set surge volume equal to the equivalent of 8 m of liquid slug, based on the diameter of the inlet pipe. PROCESS "ART-01-120-A-CD-5001_1.docx Distribution Code: A002 REPRODUCED, ANDIOR USED FOR A DIFFERENT PURPOSE FOR WHIGH IT WAS PREPARED WITHOUT PRIOR WRITTEN AUTHORIZATION FROM PEMEX REFNACION ORICA FLUOR™ 02-4014 RO-2401 Page 225 of 282No. ART-01-120-A-CD-5001 CONFIDENTIAL Date: 23-JUN-15, DESIGN CRITERIA Sheet! 96071 Table 3.1.7: Recommended Hold-Up / Surge Times for Column Draw-offs: Hold-Up ‘Surge Service NLL to LLL | NLL to HLL (minutes) | (minutes) Liquid is withdrawn by level control and feeds another column directly by pressure § 2 Liquid is withdrawn by level control and pumped away + Spare pump starts manually 5 2 + Spare pump starts automatically 2 2 Liquid is withdrawn by level control 2 2 Liquid is withdrawn by level control and feeds a unit that is, some distance away or that has instruments on a different 57 2 control room. Liquid is withdrawn by flow control 35 2 Liquid flows through a thermosyphon reboiler without a level controller to maintain a level in the sump Table 3.1.8: Recommended Hold-up / Surge Times: Fired Heater Reboilers based on Bottoms Flow Bottoms as % of Food ae ana ene 70 4 - 60 5 - 50 6 - 40 7 - 30 8 - 20 9 - 10 10 - Distribution Code: A002 REPRODUCED, ANDIOR USED FOR A DIFFERENT PURPOSE FOR WHIGH IT WAS PREPARED WITHOUT PRIOR WRITTEN AUTHORIZATION FROM PEMEX REFNACION ORICA FLUOR™ 02-4014 RO-2401 Page 226 of 282No. ART-01-120-A-CD-5001 Date: 23-JUN-15 DESIGN CRITERIA Sheet! 97 de71 CONFIDENTIAL Table 3.1.9: Recommended Hold-Up / Surge es: Kettle Type Reboilers. i Full Volume Service (minutes) Product (bottoms) directly to storage + Control Valves 1/2" to 2" 1 + Control Valves 3” to 4” 15 + Control Valves > 6” 2 Product (bottoms) goes thru exchanger then storage 2 Bottoms feeding another column 2 Fired Heater Reboilers For fired heater reboilers, some additional special considerations are listed below: ‘+ Bottoms product outlet control valve must close on air failure + Low level alarms are required + Locate temperature monitor as close to heater outlet as possible ‘+ Bottoms internal design should avoid once through flow to a fired reboiler ‘* Fuel to reboiler cut-off, or automatic turbine pump start on either low flow or low pressure on reboiler feed, are desirable, The elevation difference between LLL and LLLL and HLL and HHL for alarms and trips should be a minimum of 250 mm or be adequate to allow two minutes for operator response time, whichever is greater. 3.1.11 Tank Storage Times The following design storage times of final products, intermediate products and raw materials are Service Time (Days) Raw Materials 7 Products 5 Intermediates Products 3 3.1.12 Other Maintenance Provi ns Davits are required for tower manways. Tower ladders and platforms should be arranged to provide access to all manways, blinds, operating valves, emergency valves and instruments PROCESS "ART-01-120-A-CD-5001_1.docx Distribution Code: A002 REPRODUCED, ANDIOR USED FOR A DIFFERENT PURPOSE FOR WHIGH IT WAS PREPARED WITHOUT PRIOR WRITTEN AUTHORIZATION FROM PEMEX REFNACION ORICA FLUOR™ 02-4014 RO-2401 Page 227 of 282No. ART-01-120-A-CD-5001 CONFIDENTIAL Date: 23-JUN-15, DESIGN CRITERIA Sheet! 98071 3.2. Heat Exchangers 3.2.1 General Requirements licable Standards and Practices Heat exchangers should be designed in accordance with the appropriate standards listed below in conjunction with the appropriate job narrative specification: A\* _ NRF-090-PEMEX-2013 Shell and Tube Heat Exchangers « NRF+134-PEMEX-2012 Air Cooled Heat Exchangers A. Heat Release Curves Heat release curves are required for condensers and vaporizers if the curve is not linear. The plot should also show the vapor or liquid rates, vapor molecular weight, and liquid gravity. P hysical properties must be provided separately for each phase (ie. vapor, hydrocarbon liquid, water). B. Design Pressure Design Pressure should be in full accordance with paragraph 8.2.2 of NRF-090-PEMEX- A\ 2018 Shell and Tube Heat Exchangers. Refer to Section 2.1 for general guidelines. . Design Temperature Design Temperature should be in full accordance with paragraph 8.2.3 of NRF-090- A\ PEMEX-2013 Shell and Tube Heat Exchangers, see selected excerpt below: + The design temperatures for both sides of the heat exchanger should be as shown on the data sheet, requisition, bidding and / or fabrication documentation. When it is nol indicated for these parts, it should be determined as follows and should be included on the data sheet. + The design temperature for heat exchangers operating at or below 0°C should be the minimum expected operating temperature. * The design temperature for heat exchangers operating above 0°C should be the greater of the following two values: © Maximum operating temperature plus minimum 28°C. © Minimum design temperature of 37.8°C. + For temperatures above 0°C, the design temperature of the tubesheet, tubes, internal floating head components, and other similar parts under pressure should be equal to the greater of the design temperature for the shell side or tube side. For temperature below 0°C, the design temperature of these components should be the equal to the lesser of the design temperature for the shell side or tube side. + The temperature used to determine the differential thermal expansion in the design of fixed tubesheets should be the shell side and tube side metal temperatures. Exchanger startup and shutdown operations should also be considered as part of, the design conditions. PROCESS "ART-01-120-A-CD-5001_1.docx Distribution Code: A002 REPRODUCED, ANDIOR USED FOR A DIFFERENT PURPOSE FOR WHIGH IT WAS PREPARED WITHOUT PRIOR WRITTEN AUTHORIZATION FROM PEMEX REFNACION ORICA FLUOR™ 02-4014 RO-2401 Page 228 of 282No. ART-01-120-A-CD-5001 CONFIDENTIAL Date: 23-JUN-15 Sheet: 39de 71 DESIGN CRITERIA pret D. Instrumentation Heat exchangers (coolers, condensers, etc.) should include all the necessary instrumentation to carry out statistical analysis of their efficiencies. The instruments should have signal to DCS, and should include field instrumentation E. Miscellaneous + Include bypass and the blocks required to isolate the operating equipment for maintenance, without shutting down the plant, where applicable. + Facilities should be provided to back wash condensers that use cooling water. + Cooling water availability is limited, so air coolers use should be maximized. Air coolers design should consider a minimum outlet process temperature of 55 °C. 3.2.2 Shell and Tube Exchanger Design Criteria In addition to NRF-090-PEMEX-2093, the following general practices are to be considered A. General Requirements AN For ashell and tube exchanger, consideration should be given to set the differential pressure so that water will not leak to hydrocarbon or feed will not leak to product Maximum size for shell and tube exchangers with removable bundles should be as shown below. The thermal designer may consider larger sizes to realize economic or design advantages with PEMEX approval. * Maximum diameter: 2.0 meters. + Maximum length: 7.9 meters for large diameter bundles, 6.1 meters for bundle sizes 1.2 meters and less. + Maximum bundle weight: 27,000 kg. + Shell and tube exchangers with non removable bundles may be larger than the above, Final size should consider maintenance access and construction requirements. * Outside tube diameter should be %" unless, because of pressure drop, fouling, etc,, itis necessary to use 1” OD, + Unless greater tube thickness is required by design conditions or specified in the datasheets, the following typical industry standard values should be used as minimum tube gauges: PROCESS "ART-01-120-A-CD-5001_1.docx Distribution Code: A002 REPRODUCED, ANDIOR USED FOR A DIFFERENT PURPOSE FOR WHIGH IT WAS PREPARED WITHOUT PRIOR WRITTEN AUTHORIZATION FROM PEMEX REFNACION ORICA FLUOR™ 02-4014 RO-2401 Page 229 of 282No. ART-01-120-A-CD-5001 Date: 23-JUN-15 DESIGN CRITERIA Shoot 40de 71 CONFIDENTIAL Table 3.2.1: Minimum Recommended Exchanger Tube Wall Thickness Tube Material BWG for d.= 3/4" | BWG for d. Ferritic Alloy Steel up to and including 9% Cr 14 2 Ferritic Alloy Steel 12% Cr 16 14 Austenitic Duplex Stainless Steel 18 16 Copper Alloys 16 14 ‘Aluminum 14 2 Monel 18 16 Incoloy 18 16 Titanium 20 18 + Fixed tubesheet exchangers may have triangular or square pitch. + Removable tube bundles should be square (90°) or square rotated (45°) pitch and with a minimum distance between tubes of 6.35 mm (0.25") + For water cooled exchangers the maximum inlet temperature for the process fluid should not exceed 100°C. A lower temperature is normally expected, since upstream air cooling (where feasible) will be used to reduce the temperature. + Preferred minimum velocity: 1.8 m/s tube side, 0.6 m/s shell side. + The maximum cooling water return temperature should be per the project Basic Engineering Design Data (BEDD) document (Doc No, ART-01-120-A-BD-0001) * Fouling factors should be selected based on standard industry guidelines or Licensor requirements. For utility systems, the following recommended fouling factors should be considered: © Cooling Water: 0.0006 hr m? °C / kcal © Boiler Feedwater: 0.0002 hr m? °C / kcal © Steam (Clean): 0.0001 hr m? °C / kcal B. TEMA Type Limitation preferences in the use of different types of exchanges and TEMA designations include: + Hairpin type exchanges (double pipe or mullictube) could be specified as an alternative to TEMA type or equivalent heat exchangers when the expected area is. less than 20 m? + Heat exchangers with fouling factor larger than 0.0001 hr m? °Cikcal should have removable bundles. + Those fluids, whose fouling factor is equal or less than 0.0001 hr m? °C/keal, can be considered as clean fluid. For these fluids on the shell side fixed tubes sheet can be specified with the prior approval of PEMEX. * Channels should generally have a removable cover in accordance with TEMA type A or equivalent. The TEMA B type model or equivalent with an integrated head PROCESS "ART-01-120-A-CD-5001_1.docx Distribution Code: A002 REPRODUCED, ANDIOR USED FOR A DIFFERENT PURPOSE FOR WHIGH IT WAS PREPARED WITHOUT PRIOR WRITTEN AUTHORIZATION FROM PEMEX REFNACION ORICA FLUOR™ 02-4014 RO-2401 age 230 of 282No. ART-01-120-A-CD-5001 CONFIDENTIAL Date: 23-JUN-15 DESIGN CRITERIA Shoot 41 de 71 (bonnet) may be used for non-corrosive clean services with U-tubes bundles. In the case of high pressure designs (>70 kg/cm’ g), type D heads will be evaluated by Licensor/Contractor for use in lieu of type B heads. Type C heads will not be allowed, U-tubes can be used when the tube side fouling factor is less than or equal to 0,0006 hr m? *C/keal and the corrosiveness level of the fluid outside is light or medium or if, for process reasons, it is desirable to minimize the number of closures. The longitudinal baffle type corresponding to TEMA types G and H is acceptable when applied to condensation or vaporization on the shell side with a maximum pressure drop of 0.15 kg/cm’, The following configurations may be used with prior written approval from PEMEX: © Tube bundles with one pass shell, floating head and seal packed type P and W or equivalent. © Longitudinal baffle (TEMA type F or equivalent), It is preferred that cooling water and dirty fluids be placed on the tubeside for easier cleaning. On cooling water service the exchanger should be provided with 2 inches size chemical cleaning nozzles at inlet and outlet exchanger nozzles. Besides at inlet and outlet exchanger nozzles a Pl connection and a TI thermowell connection should be provided, For more details please refer to NRF-090-PEMEX- A\ 2048, paragraph 8.2.5.4. + Itis preferred that high viscosity fluids are placed on the shell side. * Fluids that contain solids in suspension (slurry) should flow in the tubeside and in a downward direction C. Allowable Pressure Drop As a guideline, the recommended allowable clean pressure drop per shell for shell and tube exchangers in pumped liquid service should be as follows: Table 3.2.2: Allowable Differential Pressure for Shell and Tube Exchangers iscosity Allowable AP (cP) Shell Side (kg/cm’) Tube Side (kg/cm’) <1.0 0,15 - 0.35 0,35 - 0.70 1.0-5.0 0.35 - 0.50 0.50 - 0.70 5-15 0.50 - 0.70 0.70 - 1.05 15-25 0.70 1.05 4,05 — 1.40 25-50 1.05, 1.75, > 50 Heat Transfer Engineer to Specify An appropriate safety factor should be appl ied to the hydraulic loop calculations to account for fouled service. PROCESS "ART-01-120-A-CD-5001_1.docx Distribution Code: A002 REPRODUCED, ANDIOR USED FOR A DIFFERENT PURPOSE FOR WHIGH IT WAS PREPARED WITHOUT PRIOR WRITTEN AUTHORIZATION FROM PEMEX REFNACION ORICA FLUOR™ 02-4014 RO-2401 Page 231 of 282No. ART-01-120-A-CD-5001 CONFIDENTIAL Date: 23-JUN-15, DESIGN CRITERIA Shoot 42 de 71 For problematic, high fouling service, the fouled pressure drop may be roughly estimated as: © Shell side = AP clean * (0.6/V,)? © Tube side = AP clean * (2/V,)* © Where V, and V; are the shell and tube side velocities in mis respectively For other services, the fouled pressure drop may be roughly estimated with aclean pressure drop multiplier based on the fouling factor as follows: Table 3.2.3: Estimated Fouled Exchanger Pressure Drop Fouling Resistance, (hr m?*Cikcal) _| Multiplication = 0.00040 on shell side 1 = 0.00040 on tube side with alloy tubes or 14 carbon steel in non corrosive service : <0,00040 on tube side where some pitting 12 and corrosion is expected. : 0.00040 — 0.0010 on either shel or tube side 12 > 0.0010 15 The allowable pressure drop for cooling water exchangers should be 1.0 kg/cm* on the cooling water side. Calculated pressure drop shall be as close to 1.0 kg/cm’ as possible to ‘ensure significant mal-distribution does not occur in the cooling water network. Allowable pressure drop for process side of shell and tube condensers should be as follows: Table 3.2.4: Allowable Differential Pressure for Shell and Tube Condensers ‘System Pressure, (kgicm’g) | Allowable AP, (kg/cm’) 3.50 0,10 - 0.15 per shell 3.50 - 14.00 0.15 - 0.35 per shell 3 14.00 (0.35 per shell Allowable pressure drop for multiple exchanger services in series may be specified for the entire train, instead of item by item. 3.2.3. Air Cooler Design Criteria A |g in addition the following general practices are to be considered: A. General Requirements * NRF-139-PEMEX-2012 Concrete Supports for Piping, should apply for the sizing of structures on piperacks inside process plant battery limits, PROCESS "ART-01-120-A-CD-5001_1.docx Distribution Code: A002 REPRODUCED, ANDIOR USED FOR A DIFFERENT PURPOSE FOR WHIGH IT WAS PREPARED WITHOUT PRIOR WRITTEN AUTHORIZATION FROM PEMEX REFNACION ORICA FLUOR™ 02-4014 RO-2401 Page 232 of 282No. ART-01-120-A-CD-5001 CONFIDENTIAL Date: 23-JUN-15 DESIGN CRITERIA Shoot 49de 71 + Asa general rule, when cooling process streams to 50°C or greater, an air cooler should be used + When the final process temperature required is below 50°C and a water cooling exchanger is required downstream of the air cooler, the air cooler process stream. outlet temperature should be limited to 55°C. + The width of the bundles should be limited to a maximum of 4.3 m. + Maximum tube length should be 12 m, without approval from PEMEX. + The air coolers should be forced draft fan type. minimum bare tube OD should be used. * The process fouling factor should be selected based on standard industry guidelines. No fouling factor for air should be used. + Inthe case of units that handle products with pour points higher than the minimum ambient temperature the need of louvers and steam coils or air recirculation should be considered. W)When the difference in the temperature of the fluid between the inlet of one tube pass and the outlet the next pass is greater than 110°C split headers should be considered, * Finned tube type shall be extruded. ‘©The fans should be driven by electric motors. * Unless greater tube thickness is required by design conditions or specified in the datasheets, the following typical industry standard values should be used as minimum tube gauges: Table 3.2.5: Minimum Recommended Air-Cooler Tube Wall Thickness Tube Material BWG Ferrtic Steel up to and including 9% Cr 12 Ferrtic Alloy Steel 12% Cr. 14 Stainless Steel (austenitic and duplex) 16 Copper Alloys: 14 ‘Aluminum 12 Monel 16 Incolloy 16 Titanium 18 B. Control Types Air cooler control is categorized as A, B, or C based on the following criteria. Air cooler control categories are to be identified on the first page of the air cooler datasheet along with the control temperature range. PROCESS "ART-01-120-A-CD-5001_1.docx Distribution Code: A002 REPRODUCED, ANDIOR USED FOR A DIFFERENT PURPOSE FOR WHIGH IT WAS PREPARED WITHOUT PRIOR WRITTEN AUTHORIZATION FROM PEMEX REFNACION ORICA FLUOR™ 02-4014 RO-2401 Page 233 of 282No. ART-01-120-A-CD-5001 Date: 23-JUN-15 DESIGN CRITERIA Shoot 44 de 71 CONFIDENTIAL Table 3.2.6: Air Cooler Control Categories Control Category Degrees of Control Design Requirement ‘A | Close control not required None. Fans will be on/off only B For + 5°C control of process outlet temperature | 50% of fans on VFD™ C |e For + 2°C control of process outlet | 100% of fans on temperature vr" + For recirculation systems with open floors + For where one fan on full speed results in unacceptable tube wall temperature. Notes: 1. Variable Frequency Drive. Other variable speed drive systems and/or fan pitch control are not recommended. C. Allowable Pressure Drop Allowable pressure drop for air coolers in pumped liquid services should be as follows: Table 3.2.7: Allowable Differential Pressure for Air Coolers Viscosity, (oP) Allowable AP, Tube Side, (kg/cm’) <1.0 0.35 -0.70 1.0 = 5.0 0.50 - 0.70 5.0-15 0.70-1.05 15-25 1.05— 1.40 25-50 175 > 50 Heat Transfer Engineer to Specify Allowable pressure drop for air cooled condensers should be as follows: Table 3.2.8: Allowable Differential Pressures for Air Cooled Condensers ‘System Pressure, (kg/cm’g) Allowable AP, (kg/cm?) 3.50 0.10- 0.15 3.50 — 14.00 0.15 - 0.35 > 14.00 0.35 PROCESS "ART-01-120-8-C0-500%_f.docx Distribution Code: A002 REPRODUCED, ANDIOR USED FOR A DIFFERENT PURPOSE FOR WHIGH IT WAS PREPARED WITHOUT PRIOR WRITTEN AUTHORIZATION FROM PEMEX REFNACION ORICA FLUOR™ 02-4014 RO-2401 Page 234 of 282No. ART-01-120-A-CD-5001 CONFIDENTIAL Date: 23-JUN-15 Sheet: 45 de 71 DESIGN CRITERIA Rot 3.3 Fired Heaters 3.3.1. General Requirements. Applicable Standards and Practices + NRF-089-PEMEX-2011, Direct Fire-type Heaters for Process Plants. This standard should be used for thermal and mechanical design. + NFPA 85, Boiler and Combustion Systems Hazards Code + NFPA 86, Standards for Ovens and Furnaces ‘+ API RP-535, Burners for Fired Heaters in General Refinery Services + API STD 560, Fired Heaters for General Refinery Services 3.3.2. Heater Process Specification Criteria Heater Process Design Considerations should be in full accordance with paragraph 8.2 of NRF-089-PEMEX-2011 Direct Fire-type Heaters for Process Plants, see selected excerpt below: ‘+The efficiencies calculated and actual guaranteed should be based on the design heat load, the lower heating value of fuel supplied and must include a minimum of 1.5%. loss by radiation of heat release design. Heaters using air pre-heating systems must include a minimum of 2.5% loss by radiation of heat release design. ‘+ Unless specified otherwise, calculated efficiencies for natural draft should be based on 20% excess air for gaseous fuels. Under forced draft operation on gaseous fuels the caloulated efficiency should be based on 15% excess air. ‘+ The flow velocity in the vapor or liquid-vapor should be limited to a maximum of 80% of the critical velocity. An exception may be made ona c ase by case basis with prior PEMEX approval. ‘+The minimum temperature of the combustion gases leaving the stack should be 190°C when burning fuel gas, ane xception may be made for low sulfur fuels with prior PEMEX approval. In addition to NRF-089-PEMEX-2011, the following general practices are to be considered: ‘+ The heater efficiency should be calculated using the specified fouling resistances. + Allfurnaces should be designed to fire 100% fuel gas for startup and normal operation, ‘+ Start of Run (SOR) and End of Run (EOR) conditions should be specified on the datasheet if applicable. The definitions of SOR and EOR pertaining to fired heaters is as follows subject to fluid-specific Licensor/Contractor specifications: SOR - Start of Run, with clean tube surfaces. EOR — End of Run, with fouled or coked tube surfaces, * Fired reboilers should be designed for a maximum of 50% by weight vaporization. PROCESS "ART-01-120-A-CD-5001_1.docx Distribution Code: A002 REPRODUCED, ANDIOR USED FOR A DIFFERENT PURPOSE FOR WHIGH IT WAS PREPARED WITHOUT PRIOR WRITTEN AUTHORIZATION FROM PEMEX REFNACION ORICA FLUOR™ 02-4014 RO-2401 Page 235 of 282No. ART-01-120-A-CD-5001 Date: 23-JUN-15, DESIGN CRITERIA Shoot 48 de 71 CONFIDENTIAL ‘+ Minimum stack temperature should be 28°C above water or sulfuric acid dew point, whichever is greater to prevent condensation per typical industry standards. Sulfuric acid dew point should be estimated using the Okkes correlation (1987). * A fail-safe shutdown system will be provided to shutoff all fuel sources on loss of flow in any process coil 3.3.3 General Heater Design Cri Design of the fired heater and as sociated feed distribution should be consistent with the following For multi-pass heaters the following will be specified: ‘* Vapor phase or mixed phase: inlet and outlet symmetrical arrangement of the passes and board temperature indicator on each pass outlet. ‘+ Liquid phase: for high temperature or critical services, flow control valve with a minimum flow stop on each pass inlet control valve and a board temperature indicator on each pass outlet. Licensor/Contractor should specify the maximum allowable fluid film temperature. 3.3.4 Coil Design ‘+ Design pressure should be based on the guidelines provided in Section 2.1 ‘+ Furnace tubes should be designed for a maximum tube metal temperature plus 10°C (Ref: NRF-089-PEMEX-2011 Section 8.2.2r) ‘+ For services susceptible to coking, decoking should be performed by pigging of the heater tubes. Drop out spools should be provided in inlet and outlet piping, 3.3.5 Burner Design Burner Design should be in full accordance with paragraph 8.2.10 of NRF-089-PEMEX-2011 Direct Fire-type Heaters for Process Plants, see selected excerpt below: ‘+ All bumers should be high efficiency, low NOx and noise attenuator. ‘+The builtin burners to the heaters must comply with NOM-085-SEMARNAT-2012, and must include, if necessary, the systems required to comply with the emissions of this standard. ‘+ The heaters should be designed with multiple burners and must have a pilot for each burner. ‘+ The burner must be de signed for operation limits of 50% to 125% of design heat release based on the characteristics of the fuel and excess air design, shown in data sheets. In addition to NRF-089-PEMEX-2011, the following general practices are to be considered: ‘+ Bumer tips should be removable for cleaning while the heater remains in operation, ‘+ Bumers should have natural gas pilot burners. Pilot burners should be designed for removal/cleaning while in operation. PROCESS "ART-01-120-A-CD-5001_1.docx Distribution Code: A002 REPRODUCED, ANDIOR USED FOR A DIFFERENT PURPOSE FOR WHIGH IT WAS PREPARED WITHOUT PRIOR WRITTEN AUTHORIZATION FROM PEMEX REFNACION ORICA FLUOR™ 02-4014 RO-2401 Page 236 of 282No. ART-01-120-A-CD-5001 CONFIDENTIAL Date: 23-JUN-15, DESIGN CRITERIA Shoot 47 de 71 ‘+ Combustion equipment and fired heaters should include a flame failure protection system for burners and pilots. All actions of flame failure protection system should be monitored locally and from the DCS. + Each pilot should have an independent electronic ignition. 3.3.6 Fuel Supply System For fuel gas system, provisions should be made so that no condensation occurs in fuel lines to the burners. 3.3.7 Snuffing Steam ‘+ Shuffing steam lines to the firebox and header boxes should be sized for 32 kg/h per im? of firebox. ‘+ Shuffing steam supply pressure should be at least 3.5 kglcm* g. Use of higher pressure steam will result in smaller lateral sizes. ‘+ Snuffing steam valves to be located at a safe distance from and within view of the furnace 3.3.8 Stack and Dampers Stack and Damper Design should be in full accordance with paragraphs 8.2.9 and 8.2.12 of NRF-089-PEMEX-2011 Direct Fire-type Heaters for Process Plants, see selected excerpt below: ‘+ The speed of the combustion gases from the chimney should be in the range of 7.62 mis to 9.14 mis up to 125% of design heat load. ‘+ Damper should remain at the last position to actuator force failure. Dampers should be actuated with regulating pneumatic actuators with electropositioner with a signal of 4- 20 mA, 20.68 — 103.42 kPa (3-15 psi) with a maximum torque required to 274.6 kPa (40 psi) minimum air pressure that should open if air fails. It should have a manual hydraulic actuator as an option in case of pneumatic failure, including a hydraulic drive system from the ground level In addition to NRF-089-PEMEX-2011, the following general practices are to be considered: ‘+ Damper position indicators should be visible from grade. ‘+ Height of stacks should not be less of that required for the process or the minimum necessary to achieve an adequate dispersion of air pollutants, according what is established in Mexican environmental legislation (NOM-085-SEMARNAT-2011)._ If ground level for the stack is less than the ground level for administrative buildings, the difference in height should be added to the calculated height. ‘+ Height in relation to operating platforms (any platform that may be visited at least daily by operating personnel) should be as follows: PROCESS "ART-01-120-A-CD-5001_1.docx Distribution Code: A002 REPRODUCED, ANDIOR USED FOR A DIFFERENT PURPOSE FOR WHIGH IT WAS PREPARED WITHOUT PRIOR WRITTEN AUTHORIZATION FROM PEMEX REFNACION ORICA FLUOR™ 02-4014 RO-2401 Page 237 of 282No. ART-01-120-A-CD-5001 CONFIDENTIAL Date: 23-JUN-15 DESIGN CRITERIA Shoot 48de 71 Table 3.3.1: Required Stack Elevation Above Platform Radial Distance from Edge of | Height of Stack Above Stack to Edge of Platform, m Platform, m 0-475 45 47.550 35, 50-525 25 525-55 2 55-575 1 3.3.9 Air Preheaters, Waste Heat Boilers, and Air Ducts ‘+ Ingeneral, air preheat is preferred over steam generation for heat recovery. ‘+ Temperature of flue gas leaving air preheater or WHB should retain a minimum 28°C margin above the water or acid dew point for fired heaters operating at normal rate with fuel gas. ‘+ Combustion air ductwork for each heater should have a flow-measuring device, ‘+ Mechanical draft systems should include: © Individual air control to each burner. © ID fan failure detection by fan speed. © Ai preheater system should be balanced-draft type. © Operating flexibility of air preheater system: change to natural draft when forced draft fails. Vendor to determine operating capacity when heater is operating under natural draft > High temperature alarm on flue gas out of air preheater/WHB. © Bypass around air preheater on air. Variable inlet vanes on forced draft fan Overpressure protection for furnace boxes. o Temperature probes upstream and downstream of combustion air bypass, ‘© Temperature probes to measure temperature upstream and downstream of where flue gas bypass duct connects to hot ducting and stack. 3.3.10 Instrumentation Minimum heater instrument connections should be in full accordance with paragraph 8.2.16 of NRF-089-PEMEX-2011 Direct Fire-type Heaters for Process Plants, see selected excerpt below: + For the process fluid temperature. In the interconnecting piping of each pass. + For combustion air temperature for forced draft heaters or air preheating system. * For flue gas temperature around including the air preheating system. + For combustion air pressure for forced draft heaters or air preheating system. * For flue gas pressure around the heater including the air preheating system, PROCESS "ART-01-120-A-CD-5001_1.docx Distribution Code: A002 REPRODUCED, ANDIOR USED FOR A DIFFERENT PURPOSE FOR WHIGH IT WAS PREPARED WITHOUT PRIOR WRITTEN AUTHORIZATION FROM PEMEX REFNACION ORICA FLUOR™ 02-4014 RO-2401 Page 238 of 282No. ART-01-120-A-CD-5001 CONFIDENTIAL Date: 23-JUN-15, DESIGN CRITERIA Sheet! 49 de 71 Rev. 1 + For sampling of emissions to the atmosphere in the stack according to the standard NMX-AA-09-1993-SCFI, Determination of Gas Flows, Continuous Atmospheric, Fixed Sources. ‘+ For flue gas sampling, in addition to those required for the sampling of contaminating emissions to the atmosphere located in the chimney. At the outlet of the radiation and the convection sections. ‘* For purge vapor in the radiation section. «For drain and vent. ‘+ For metal temperature of the tubes. A skin thermocouple at the output of each pass. ‘+ For continuous analysis of oxygen and carbon monoxide at the outlet of the radiant section. ‘+ In addition to NRF-089-PEMEX-2011, the following instruments are to be considered: ‘+ Thermocouples for measuring the process fluid temperature should be located at the fired heater inlet and at the outlet of the convection coils in each pass. + Flue gas temperature measurements at radiant floor and roof, convection section exit, inlet and outlet of air preheater and outlet air from air preheater (if any). Draft indicator should be provided for floor, bridge, before and after the damper. PROCESS "ART-01-120-A-CD-5001_1.docx Distribution Code: A002 REPRODUCED, ANDIOR USED FOR A DIFFERENT PURPOSE FOR WHIGH IT WAS PREPARED WITHOUT PRIOR WRITTEN AUTHORIZATION FROM PEMEX REFNACION ORICA FLUOR™ 02-4014 RO-2401 Page 238 of 282No. ART-01-120-A-CD-5001 CONFIDENTIAL Date: 23-JUN-15 DESIGN CRITERIA Sheet! ode 71 3.4 Pumps 3.4.1 General Requirements. Applicable Standards and Practices ‘+ Centrifugal pumps (excluding sealless pumps). Pumps handling flammable or hazardous liquids should be in accordance with NRF-050-PEMEX-2012 Centrifugal Pumps and API685 2nd edition Seabless Centrifugal Pumps for Petroleum, Petrochemical, and Gas Industry Process Service, unless otherwise approved by PEMEX. ‘+ Centrifugal and Rotary Pumps should be in accordance with ISO 21049:2004 Pumps Shaft Sealing Systems for Centrifugal and Rotary Pumps. + Dosing pumps should bein accordance with NRF-182-PEMEX-2013 Positive Displacement Dosing Pumps. ‘+ Reciprocating pumps should bei n accordance with NRF-190-PEMEX-2008 Reciprocating Pumps. ‘+ Rotary pumps should be in accordance with NRF-209-PEMEX-2008 Rotary Pumps. ‘+ If the specified driver for an installed spare pump in a noneritical service is a steam turbine, it should comply with NRF-213-PEMEX-2011 Steam Turbine Drivers, provided the steam conditions are below 48 barg and 400°C. ‘+ Steam turbine drivers for non-spared, critical or high power pump services should comply with NRF-170-PEMEX-2008 Steam Turbines for Special Service. In addition to the Applicable Standards and Practices listed above the following general practices are to be considered ‘+ DCS should consider the signal status from in operation and spare pumps, as well as the option to turn off them. Turing on should be carried out only at field. ‘+ Include bypass andthe blocks required to isolate the operating equipment for maintenance, without shutting down the plant, where applicable. ‘+ The block valves at suction and discharge pipes should be located as close to the pump as possible to minimize the liquid trapped volume which will be purged for maintenance, ‘+The suction and discharge pump pipes should use permanent spectacle blinds with its proper hang spacer flanges, in order to avoid the installation of provisional blind fianges or inserted temporary steel plates, which can produce pump misalignments, flanges misalignment (being not parallel), etc. Same criteria are for all the mechanical rotary equipment like compressors, etc. 3.4.2 Pump Rated Capacity Criteria + Asa general rule, the rated pump capacity should be per Table 3.4.1 PROCESS "ART-01-120-A-CD-5001_1.docx Distribution Code: A002 REPRODUCED, ANDIOR USED FOR A DIFFERENT PURPOSE FOR WHIGH IT WAS PREPARED WITHOUT PRIOR WRITTEN AUTHORIZATION FROM PEMEX REFNACION ORICA FLUOR™ 02-4014 RO-2401 Page 240 of 282No. ART-01-120-A-CD-5001 CONFIDENTIAL Date: 23-JUN-15, Sheet. 51 de 71 DESIGN CRITERIA pret Table 3.4.1: Pump Rated Capacity Criteria Rated Capacity Over Normal, % Service Gena eee Unit Feed Pump 5% 10% Feed Booster Pump 10% 15% Product Pump 10% 15% Reflux Pump 15% 20% Pumparound Reflux Pump. 20% 20% Intermittent Service 0 0 Reboiler Feed 15% 20% Boiler Feed = 10% ‘Surface Condenser Condensate = 10% ‘Chemical injection 20% = ‘+ For pumps in services where there are several process cases, for which the normal flow rate varies more than 30%, the overdesign factor should be jointly agreed with PEMEX. 3.4.3 Rated Head + Total developed head should be bas ed on! owest suction pressure and highest discharge pressure based on fully fouled equipment. ‘+ Line friction losses should be set at 20% over the calculated value for single phase fluids and 30% for two-phase fluids with the exception of steam systems, for which no margin is added. ‘+ Equipment pressure losses (exchangers, etc.) should be set at the values specified on the equipment data sheets. ‘+ For control vaives at the discharge of reflux, charge and recycle pumps, use whichever of the following four pressure drops is greater: i, Atnormal flow rate, 33% of the total variable system pressure drop including control valve (50% of the variable system pressure drop excluding control valve). ‘At normal flow rate, 1 kg/cm? ‘At pump rated capacity, 20% of the total variable system pressure drop including control valve iv. At pump rated capacity, 0.7 kg/em?, ‘+ Limitations (ji) and (iv) above are required to make sure there is enough pressure drop built into the pump head for the control valve to operate at the pump rated capacity. ‘+ For high head pumps, such as hydrotreater charge pumps, consideration should be given to specifying the contral valve at 20% (instead of 33%) of the total variable system drop at normal flow. PROCESS "ART-01-120-A-CD-5001_1.docx Distribution Code: A002 REPRODUCED, ANDIOR USED FOR A DIFFERENT PURPOSE FOR WHIGH IT WAS PREPARED WITHOUT PRIOR WRITTEN AUTHORIZATION FROM PEMEX REFNACION ORICA FLUOR™ 02-4014 RO-2401 Page 241 of 282No. ART-01-120-A-CD-5001 CONFIDENTIAL Date: 23-JUN-15 DESIGN CRITERIA Sheet! 52de 71 Rev. 1 ‘+ In systems for which the net differential pressure is very high (>35 kg/cm’), review head contingency with the Lead Process Engineer. + For applications with two control valves in series, the primary control valve should have aminimum pressure drop based on the criteria given above. The secondary control valve (temperature control valve at inlet to exchanger) should have a minimum pressure drop that is the greater of: ‘© Atnormal flow rate, 20% of exchanger pressure drop in fouled condition. © Atnormal flow rate, 0.35 kg/cm’. + Head capacity curves that rise continuously to shutoff are preferred for all centrifugal pumps, and are required for pumps operating in parallel. ‘+ The minimum required capacity should be specified where it is known that the pump will operate, even for short periods of time, at capacities well below its normal capacity. ‘+ Where parallel operation is specified, the characteristic curves should be such that the capacity of each pump should be approximately a constant portion of the total capacity at all heads from shutoff to 120% of rated capacity ‘+ All pumps should be suitable for operating at the specified operating conditions and at off-design conditions occurring at plant startup, shutdown, process upset, power outage, etc. as applicable, ‘+ Pumps charging fractionation systems should be checked for adequate differential head to maintain a substantial flow rate to the column during upsets when maximum pressure may approach relief valve setting. The system control valve should be able to “give up” enough pressure drop to maintain a substantial flow rate to the column ‘+ For boilers, ASME code requires pumping at the relief valve set pressure plus 3% accumulation. 3.4.4 Suction Pressure + Rated suction pressure is the pressure existing at the pump suction with the pump operating at rated capacity with the liquid level at bottom tangent line. ‘+The maximum pump suction pressure is determined by: © Relief valve setting plus maximum static head from the suction to the pump centerline and any additive pressure drop (including trays). Do not take into account the suction piping line loss. o For a system unprotected by a relief valve, the shutoff pressure of the upstream booster pump © Fora gravity flow system, the maximum static head 3.4.5 Available NPSH + NPSH is the minimum net positive suction head available at the pump. The figure is obtained by subtracting the liquid vapor pressure from the suction pressure (absolute) at the pump. The result (in kg/om’) is converted to meters of fluid, * Vapor pressure (kg/cm’a) is determined at normal pumping temperature. PROCESS "ART-01-120-A-CD-5001_1.docx Distribution Code: A002 REPRODUCED, ANDIOR USED FOR A DIFFERENT PURPOSE FOR WHIGH IT WAS PREPARED WITHOUT PRIOR WRITTEN AUTHORIZATION FROM PEMEX REFNACION ORICA FLUOR™ 02-4014 RO-2401 Page 242 of 282No. ART-01-120-A-CD-5001 CONFIDENTIAL Date: 23-JUN-15 DESIGN CRITERIA Sheet! 8671 ‘+ Pump selection can be affected considerably by NPSH values, therefore, they should be determined initially as accurately as possible. + The NPSHA (NPSH available) to be shown on the pump data sheet must include adjustments to the actual calculated NPSH as follows: 10% or 1 m, whichever is greater. For vacuum service (vacuum at pump inlet) or low temperature (below 0°C) the margin should be at least 2 m. + NPSH margin used should be indicated onthe pump data sheet to avoid double accounting of NPSH margin when the Mechanical Engineer selects the pump. ‘+ Pump available NPSH should be calculated from the bottom tangent line of vertical suction vessels and the bottom of the vessel for horizontal vessels. ‘+The NPSH required for pumps should be based on water. No hydrocarbon correction factor should be used. ‘+The economics of increasing suction line size versus adjusting vessel elevation should be considered in providing sufficient NPSH ‘+ The suction line losses should be based on rated flow capacity of the pump. Pressure drop through any permanent strainer required should be based on 50% clogging. Use LID=250 for astrainer and assume the suction nozzle one size smaller than the suction line size. For this, include a reducer in line loss calculation ‘+ For subcooled liquids, the source pressure should be the minimum normal operating pressure and the vapor pressure should be at the maximum normal process temperature. Consideration shall be taken for blanket gas solubility in pumped liquids when determining the fluid vapor pressure. ‘+ Static head should be measured from the bottom of horizontal drums, from the bottom tangent line of vertical vessels and columns with bottom drawoffs, and from the bottom. elevation of the outlet nozzle for side drawotfs, to the centerline of a horizontal centrifugal or rotary pump, or to the suction nozzle of a vertical centrifugal pump or reciprocating pump, ‘+The design of storage tank suction lines should be based on the available NPSH from the lowest specified liquid level in the tank at which rated pump capacity is required. ‘+ Ifa vortex breaker is required, the pressure drop through it should be considered. + For horizontal centrifugal pumps, assume the elevation of the pump centerline to be 1 m above grade, unless the actual elevation is known. * For reciprocating pumps no ac celeration heads hould be included for NPSHA calculations. This fact should be stated in the datasheet. 3.4.6 Minimum Flow + Pumps are typically suitable for continuous operation at a flow of 30% of normal capacity. If flow conditions necessitate flow for less than 30%, minimum flow provisions may be required. Some high head pumps require a minimum flow as high as 45%. PROCESS "ART-01-120-A-CD-5001_1.docx Distribution Code: A002 REPRODUCED, ANDIOR USED FOR A DIFFERENT PURPOSE FOR WHIGH IT WAS PREPARED WITHOUT PRIOR WRITTEN AUTHORIZATION FROM PEMEX REFNACION ORICA FLUOR™ 02-4014 RO-2401 Page 243 of 282No. ART-01-120-A-CD-5001 Date: 23-JUN-15 DESIGN CRITERIA Sheet! $4 de 71 Rev. 1 CONFIDENTIAL + Minimum flow required should bebas ed ont he pump manufacturer's recommendations, but 30% of normal flow may be us ed for initial sizing of the minimum flow line. ‘+ Specify the minimum flow requirement, if it exists as a process requirement in normal operation, in an emergency, or during start-up and shutdown of the unit ‘+ Minimum flow provisions for centrifugal pumps should consist of a line from the pump discharge to the suction source (vessel), preferably through a cooler. ‘+ Even if there is no specific minimum process flow requirement, pumps in the following services may need a minimum flow bypass: © High differential pressure multistage pumps © Boiler feed water pumps. © Where there is a possibility of no-flow conditions occurring in a pump discharge system (such as a control valve failing to a closed position or controlled to be so by a logic). + Minimum flow bypass provision for centrifugal pumps is to be made with a modulating control valve unless prior approval from PEMEX is received. + No additional capacity should be added t o pump flow rate for minimum flow bypass rate when modulating controlling of minimum flow bypass is provided. * Minimum flow bypass control valve sizing should be based on 110% of the flow requirement. Control valve should be designed to prevent erosion/cavitation damage due to flashing across the bypass valve caused by high differential pressure. 3.4.7 Maximum Differential Head for Centrifugal Pumps + For preliminary estimation of the maximum differential head at shut-off conditions use: © 1.25 times the differential head s pecified for the normal capacity, for pumps driven by an electric motor (fixed speed driver). © 1.35 times the differential head s pecified for the normal capacity, for pumps driven by a variable speed driver. + The maximum differential head at shutoff conditions should be determined based on the maximum anticipated liquid density, Consideration must be given to operation with cold start-up fluids. 3.4.8 Maximum Discharge Pressure for Centrifugal Pumps + The maximum discharge pressure should be calculated as the greater of the following caloulations: © The normal suction pressure (normal pressure at the suction vessel plus the static head corresponding to NLL to the anticipated shaft centre line of the pump) plus the maximum differential head at shut-off. ‘© The maximum suction pressure (Suction vessel at PRV set pressure plus the static head corresponding to HLL to the anticipated shaft centre line of the pump) plus the differential head at the normal capacity. PROCESS "ART-01-120-A-CD-5001_1.docx Distribution Code: A002 REPRODUCED, ANDIOR USED FOR A DIFFERENT PURPOSE FOR WHIGH IT WAS PREPARED WITHOUT PRIOR WRITTEN AUTHORIZATION FROM PEMEX REFNACION ORICA FLUOR™ 02-4014 RO-2401 Page 244 of 282No. ART-01-120-A-CD-5001 CONFIDENTIAL Date: 23-JUN-15, DESIGN CRITERIA Sheet! 55 de 71 Rev. 1 ‘+ When it is foreseen that it is possible to have the pump at shut-off conditions coincident with arr elief condition in the suction vessel, the maximum discharge pressure should be calculated at the sum of: © The maximum differential head as stated above and maximum liquid density at any specified operating condition. © The set pressure of the PRV in the suction vessel © Static head from the HLL to the anticipated shaft centre line of the pump. ‘+ For booster pumps (two pumps in series), the maximum discharge pressure should be calculated as the maximum suction pressure (shutoff head of the first pump plus the static head corresponding to NLL to the anticipated shaft centre line of the pump) plus the maximum differential head at shut-off of the booster pump. 3.4.9 Maximum Discharge Pressure for Reciprocating Pumps ‘+ The maximum discharge pressure should correspond to the pump PRY setting. 3.4.10 Drivers, ‘+ Allelectric motor drivers should be high efficiency. ‘+ Asa general rule electric motor drivers should be specified, unless the use of steam turbine drivers is required due to process reasons, safety (equipment, personnel or catalyst protection), or pump availability for certain critical services (pump-out, etc) to improve the unit reliability ‘+ The use of seal-less centrifugal pumps is permitted in those services where it is recommended for safety reasons. The datasheet should state whether magnetic drive pumps or canned motor pumps are preferred. 3.4.11 Mechanical Seals The seal selection should be in strict accordance with NRF-050-PEMEX-2012 Centrifugal Pumps and API-682 (ISO 21049:2012) Pumps Shaft Sealing Systems for Centrifugal and Rotary Pumps. Unpressurized dual mechanical seals should be specified in the following cases’ ‘+ When the seal chamber pressure is more than 30% above the maximum fluid vapor pressure, or 220°C temperature margin based onthe maximum process fluid temperature (API-682 Section 6,1.2,14). * When the normal pumping temperature is less than 176°C (AP/-682 Section A.2.4.4). + When the maximum pumping temperature is less than the self-ignition temperature of the pumped liquid * The pumped liquid has an HS content higher than 50 ppm wt. Pressurized dual mechanical seals will be specified by PEMEX. The following preliminary assumptions will be used ‘+ The pumped liquid has a solid content above 0.5 wt% (the use of gas seals - 3NC configuration per API 682 — is not allowed for these services). PROCESS "ART-01-120-A-CD-5001_1.docx Distribution Code: A002 REPRODUCED, ANDIOR USED FOR A DIFFERENT PURPOSE FOR WHIGH IT WAS PREPARED WITHOUT PRIOR WRITTEN AUTHORIZATION FROM PEMEX REFNACION ORICA FLUOR™ 02-4014 RO-2401 Page 248 of 282No. ART-01-120-A-CD-5001 CONFIDENTIAL Date: 23-JUN-15, DESIGN CRITERIA Sheet! sede71 ‘+ When the seal chamber pressure is less than or equal to 30% above the maximum fluid vapor pressure, or a 20°C temperature margin based on the maximum process fluid temperature (API-682 Section 6.1.2.14). ‘+The pumped liquid can polymerize (the use of gas seals - 3NC configuration per API 682 - is not allowed for these services) ‘+The pumped liquid contains Benzene (regardless of its content). However, for services containing lethal or carcinogenic fluids the first option would be as eal-less pump. Arrangement 3 seals should only be considered if the seal-less pump is not suitable for the service. ‘+ The pumped liquid has an H2S content higher than 1000 ppm wt. As an alternative, seal-less pumps might be specified. 3.4.12 Pump Start-up and/or Re-Acceleration Unless otherwise specified, pumps should be started up by an operator from the local panel. Should automatic start-up or re-acceleration be required due to process reasons, this requirement should be clearly stated on the data sheet and reviewed with PEMEX before implementation. 3.4.13 Sparing Philosophy ‘+ All pump services shall be provided with an installed spare pump. + Non-critical services, a spare pump may be shared between two or more services, provided no interferences exist between the different services, duet o auxiliary systems (e.g. seal systems), isolating valves shutoff pressures, etc. PROCESS "ART-01-120-A-CD-5001_1.docx Distribution Code: A002 REPRODUCED, ANDIOR USED FOR A DIFFERENT PURPOSE FOR WHIGH IT WAS PREPARED WITHOUT PRIOR WRITTEN AUTHORIZATION FROM PEMEX REFNACION ORICA FLUOR™ 02-4014 RO-2401 Page 246 of 282No. ART-01-120-A-CD-5001 Date: 23-JUN-15, 57 de 71 CONFIDENTIAL DESIGN CRITERIA Sheet Rev. 1 3.5 Compressors 3.5.1 General Requirements. Applicable Standards and Practices ‘* Centrifugal process compressors should bein accordance with NRF-131-PEMEX- 2013 Centrifugal Compressors. ‘+ Reciprocating process compressors should be in accordance with NRF=132-PEMEX- 2013 Reciprocating Compressors. ‘+ Rolary compressors should bein accordance with ISO 10440-1:2007 Rotary Type Positive Displacement Compressors. ‘* If the specified driver for a non-spared Compressor service is as team turbine, it should comply with NRF-170-PEMEX-2008 Steam Turbine for Special Service. In addition to the Applicable Standards and P ractices listed above the following general practices are to be considered ‘+ Reciprocating compressors, unless otherwise specified, should be opposed-balanced horizontal cylinder design A. Pressure Variation + Pulsation dampeners should be provided for both the suction and discharge of reciprocating compressors. The pulsation dampers must eliminate harmful and excessive vibration caused in pipes that connect to compressors. + Damping equipment must be pulsation dampers or bottles and made with ASME stamped * Contractor or supplier must carry out an interactive acoustic simulation study, of the entire system, when two or more units are going to operate in parallel. + Relief valves should be provided on reciprocating compressors to prevent over pressuring in the event that the compressor is blocked in while operating. For reciprocating compressors, the maximum operating pressure is equal to the rated discharge pressure. A margin should be included for pressure pulsations for design pressure considerations. B. Discharge Temperature Li For reciprocating compressors, the maximum theoretical (predicted) or actual discharge temperatures should not exceed 150°C. The maximum discharge temperature should not exceed 135°C for hydrogen rich services (those with a molecular weight of 12 or less). €. Flow Variation + The surge point of a compressor should be less than 60% of the rated capacity of all operating speeds regardless of type of driver, unless advance surge control is, provided. PROCESS "ART-01-120-A-CD-5001_1.docx Distribution Code: A002 REPRODUCED, ANDIOR USED FOR A DIFFERENT PURPOSE FOR WHIGH IT WAS PREPARED WITHOUT PRIOR WRITTEN AUTHORIZATION FROM PEMEX REFNACION ORICA FLUOR™ 02-4014 RO-2401 Page 247 of 282No. ART-01-120-A-CD-5001 CONFIDENTIAL Date: 23-JUN-15 Sheet: 58 de 71 DESIGN CRITERIA Rot * Unloaders for reciprocating compressors should be electronically operated and provide for startup and step capacity control. The unloader should have continuous control (stepless control) to guarantee a smooth operation from the 20% to 100% of the normal flow rate, + Capacity control with bypass or step-less capacity control with a hydraulic power unit should be considered based on economics. D. Design Pressure for Centrifugal Compressors For centrifugal compressors, the design pressure of the compressor discharge should be at least equal to the specified relief valve setting. If a relief valve setting is not specified, the design pressure should beat least 1.25 times the maximum specified discharge pressure (Ref. API RP 617). This is an approximation of the maximum head at low or no flow to avoid the need for a relief valve. The maximum head of the compressor should be based on the maximum molecular weight gas anticipated. Maximum driver speed should also be considered in calculating the maximum head. E. Process Case Definition Process compressor specifications should include definitions of all relevant cases, such as the following conditions (when applicable): + Start of run + Middle of run = End of run + Regeneration + High octane yield + Low octane yield © Purging out © Start-up * Shutdown © Tumdown F. Miscellaneous Compressors should be specified to be constructed and tested under the code ASME Section VIII and should be stamped of the test under ASME code. As far as possible, all parts should be made and assembled in the factory. All welding should be consistent with the standards of the American Welding Society. Centrifugal compressors should be designed with automatic anti surge control system with signal to DCS. The vendor should provide the antisurge control valves, the antisurge dynamic software, a dedicated PLC or Board for monitoring and control, required process transmitters if special requirements to be met, and intercommunication with the plant DCS. PROCESS "ART-01-120-A-CD-5001_1.docx Distribution Code: A002 REPRODUCED, ANDIOR USED FOR A DIFFERENT PURPOSE FOR WHIGH IT WAS PREPARED WITHOUT PRIOR WRITTEN AUTHORIZATION FROM PEMEX REFNACION ORICA FLUOR™ 02-4014 RO-2401 Page 248 of 282No. ART-01-120-A-CD-5001 CONFIDENTIAL Date: 23-JUN-15, DESIGN CRITERIA Sheet! 59 de 71 Rev. 1 3.5.2 Sparing Philosophy ‘+ Centrifugal compressors: Due to their high availability, centrifugal compressors should not be spared, but fully tested spare rotors should be specified (including the steam turbine, if this type of driver is specified). ‘+ Reciprocating Compressors: Two (2) compressors rated at 100% should be supplied. Dead volume capacity increase is not allowed. ‘+ Centrifugal fans: Two (2) fans rated at 100% should be supplied ‘+ Rotary compressors: One (1) compressor rated at 100% should be supplied (where a large enough machine is available; otherwise, multiples to give 100% total). ‘+ Liquid ring compressors: Justification of the sparing philosophy for liquid ring compressors will be made to PEMEX on a case-by-case basis. 3.53. Drivers + Allelectric motor drivers should be high efficiency. ‘+ Asa general rule electric motor drivers should be specified, unless the use of steam turbine drivers is required due to process reasons, safety (equipment, personnel or catalyst protection), or pump availability for certain critical services (pump-out, etc) to improve the unit reliability + Reciprocating Compressors: The driver should generally be an electric motor directly coupled to the compressor. The driver nameplate rating should be 110% of the greatest power absorbed for any of the specified operating condition, or the power absorbed at the set point pressure of the discharge relief valves (whichever is greater) * Centrifugal Fans: For fans in critical services, one machine should be driven by an electric motor and the spare machine should be driven by a steam turbine in order to ensure fan operation in the event of a power failure. + If centrifugal compressor drivers are specified as steam driven, they should be designed as special purpose application. 3.5.4 Installation The installation of reciprocating compressors should include the following elements upstream of the compressors; if a compressor combines several services, it is understood that the following applies for each service. The elements are indicated in order of installation, beginning with the most distant from the compressor. If there is a main compressor and a standby unit (or two compressors in parallel operation, and one in standby), unless otherwise specified, a single element of each type should be installed. * One (1) vertical knockout drum at the suction of the compressor. The KO drum should be supplied with a sight level indicator, high and low level switches and a high high. level compressor shutdown. The KO drum should be located as near as possible to the compressor(s). * The lines from the knockout drum to the compressor should be sloped towards the drum, If several compressors are in service, the lines should be as similar as possible PROCESS "ART-01-120-A-CD-5001_1.docx Distribution Code: A002 REPRODUCED, ANDIOR USED FOR A DIFFERENT PURPOSE FOR WHIGH IT WAS PREPARED WITHOUT PRIOR WRITTEN AUTHORIZATION FROM PEMEX REFNACION ORICA FLUOR™ 02-4014 RO-2401 Page 248 of 282No. ART-01-120-A-CD-5001 CONFIDENTIAL Date: 23-JUN-15 DESIGN CRITERIA Sheet! ode 71 in order to avoid potential vibration problems. if there is any risk of condensation, these lines must be traced ‘+ In the case of multistage compressors the same components should be i nstalled downstream of the process gas intercooler. + Anon-slam check valve should be installed at each compressor discharge line (if two or more services are combined in the same machine, one check valve is required for each discharge line). 3.5.5 Reciprocating Compressor Cylinder and Packing Lubrication Unless an oil free gas is mandatory due to process reasons, the reciprocating compressors should be of the lubricated type. 3.5.6 Reciprocating Compressor Capacity Regulation System ‘+ Reciprocating compressors should have valve unloaders for step capacity regulation. These unloaders for reciprocating compressors should be electronically operated and provide for startup and step capacity control. + For constant-speed units compressing corrosive gases or gases that may polymerize clearance pockets are not allowed. 3.5.7 Compressor Start-up and/or Re-Acceleration ‘+ Unless otherwise specified, compressors should be started up by an operator from the local panel. Should automatic start-up or re-acceleration be required due to process. reasons, this requirement should be clearly stated on the data sheet, PROCESS "ART-01-120-A-CD-5001_1.docx Distribution Code: A002 REPRODUCED, ANDIOR USED FOR A DIFFERENT PURPOSE FOR WHIGH IT WAS PREPARED WITHOUT PRIOR WRITTEN AUTHORIZATION FROM PEMEX REFNACION ORICA FLUOR™ 02-4014 RO-2401 age 250 of 282No. ART-01-120-A-CD-5001 CONFIDENTIAL No: “ART Ovi DESIGN CRITERIA Shoot St de 71 4.0 PIPING 4.1. General ‘© Battery limit isolation should be provided for each line crossing the battery limits. Refer to NRF-032-PEMEX-2012 Piping Systems for Industrial Plants and Program Bulletin (Document Number TBD) for details. ‘* Closed sample systems are required to avoid atmosphere emissions or liquids spill to drain. 42 Pipe Sizes ‘+ Piping smaller than %" should not be used. ‘+ Nominal pipe size in sleeper ways and pipe racks should not be less than 2", ‘+ Nominal pipe sizes 1%", 2%", 314", 5" and 9" should not be used. 4.3 Line Sizing Criteria ‘+ A safety margin of 20% should be added to all friction loss caloulations for single phase fluids and 30% for two-phase fluids. Steam systems should have no margin added, A safety margin should only be added to frictional losses, and not to pressure losses due to elevation changes or acceleration. ‘* Pressure drop and velocity ranges should be based on the guidelines provided in Table 434 4.4 Sample Connections ‘+ Sample connections should have two block valves per connection. When the connection is not in use, both valves should be closed and the open end of the sample connection should be sealed or plugged. When sampling piping is not in use, it should be purged with unit flush or nitrogen and isolated 45 Design Temperature «Refer to Section 2.2 for guidelines on specifying design temperature for piping PROCESS "ART-01-120-A-CD-5001_1.docx Distribution Code: A002 REPRODUCED, ANDIOR USED FOR A DIFFERENT PURPOSE FOR WHIGH IT WAS PREPARED WITHOUT PRIOR WRITTEN AUTHORIZATION FROM PEMEX REFNACION ORICA FLUOR™ 02-4014 RO-2401 Page 25: of 282No. ART-01-120-A-CD-5001 CONFIDENTIAL Date: 23-JUN-15, DESIGN CRITERIA Sheet! 62der1 Table 4.3.1: Pressure Drop and Velocity Ranges Pressure Drop Velocity kglem?/ 100 m misec Liquids Boiling liquids at pump suction 0.01 - 0.06 03-12 Sub-cooled liquids at pump suction 0.05 - 0.28 03-24 Cooling water at pump suction 0.05 - 0.23 03-24 Liquids at pump discharge 0.23 - 0.90 15-45 Cooling water at pump discharge 0.11 - 0.45 15-45 Differential pressure liquids (static head) = 7.6 maximum Gases ‘Atmospheric or higher pressure gases 0.02- 0.45 : Vacuum gases 0.005 - 0.11 : Gas stream with excess pressure = 76 maximum Steam Steam over 3.5 kg/om’g (headers) 0.11 - 0.36 Note 1 Steam over 3.5 kg/cm’g (short leads to 0.35 -0.90 Note 4 equipment) Steam under 3.5 kglcm’g (headers) 0.05 - 0.44 Note 1 ‘Steam above atmospheric (short leads to 011-035 Note 4 equipment) Miscellaneous = Two Phase = Note 2 Sour Water = Note 3 Lean Amine (Carbon Steel Service) = 1.89 Rich Amine (Carbon Steel Service) = 1.89 Hydrofluoric Acid (Liquid) (Carbon Steel Service) 0.677 Liquid Sulfur (Carbon Steel Service) = 1.0) Sulfuric Acid (Carbon Stee! Service) = 12 Caustic (Carbon Steel Service) = 12 Notes: 1. Maximum of 9 mis per inch of pipe diameter between 3” to 6" diameter, 60 mis for saturated steam & 76 mis for superheated steam in sizes over 6". 2, Normally limited to erosional velocity of rho v’ < 14,882 kg/m s? (10,000 Ibift s*). 3. For maximum allowable velocities in sour water service, consult with metallurgist 4. Amine and HF Acid velocity are per NRF-028-PEMEX-2010 Annex 1 Section 2.4.6 and 2.6.4, respectively. PROCESS "ART-01-120-A-CD-5001_1.docx Distribution Code: A002 REPRODUCED, ANDIOR USED FOR A DIFFERENT PURPOSE FOR WHIGH IT WAS PREPARED WITHOUT PRIOR WRITTEN AUTHORIZATION FROM PEMEX REFNACION ORICA FLUOR™ 02-4014 RO-2401 Page 252 of 282No. ART-01-120-A-CD-5001 CONFIDENTIAL Date: 23-JUN-15, DESIGN CRITERIA Sheet! 68de71 5.0 INSTRUMENTATION 5.1. General ‘+ Flow meters should be specified for all the inlet and outlet process streams and selected utilities at the battery limits with signal to the Distributed Control System (DCS). The flow meters should totalize the daily and monthly consumption. ‘+ Pressure and temperature indication should be specified for all the inlet and outlet process streams and selected utilities at the battery limits with signal to the Distributed Control ‘System (DCS). ‘+ The required analyzers according Licensor technology for the optimum plant operation should be included and should have signal transmitting to DCS. ‘© Bypass and the blocks are required to isolate control valves in order to maintain them while the plant is operating, according to API-553 or API 551. The seal characteristics of valves for blocks should be the applicable ANSI standard, 5.2. Control Valves ‘+ For pressure drop allowance in pumped systems refer to Section 3.4.3. + On light hydrocarbon products to storage that are stored under product vapor pressure, use a valve pressure drop based on downstream vapor pressure at maximum ambient temperature * All control valves should be flanged. Flanges should be integral to the body and are not acceptable sliding type (slip on). The class of flanges and their rating should be in accordance with the respective counter flange pipe and the latest edition of ASME B16.5. ‘© For control valves, leaks classification in the seat should be according to ANSI / FCI 70-2 latest edition. ‘+ Noise levels for control vaives should not be greater than 85 db + / - 5 db, measured at a distance of 1.0 meter downstream of the valve and 1.0 meter from the surface of the pipe. ‘+ For sour fluid services, material selection of the control valve for resisting corrosion by hydrogen sulfide (H,S), should be done according to NACE MR-0103-2010 5.3. Control Valve Block and Bypass Valves ‘+ Block and bypass valves should be sized by Control Systems but checked by Process. ‘* For gas/vapor or flashing services with high pressure drop across the control valvelby- pass valve, check the need to swedge up the line downstream of the control and by-pass valves. This line segment may restrict flow at the lower downstream pressure. ‘+ For control valve block valves and bypass valve. After selection of control valve Cv the following general sizing criteria should be considered: © Bypass valve: Cv of bypass valve will be at least the calculated Cv of the control valve, but not more than twice the selected Cv of the control valve. © Typically globe valves will be used for bypass valves up to 4 inches (Cv = 200), and if the bypass valve Cv requirement is >200, use a gate valve with the required Cv. When gate valves are used as bypass valves, their minimum size will be 2 sizes Under line size, PROCESS "ART-01-120-A-CD-5001_1.docx Distribution Code: A002 REPRODUCED, ANDIOR USED FOR A DIFFERENT PURPOSE FOR WHIGH IT WAS PREPARED WITHOUT PRIOR WRITTEN AUTHORIZATION FROM PEMEX REFNACION ORICA FLUOR™ 02-4014 RO-2401 Page 253 of 282No. ART-01-120-A-CD-5001 CONFIDENTIAL Date: 23-JUN-15, Sheet: 64 de 71 DESIGN CRITERIA pret ‘© For bypass globe valves consider the use of guided disc, angle, y-pattern or specialty choke type globe valves to minimize possibility of bypass valve failure in high pressure drop or flashing services. For extreme cases consider supplying a bypass valve that is the same as the control vaive. ‘+ In applications where the pressure drop across the valve is high and flashing is possible, the sizes of block and bypass will be determined by process calculations. Bypass valves may need to be oversized for process reasons such as startup (faster filing or emptying a system) or gravity draining. The Process Engineer should coordinate this activity with the Control Systems Engineer. 5.4 Level Instruments © The level symbology used onthe P&ID's to establish control elevation in vessels and tanks may include any combination of the following: HHLL high high liquid level HLL high liquid level NLL normal liquid level LLL low liquid level LLLL low low liquid level HHIL high high interface level HIL high interface level NIL normal interface level LIL low interface level LLIL low low interface level © The high high and ow low liquid levels and interface levels establish the set points for level shutdown switches where applicable. ‘+The high and low liquid levels and interface levels establish the range for a continuous level measuring device (d/p, displacer, etc.) and for level alarm switches, ‘* The normal liquid level and interface level establishes the anticipated operating point. 5.5 Relief Valves Applicable Standards and Practices * Relief valves should be in accordance with NRF-031-PEMEX-2011 Flare and B umers ‘Systems and the project Flare System Design Philosophy document. 5.6 Emergency Isolation Valves Applicable Standards and Practices ‘+ Emergency isolation valves should bein accordance with NRF-204-PEMEX.2012 Emergency Block Valves. ‘+ The selection of services requiring emergency isolation valves should be in accordance with the Project Bolletin BP4-ART-050 “Guidelines for Emergency Isolation Valve". PROCESS "ART-01-120-A-CD-5001_1.docx Distribution Code: A002 REPRODUCED, ANDIOR USED FOR A DIFFERENT PURPOSE FOR WHIGH IT WAS PREPARED WITHOUT PRIOR WRITTEN AUTHORIZATION FROM PEMEX REFNACION ORICA FLUOR™ 02-4014 RO-2401 Page 254 of 282No. ART-01-120-A-CD-5001 CONFIDENTIAL Date: 23-JUN-15 DESIGN CRITERIA Sheet! 65de 71 Rev. 1 6.0 DRAWING FORMAT 6.1 Process Flow Diagrams (PFDs) Process Flow Diagrams should contain the following minimum information: + Name and plant tag + Plant location Equipment tag and name with main characteristics © Pumps: normal flow rate and differential pressure © Compressors: normal flow rate at suction conditions and hydraulic power © Reactors: diameter, T-T length, packing length and catalyst volume © Vessels and Columns: diameter and T-T length © Heat Exchangers: duty ©. Fired Heaters: absorbed duty + Equipment Symbols with the following data: © Reactors: temperature measurement instrument control © Vessels: representation of internals such as baffles and demisters. © Columns: representation of internals such as trays, packing, baffles and demisters, Number trays from top to bottom. © Heat exchangers: indicate which fluid goes on shell side and which on tube side. © The rest of the equipment represented by its conventional symbol ‘+ Streams identified by number. ‘+ Equipment tags near the symbol. ‘+ Banner for pressure and temperature indication on reactors, towers and vessels. ‘* Banner for pressure and temperature indication on entering and going out lines from the plan and in important points where there is a change in operating conditions. ‘* Identification of the entering and going out streams from the drawing, indicating stream description, arrows indicating which drawing they are coming from or going to. ‘* Basic process control for the streams going in or out from the process equipment. 6.2 Piping and Instrument Diagrams (P&IDs) Piping and Instrument Diagrams should contain the following minimum information + Name and plant tag + Plant location © Equipment tag and name with main characteristics: © Pumps: design flow rate, design differential pressure, material of construction, insulation, hydraulic horsepower and motor horsepower. © Compressors: design flow rate, hydraulic horsepower and motor horsepower. PROCESS "ART-01-120-A-CD-5001_1.docx Distribution Code: A002 REPRODUCED, ANDIOR USED FOR A DIFFERENT PURPOSE FOR WHIGH IT WAS PREPARED WITHOUT PRIOR WRITTEN AUTHORIZATION FROM PEMEX REFNACION ORICA FLUOR™ 02-4014 RO-2401 Page 255 of 282No. ART-01-120-A-CD-5001 CONFIDENTIAL Date: 23-JUN-15 Sheet: 66 de 71 DESIGN CRITERIA Rot © Vessels: diameter and T-T length, material of construction, insulation, height from interior tangent to grade level, design pressure and temperature, representation of the baffies and demisters, feed and product nozzles, normal (NLL), low (LLL) and high (HLL) liquid levels and shut down level for compressors in suction K.O drum, nozzles location for pressure, temperature and level measuring instruments. © Columns: diameter and T-T length, material of construction, insulation, height from interior tangent to grade level, design pressure and temperature, type and number of trays, number of liquid paths on the tray, type and material of the packing, feed and product nozzles, normal (NLL), low (LLL) and high (HLL) liquid levels, nozzles location for pressure, temperature and level measuring instruments © Reactors: diameter and T-T length, material of construction, insulation, height from interior tangent to grade level, design pressure andt emperature conditions, representation of internal devices and temperature systems, catalyst beds, nozzles for feed, product, instruments, drain, ete. © Heat exchanger: Type according TEMA, design heat exchanger duty, material of construction, insulation, design pressure and design temperature ©. Fired heaters or furnaces: design absorbed duty, material of construction, insulation, design pressure, design temperature, representation of the number of tube passes, controls at the entrance of the heater, location for pressure, temperature and level measurement instruments. Relief valves, indicating the destination of the line, orifice and body size and set pressure. + Drains and vents ‘+ Indication if pipe has to be sloped and the inclination degree ‘+ Indications of lines which require free draining ‘+ Identification of startup and shutdown lines ‘+ Identification if there is a specification change ‘+ Identification of the sampling points with the arrangements required for sampling ‘* Chemical injection points ‘* Identification of source and destination of the lines that enters or goes out from the drawing, indicating the equipment which they are coming from or going to. + All required lines for shutdown, start-up, load deviations and off-specification products. Include notes which indicate the service type and that this is intermittent, Instruments: © Location and identification of all the instruments on the equipment and lines, with their tags and the correspondent numbering, indicating if it is a field instrument or with signal to the control room © Primary elements type © Indication at the valves if they open, close or keep in po! © Adjustment pressure for relief valves opening Input and output for control systems (DCS, ESD, PLC, etc.) PROCESS "ART-01-120-A-CD-5001_1.docx Distribution Code: A002 REPRODUCED, ANDIOR USED FOR A DIFFERENT PURPOSE FOR WHIGH IT WAS PREPARED WITHOUT PRIOR WRITTEN AUTHORIZATION FROM PEMEX REFNACION ORICA FLUOR™ 02-4014 RO-2401 Page 256 of 282No. ART-01-120-A-CD-5001 CONFIDENTIAL Date: 23-JUN-15, DESIGN CRITERIA Sheet! 67 det © Motor control scheme © Clarification notes about the location of instruments, piping, vent pump destination or equipment drains, or something to be taking into account by the contractor during detail engineering or construction © Notes about information which depends onthe equipment provider, location of critical elements such as valves © Special notes about start up and shut down © Bypass and block valves for control valves © Emergency block valves PROCESS "ART-01-120-A-CD-5001_1.docx Distribution Code: A002 REPRODUCED, ANDIOR USED FOR A DIFFERENT PURPOSE FOR WHIGH IT WAS PREPARED WITHOUT PRIOR WRITTEN AUTHORIZATION FROM PEMEX REFNACION ORICA FLUOR™ 02-4014 RO-2401 Page 257 of 282No. ART-01-120-A-CD-5001 CONFIDENTIAL Date: 23-JUN-15 DESIGN CRITERIA Sheet! 68671 7.0 SAFETY AND ENVIROMENTAL CONSIDERATIONS 7A Safety 7.1.1 Flare and Relief Systems Applicable Standards and Practices Flare and Relief Systems should be in accordance with NRF-031-PEMEX-2011 Flare and Burners Systems, The project Flare System Design Philosophy, ART-01-120-A-FG-5002, document addresses the approach that should be taken by the Project to insure consistent design throughout the plant. Licensor/Contractor should consider these criteria in the development of deliverables. 7.1.2 Hazardous Substances and Areas Applicable Standards and Practices + NRF-232-PEMEX-2010 Personal Protection Clothes andG arments Against Hydrofluoric Acid ‘+ For hydrocarbons and toxic gases such as H2S, SOx and H., leak detection equipment should be specified, as well as their location in the plant and the signaling to central control room and operator's field room, including optical and sound signs that meet the related standards. 7.1.3. Electrical Area Classification Applicable Standards and Practices + NRF-036-PEMEX-2010 Classification of Hazardous Area and Selection of Electrical Equipment 7.14 Fire Protection Applicable Standards and Practices ‘+ NRF-015-PEMEX-2012 Area and Flammable Product and Fuel Storage Protection ‘+ NRF-016-PEMEX-2010 Fire-Fighling Network Design + NRF-019-PEMEX-2011 Fire Protection in Control Rooms Containing Electronic Equipment + NRF-128-PEMEX-2011 Fire-Fighting Networks in Land Industrial Facilities + NRF-184-PEMEX-2013 Gas and Fire Systems: CEP + NRF-205-PEMEX-2008 Gas and Fire Systems: Safety Panels + NRF-210-PEMEX-2013 Gas and Fire Systems: Detection and Alarms 7.1.5 Plant Layout Applicable Standards and Practices PROCESS "ART-01-120-A-CD-5001_1.docx Distribution Code: A002 REPRODUCED, ANDIOR USED FOR A DIFFERENT PURPOSE FOR WHIGH IT WAS PREPARED WITHOUT PRIOR WRITTEN AUTHORIZATION FROM PEMEX REFNACION ORICA FLUOR™ 02-4014 RO-2401 Page 258 of 282No. ART-01-120-A-CD-5001 CONFIDENTIAL Date: 23-JUN-15 DESIGN CRITERIA Sheet! 68de71 + NRF-010-PEMEX-2014 Minimum Spacing and Criteria for Distribution of Industrial Facilities (only for New Plants) 7.2. Environmental ‘+ Any environmental protection improvement should be considered, Environmental impact issues are a major concern and should be minimized, Full Flue Gas Treatment for eneray recovery and low environmental impact is required and the Licensor/Contractor should propose its treatment processing scheme based on its experience and to comply with the maximum fine particles emission standard of 50 mg/Nm’ in the Flue Gas (wet gas scrubbing will be excluded), + Refer to Health, Safety and Environmental (HSE) Basic Philosophy document for additional criteria related to project environmental requirements. PROCESS "ART-01-120-A-CD-5001_1.docx Distribution Code: A002 REPRODUCED, ANDIOR USED FOR A DIFFERENT PURPOSE FOR WHIGH IT WAS PREPARED WITHOUT PRIOR WRITTEN AUTHORIZATION FROM PEMEX REFNACION ORICA FLUOR™ 02-4014 RO-2401 Page 259 of 282No. ART-01-120-A-CD-5001 CONFIDENTIAL Date: 23-JUN-15, DESIGN CRITERIA Sheet! 7ode71 8.0 GENERAL LICENSOR GUIDELINES Licensor/Contractor should fully comply with the following general guidelines in developing the Basic Engineering (BE) and Extended Basic Engineering (EBE) packages: + The development of the Basic Engineering package should contain the requirements and specifications of all the utilities to be used as well as the catalyst and chemicals needed for the unit performance + The specialized technical assistance required for the EPC stages of the project should be provided by licensor. + The Licensor/Contractor should consider all the requirements for the adequate unit operation; therefore it should detail and specify all the critical parts of the process to guarantee the integral unit performance. + Licensor/Contractor should consider and indicate over design capacity in critical circuits, materials selections, scaling factors and oper ational efficiency in order to guarantee an efficient and flexible operation and production capacity during the four years of continuous operation. * Stack gas analyzers required to fulfill the environmental standards should be s pecified Licensor should specify the lab test and the lab equipment required to carry out them, indicating the sample point, method and periodicity, + Licensor/Contractor should provide detailed design drawings for critical equipment and devices. (Including internal devices for all reactors and towers). + Complementary packages, such as condensate recovery system and flare knock out drums should be taken into account for the required area in the plot plan. Licensor/Contractor should consider only spaces ISBL, Fluor-ICA Fluor should be responsible for including and complementing ISBL equipment as well as infrastructures to provide required services, + Licensor/Contractor should include in the PDP, the facilities required for a safe emergency or scheduled shut down. + If any of the design bases items are considered as a technical or economical critical factor, the Licensor/Contractor should propose, according to its experience, the modifications needed to improve the process features, These modifications and the reasons for its inclusion should be proposed to PEMEX for approval, the warranties must be maintained + The Licensor/Contractor should specify critical constructability issues and whether any equipment will be field-fabricated. The maximum wide for passing through road bridges should be according NOM-012-SCT-2-2008. + Licensor/Contractor should include the Chemicals Packages (corrosion inhibitors, antifoam agents, Soda ash, Quelant, Oxygen scavenger agents, etc.,) providing the equipment list (Drums, pumps, heat exchangers, etc.) and typical drawing. + PDP should include a centralized sour water recollection system including tank, pump, etc. to deliver a sour water stream to B.L. + Licensor/Contractor should include the washing water system design, indicating the injection Points to the plant and the metallurgy selection so as to guarantee an efficient operation. The system should be fully instrumented. PROCESS "ART-01-120-A-CD-5001_1.docx Distribution Code: A002 REPRODUCED, ANDIOR USED FOR A DIFFERENT PURPOSE FOR WHIGH IT WAS PREPARED WITHOUT PRIOR WRITTEN AUTHORIZATION FROM PEMEX REFNACION ORICA FLUOR™ 02-4014 RO-2401 age 260 of 282No. ART-01-120-A-CD-5001 CONFIDENTIAL Date: 23-JUN-15 DESIGN CRITERIA Sheet! 71071 + The PDP should consider the use of a feed charge tank and loading pumps with level control system for feedstock rejection in order to guarantee a safe and efficient operation, where appropriate. + Licensor/Contractor should include in this PDP the battery limit diagrams, including all the feed process streams and also product and by products streams. + Licensor/Contractor should include all equipment, accessories, valves, ete. for this process in order to have a safe and reliable unit * All the cyclic operation systems should be automatically operated and should minimize the risk for operator. + Catalysts, chemicals and additives required for the process should be indicated in terms of name, description, MSDS (material safety data sheet), and quantities. + Licensor/Contractor should provide standard specification of materials used in pipes of process of high temperature and corrosive conditions. PROCESS "ART-01-120-A-CD-5001_1.docx Distribution Code: A002 REPRODUCED, ANDIOR USED FOR A DIFFERENT PURPOSE FOR WHIGH IT WAS PREPARED WITHOUT PRIOR WRITTEN AUTHORIZATION FROM PEMEX REFNACION ORICA FLUOR™ 02-4014 RO-2401 Page 261 of 282