IPS-E-PR-230 ENGINEERING STANDARD FOR PIPING & INSTRUMENTATION DIAGRAMS (P & IDs) ORIGINAL EDITION OCT. 1996 This standard specification is reviewed and updated by the relevant technical committee on Oct. 2002. The approved modifications are included in the present issue of IPS.This Standard is the property of Iranian Ministry of Petroleum. All rights are reserved to the owner.Neither whole nor any part of this document may be disclosed to any third party, reproduced, stored inany retrieval system or transmitted in any form or by any means without the prior written consent of theIranian Ministry of Petroleum. Oct.1996 IPS-E-PR-230CONTENTS : PAGE No.0. INTRODUCTION …………………………………………………………………………………………………………….. 31. SCOPE ………………………………………………………………………………………………………………………….. 42. REFERENCES ……………………………………………………………………………………………………………….. 43. DEFINITIONS AND TERMINOLOGY ………………………………………………………………………………… 54. SYMBOLS AND ABBREVIATIONS ………………………………………………………………………………….. 65. UNITS ……………………………………………………………………………………………………………………………. 66. GENERAL ……………………………………………………………………………………………………………………… 6 6.1 Definition…………………………………………………………………………………………………………………. 6 6.2 Representation ………………………………………………………………………………………………………… 6 6.3 Drafting …………………………………………………………………………………………………………………… 6 6.4 Equipment Location Index ……………………………………………………………………………………….. 9 6.5 Drawing Number ……………………………………………………………………………………………………… 9 6.6 Arrangement……………………………………………………………………………………………………………. 97. MINIMUM INFORMATION TO BE SHOWN ON P&I DIAGRAMS……………………………………….. 10 7.1 General ………………………………………………………………………………………………………………….. 10 7.2 Equipment Indication……………………………………………………………………………………………… 10 7.3 Instrumentation ……………………………………………………………………………………………………… 17 7.4 Piping ……………………………………………………………………………………………………………………. 18 7.5 General Notes………………………………………………………………………………………………………… 208. DESIGN CRITERIA FOR PREPARATION OF P&I DIAGRAMS …………………………………………. 21 8.1 Assembly Piping of Pumps…………………………………………………………………………………….. 21 8.2 Steam-Out, Drain and Vent for Vessels …………………………………………………………………… 22 8.3 Bypass for Safety/Relief Valve ……………………………………………………………………………….. 23 8.4 Block and Bypass Valves for Control Valve ……………………………………………………………. 23 8.5 Line Numbering……………………………………………………………………………………………………… 23 8.6 Philosophy of Instrumentation Installation ……………………………………………………………… 24 8.7 Utility Connections ………………………………………………………………………………………………… 24 8.8 Unit Battery Limit Installation …………………………………………………………………………………. 25 8.9 Sample Connections………………………………………………………………………………………………. 27 8.10 Steam Trap Assembly…………………………………………………………………………………………… 279. CRITERIA FOR UTILITY FLOW DIAGRAMS …………………………………………………………………… 2910. ABBREVIATIONS/GRAPHICAL SYMBOLS/IDENTIFICATIONS ……………………………………… 3011. PREPARATION OF P&I DIAGRAMS…………………………………………………………………………….. 31 11.1 General………………………………………………………………………………………………………………… 31 11.2 Establishment of P&IDs Preparation Steps ………………………………………………………….. 31 11.3 Handling of Licensed Process………………………………………………………………………………. 36 11.4 Revisions of P&I Diagram …………………………………………………………………………………….. 37 11.5 Approval of P&I Diagram………………………………………………………………………………………. 38 1 Oct.1996 IPS-E-PR-230APPENDICES:APPENDIX A ABBREVIATIONS/GRAPHICAL SYMBOLS/IDENTIFICATIONS………………………. 39 A.1 Abbreviations………………………………………………………………………………………………………… 40 A.2 Graphical Symbols ………………………………………………………………………………………………… 44APPENDIX B P&IDs/UFDs TITLE BLOCK (TYPICAL)………………………………………………………. 102APPENDIX C REFERENCE BLOCKS ON P&IDs ………………………………………………………………. 103APPENDIX D UTILITIES IDENTIFICATION TABLE (TYPICAL)…………………………………………… 104APPENDIX E NOZZLES IDENTIFICATIONS ON VESSELS, REACTORS AND TOWERS …….. 105APPENDIX F PRESSURE RATINGS DESIGNATIONS-NOMINAL SIZE (IMPERIAL-METRIC) . 106APPENDIX G PIPE COMPONENT-NOMINAL SIZE …………………………………………………………… 107APPENDIX H TYPICAL SAMPLE CONNECTION DETAILS FOR GASES AND LIGHT LIQUIDS(RVP 34.5 KPa)……………………………………………………………………………………………………………. 108APPENDIX I BLOCK AND BYPASS VALVES FOR CONTROL VALVE ………………………………. 109APPENDIX J PHILOSOPHY OF INSTRUMENTATION INSTALLATION………………………………. 110 2 Oct.1996 IPS-E-PR-2300. INTRODUCTIONThe Standard Practice Manuals titled as “Fundamental Requirements for the Project Design andEngineering” is intended for convenience of use and pattern of follow-up and also a guidance.These Standard Engineering Practice Manuals, also indicate the check points to be considered bythe process engineers for assurance of fulfillment of prerequisitions at any stage in theimplementation of process plant projects.It should be noted that these Iranian Petroleum Standards (IPS), as Practice Manuals do notprofess to cover all stages involved in every process project, but they reflect the stages that exist ingeneral in process projects of oil, gas and petrochemical industries of Iran.These preparation stages describe the following three main phases which can be distinguished inevery project & include, but not be limited to: Phase I: Basic Design Stages (containing seven Standards) Phase II: Detailed Design, Engineering and Procurement Stages (containing two Standards) Phase III: Start-Up Sequence and General Commissioning Procedures (containing two Standards)The process engineering standards of this group include the following 11 Standards: STANDARD CODE STANDARD TITLE I) Manuals of Phase I (Numbers 1 – 7) IPS-E-PR-150 “Basic Design Package” IPS-E-PR-170 “Process Flow Diagram” IPS-E-PR-190 “Layout and Spacing” IPS-E-PR-200 “Basic Engineering Design Data” IPS-E-PR-230 “Piping & Instrumentation Diagrams (P&IDs)” IPS-E-PR-250 “Performance Guarantee” IPS-E-PR-308 “Numbering System” II) Manuals of Phase II (Numbers 8&9) IPS-E-PR-260 “Detailed Design, Engineering and Procurement” IPS-E-PR-300 “Plant Technical and Equipment Manuals (Engineering Dossiers)” III) Manuals of Phase III (Numbers10&11) IPS-E-PR-280 “Start-Up Sequence and General Commissioning Procedures” IPS-E-PR-290 “Plant Operating Manuals”This Engineering Standard Specification Covers: “PIPING & INSTRUMENTATION Diagrams (P & IDs)” 3 Oct.1996 IPS-E-PR-2301. SCOPEThis Engineering Standard Specification covers the format and technical basis for the Piping andInstrumentation Diagrams (P&IDs) and Utility Distribution Flow Diagrams (UDFDs) for process,offsite and utility plants. Namely, the purpose of this manual is to indicate in general terms, theextents of detailing, valving philosophy and instrumentation requirements of similar processdesigns.This Standard is also intended to establish uniform symbols for equipment, piping andinstrumentation on P&IDs and UDFDs throughout the Oil, Gas and Petrochemical (OGP) projects.Note:This standard specification is reviewed and updated by the relevant technical committee onOct. 2002. The approved modifications by T.C. were sent to IPS users as amendment No. 1by circular No. 175 on Oct. 2002. These modifications are included in the present issue ofIPS.2. REFERENCESThroughout this Standard the following dated and undated standards/codes are referred to. Thesereferenced documents shall, to the extent specified herein, form a part of this standard. For datedreferences, the edition cited applies. The applicability of changes in dated references that occurafter the cited date shall be mutually agreed upon by the Company and the Vendor. For undatedreferences, the latest edition of the referenced documents (including any supplements andamendments) applies.ASME (AMERICAN SOCIETY OF MECHANICAL ENGINEERS) ASME Code.ANSI (AMERICAN NATIONAL STANDARD INSTITUTE) ANSI B 16.1 “Cast Iron Pipe Flanges and Flanged Fittings, Class 25, 125, 250 and 800” 1st. Ed., 1989IPS (IRANIAN PETROLEUM STANDARDS) IPS-E-PR-200 “Basic Engineering Design Data” IPS-E-PR-308 “Numbering System” IPS-E-PR-725 “Process Design of Plant Waste Sewer Systems” IPS-G-IN-160 “Control Valves” IPS-D-AR-010 “Abbreviations & Symbols for HVAC&R Drawings” IPS-D-AR-011 “General Notes for HVAC & R System”ISA (INSTRUMENT SOCIETY OF AMERICA) ISA-S5.1 “Instrumentation Symbols and Identification” 1st. Ed., 1984 ISA-S5.2 “Binary Logic Diagrams for Process Operations” 2nd. Ed., 1981 ( Reaffirmed 1992 ) ISA-S5.3 “Graphic symbols for distributed control / shared display instrumentation, logic and computer systems “Ed.,1983 4 Oct.1996 IPS-E-PR-230 ISA-S5.4 “Instrument Loop Diagrams” Ed., 1991 ISA-S5.5 “Graphic Symbols for Process Displays” 1st. Ed., 1985 ISA-S18.1 “Annunciator Sequences and Specifications” 1st. Ed., 1979 (Reaffirmed 1992) ISA-S50.1 “Compatibility of analogue signals for electronic industrial process instruments” 1st. Ed., 1975 ( Reaffirmed 1995) ISA-S51.1 “Process Instrumentation Terminology” 1st. Ed., 1979ISO (INTERNATIONAL ORGANIZATION FOR STANDARDIZATION) ISO 3098: Part 1 “Technical Drawings-Lettering, Part 1: Currently Used Characters” 1st. Ed. 1974 ISO 3511: Part 1 & Part 4 “Process measurement control functions and instrumentation-symbolic representation-Part 1: Basic requirements, 1st.Ed. 1977;Part 4: Basic symbols for process computer, Interface, and shared display/control functions” Ed. 1985 1st. Ed., 1984 ISO 6708 “Pipe component definition of nominal size” Ed., 1995.API (AMERICAN PETROLEUM INSTITUTE) API Standard 602 “Compact steel gate valves-flanged, threaded, welding and extended body ends “nine Ed., 19953. DEFINITIONS AND TERMINOLOGY – Company or Employer/Owner: Refers to one of the related and/or affiliated companies of the Iranian ministry of petroleum such as National Iranian Oil Company (NIOC), National Iranian Gas Company (NIGC), National Petrochemical Company (NPC), etc. – Contractor: Refers to the persons, firm or company whose tender has been accepted by the Employer, and includes the Contractor’s personnel representative, successors and permitted assigns. – Licenser: Refers to a company duly organized and existing under the laws of the said company’s country and as referred to in the preamble to the contract. – Project: Refers to the equipment, machinery and materials to be procured by the “Contractor” and the works and/or all activities to be performed and rendered by the “Contractor” in accordance with the terms and conditions of the contract documents. – Unit(s): Refer to one or all process, offsite and/or utility Units and facilities as applicable to form a 5 Oct.1996 IPS-E-PR-230 complete operable oil, gas and/or petrochemical plant .4. SYMBOLS AND ABBREVIATIONSFor symbols and abbreviations refer to Appendix A of this Standard.5. UNITSThis Standard is based on International System of Units (SI), except where otherwise specified.6. GENERAL6.1 DefinitionThe Piping and Instrument Diagram (P&ID), based on the Process Flow Diagram (PFD), representsthe technical realization of a process by means of graphical symbols for equipment and pipingtogether with graphical symbols for process measurement and control functions.The Utility Flow Diagram (UFD) is a special type of a P&ID which represents the utility systemswithin a process plant showing all lines and other means required for the transport, distribution andcollection of utilities. The process equipment in the UFD can be represented as a box withinscription (e.g., identification number) and with utility connections.6.2 RepresentationThe representation and designation of all the equipment, instrumentation and piping should complywith the requirements of this Standard. Auxiliary systems may be represented by rectangular boxeswith reference to the separate diagrams.Dimensions of the graphical symbols for equipment and machinery (except pumps, drivers, valvesand fittings) should reflect the actual dimensions relative to one another as to scale and elevation.The graphical symbols for process measurement and control functions for equipment, machineryand piping, as well as piping and valves themselves, shall be shown in the logical position withrespect to their functions.All equipment shall be represented such that the consistency in their dimensions is considered if notin contrast to the good representation of the equipment.6.3 Drafting6.3.1 General rulesDrafting shall be in accordance with the requirements outlined in this Standard. The drafting mustbe of sufficiently high quality to maintain legibility when the drawing is reduced to an A3 size sheet.6.3.2 Drawings sheet sizesDiagrams shall be shown on A0 size (841 mm × 1189 mm) tracing paper. A1 size (591 mm × 841mm) may be used for simple P&IDs and UFDs as per Company’s approval (see Article 6.3.3.2 fordrawing dimensions and title block sizes).6.3.3 Drawing title block 6 Oct.1996 IPS-E-PR-2306.3.3.1 The following requirements shall be shown on the title block of each drawing (see AppendixB): – revision table; – main Company’s name (e.g., National Iranian Oil Company); – name of Company Relevant Organization, (if any), (e.g., Refineries Engineering and Construction); – name of refinery or plant (in English and Persian words); – Company’s emblem; – Contractor’s name; – drawing title; – Company’s project No.; – Contractor’s job No. (optional); – Contractor’s drawing No. (optional); – Company’s drawing No.6.3.3.2 Title block sizes and drawing dimensions shall be as follows: DRAWING DIMENSIONS TITLE BLOCK SIZE (INCLUDING REVISION TABLE) (mm × mm) WIDTH (mm) × LENGTH (mm) A0 = 841 × 1189 180 × 190 A1 = 594 × 841 130 × 175 A2 = 420 × 594 100 × 155 A3 = 297 × 420 75 × 1206.3.4 Line widthsTo obtain a clear representation, different line widths shall be used. Main flow lines or main pipingshall be highlighted.The following line widths shall be applied: – 0.8 mm for main process lines; – 0.5 mm for other process lines; utility lines, and underground lines; – 0.5 mm for graphical symbols for equipment and machinery, except valves and fittings and piping accessories; – 0.5 mm for rectangular boxes for illustrating Unit operations, process equipment, etc.; – 0.5 mm for subsidiary flow lines or subsidiary product lines and for energy carrier lines and auxiliary system lines; – 0.4 mm for class changes designation; – 0.3 mm for graphical symbols for valves and fittings and piping accessories and for symbols for process measurement and control functions, control and data transmission lines; – 0.3 mm for all electrical, computer and instrument signals; – 0.3 mm for reference lines; Line widths of less than 0.3 mm shall not be used.6.3.5 Line spacingThe space between parallel lines shall not be less than twice the width of the heaviest of these lineswith a minimum value of 1 mm. A spacing of 10 mm and more is desirable between flow lines. 7 Oct.1996 IPS-E-PR-2306.3.6 Direction of flowIn general, the main direction of flow proceeds from left to right and from top to bottom. Inlet andoutlet arrows are used for indicating the inlet and outlet of flows into or out of the diagram.Arrows are incorporated in the line for indicating the direction of the flows within the flow diagram. Ifnecessary for proper understanding, arrows may be used at the inlets to equipment and machinery(except for pumps) and upstream of pipe branches. If a diagram consists of several sheets, theincoming and outgoing flow lines or piping on a sheet may be drawn in such a manner that the linescontinue at the same level when the individual sheets are horizontally aligned.6.3.7 ConnectionsConnections between flow lines or pipelines shall be drawn as shown in Figs. 1 and 2 below: Fig. 1 Fig. 2Figs. 3 and 4 show two flow lines or pipelines, which are not connected: Fig. 3 Fig. 46.3.8 Inscriptions6.3.8.1 Type of letteringLettering in accordance with ISO 3098 Part 1, Type B vertical, to be used.6.3.8.2 Height of letteringThe height of letters should be: – 7 mm for drawing number; – 5 mm for drawing title and identification numbers of major equipment; – 3 mm for other inscriptions. 8 Oct.1996 IPS-E-PR-2306.3.8.3 Arrangement of inscription a) Equipment Identification numbers for equipment should be located close to the relevant graphical symbol, and should not be written into it. Further details (e.g., designation, design capacity, design pressure, etc.) may also be placed under the identification numbers. b) Flow lines or piping Designation of flow lines or piping shall be written parallel to and above horizontal lines and at the left of and parallel to vertical lines. If the beginning and end of flow lines or piping are not immediately recognizable, identical ones should be indicated by corresponding letters. c) Valves and fittings Designation of valves and fittings shall be written next to the graphical symbol and parallel to the direction of flow. d) Process measurement and control functions The representation should be in accordance with the requirements stipulated in ISA-S5.1 and ISO 3511, Parts 1 and 4, latest revisions unless otherwise specified in this Standard.6.4 Equipment Location IndexPiping and Instrument Diagrams shall be divided into equivalent intervals (each in 50 mm) either inlength or width. The intervals shall be designated with numbers from 1 to 23 in length and alphabetsfrom “A” to “P” in width. Equipment location on each diagram shall be addressed by the relevantcoordinates where required. In upper right-hand area of the flow diagram under title of “Item Index”all main equipment shall be listed by equipment number, alphabetically and numerically andequipment location coordinates. In a separate sheet apart from P&IDs, an “Item Index” shall beprepared to summarize all equipment of the Unit/Plant with reference P&IDs and equipmentlocation.6.5 Drawing NumberNumbering of drawings shall be according to IPS-E-PR-308, “Numbering System”.6.6 Arrangement6.6.1 The preferred arrangement is such that towers, vessels and fired heaters be shown in theupper half of the diagram, heat exchange equipment in the upper three quarters as practical, andmachinery equipment in the lower quarter. The spacing of equipment and flow lines shall permitidentification and tracing of the lines easily.6.6.2 The area above the title block on each sheet shall be completely left open for notes.6.6.3 The general flow scheme shall be from left to right. Unnecessary line crossing should beavoided.6.6.4 Process lines entering and leaving the diagram from/to other drawings in the Unit shall beterminated at the lefthand or righthand side of the drawing. Lines from/to higher number drawingsshall enter and leave the drawing on the righthand end and vice versa.6.6.5 Each process line entering or leaving the side of the drawing should indicate the following 9 Oct.1996 IPS-E-PR-230requirements in an identification box (see Appendix C): a) The service b) The origin or destination equipment item number c) Continuation drawing number with the relevant coordinates.6.6.6 Process lines to/from other Units shall be terminated at the bottom of the drawing at a boxindicating (see alsoAppendix C): a) The service b) Source or destination Unit name and number c) The drawing number of the connecting flow diagrams with the relevant coordinates.6.6.7 All utility lines entering or leaving the diagram shall be terminated at any convenient locationat a box indicating the relevant utility service abbreviation (e.g., CWS, CWR, ISA, etc.). See IPS-E-PR-308, “Numbering System” and Appendix A of this Standard for utility services abbreviations. A”Utilities Identification Table” Showing utility services with the reference drawings should beprovided at top or left hand side of each drawing title block (see Appendix D).6.6.8 Instrument, control system and software linkage signals from sheet to sheet shall beterminated preferably at the side of sheet or in an appropriate location at a box indicating thecontinuation instrument number, location, and drawing number (see Appendix C).6.6.9 Equipment descriptions of towers, vessels, tanks, furnaces, exchangers, mixers and otherequipment except machinery shall be located along the top of the flow diagram. Machinerydescriptions shall be along the bottom.7. MINIMUM INFORMATION TO BE SHOWN ON P&I DIAGRAMS7.1 General7.1.1 Each P&ID shall present all information as required herein below during implementation of aproject in detailed design phase. Extent of information shown on each P&ID in the basic designstage shall be agreed by Company in advance.7.1.2 Vendor supplied packages with an outline of the main components shall be shown in adashed/dotted box. Letter “P” referring to package shall be indicated adjacent to each equipmentand instrument of the package.7.1.3 Equipment, instruments or piping which are traced or jacketed, shall be shown.7.1.4 The identification number and service presentation shall be shown for each piece ofequipment. This information shall be indicated in or adjacent to towers, drums, heaters, tanks andheat exchangers, etc.7.2 Equipment Indication7.2.1 Vessels, towers, drums7.2.1.1 The following requirements shall be shown: a) changes of shell diameter (if any); 10 Oct.1996 IPS-E-PR-230 b) top and bottom trays, and those trays which are necessary to locate feed, reflux and product lines; c) all draw-off trays with tray number and diagrammatic representation of the downcommer position (e.g., side or center); d) all nozzles, manholes, instrument connections, drains, vents, pump-out and steam-out connections, blank-off ventilations, vortex breakers, safety/relief valve connections, sample connections and handholes; e) skirt or legs, top and bottom tangent lines; f) elevations above base line to bottom tangent line of column or to bottom of horizontal drum; g) the position of high high liquid level (HHLL), high liquid level (HLL), normal liquid level (NLL), low liquid level (LLL) and low low liquid level (LLLL); Notes: 1) For draw-offs only “NLL” shall be shown. The other liquid positions will be shown as required. 2) Indication of “HHLL” and “LLLL” shall be made only when they are actuating start/stop of an equipment or machinery through a switch. 3) “HLL”, “NLL” and “LLL” shall be shown for all cases except as specified under Note 1 above. h) all flanged connections; [all connections whose purpose is not readily evident shall indicate the purpose (e.g., spare inlet, catalyst draw-off, etc.).]; i) catalyst beds, packings, demisters, chimney trays, distributors, grids, baffles, rotating discs, mixers, cyclones, tangential inlet and all other internals; j) water drop-out boots; k) maintenance blinds for the vessel nozzles.7.2.1.2 Important notes: a) All nozzles and connections indicated on the equipment data sheet shall be shown in their correct positions. b) All indications shall be such that the consistency in the dimensions is considered, although not necessarily to scale. c) Numbering of the trays shall be from bottom to top. d) Height of the vessel bottom tangent line shall be indicated. Self standing : Skirt height Elevated vessel: Minimum required height shall be shown as “min. ….”. e) A valved drain for all columns and vessels shall be indicated. Generally, this valve is to be located on the bottom line outside the skirt and between the vessel and the first pipe line shut-off location (valve or blinding flange). The drain valve shall be located on the bottom of the vessel when: 1) No bottom line is present. or 2) The bottom line is not flushed with the lowest point of the vessel. 11 Oct.1996 IPS-E-PR-230 f) The valved vent with blind flange for all columns and vessels provided on the top of the vessel should be indicated. g) Relief valves generally located on the top outlet line downstream of the vessel blinding location or directly connected to the vessel should be indicated. h) Utility connections on all vessel/columns shall be shown. i) One local PI shall be indicated on top of vessel/column. j) One local TI shall be indicated on the top outlet line of vessel/column. k) Nozzles identifications on vessels, reactors and towers shall be according to Appendix E of this Standard.7.2.1.3 Equipment descriptionThe following requirements shall be described under equipment description: a) vessel item number (this number will also appear adjacent to the vessel); b) service; c) size [inside diameter(s) and tangent to tangent length]; d) design pressure (internal/external) and design temperature; e) indication of insulation; f) line number of vessel trim (this applies to LG & LC connections, vents, sample connections, etc.); g) indication of cladding and lining (if any).7.2.2 Tanks7.2.2.1 The following requirements shall be shown: a) all nozzles, manways, instrument connections, drains, vents, vortex breakers, and safety/relief valve connections; b) all internals such as steam coils, air spargers, tank heaters and etc.7.2.2.2 Equipment description a) equipment item number (this number also appears adjacent to the tank); b) service; c) inside diameter and height; d) nominal capacity, in (m³); e) design pressure and temperature; f) indication of insulation.7.2.3 Fired heaters, boilers, incinerators7.2.3.1 The following requirements shall be shown: a) all nozzles, instrument connections, drains, vents and damper(s); b) ducting arrangement including damper actuators where required; 12 Oct.1996 IPS-E-PR-230 c) detail of draft gages piping and arrangement; d) waste heat recovery system (if present), such as economizer, air preheater, forced draft fan, induced draft fan,etc.; e) decoking connections; f) detail of one complete set of burners for each cell and total burner number required for each type of burner; g) tube coils schematically in correct relative positions and all skinpoint thermocouples; h) logic diagram of shut down system (heat off sequence); i) number of passes and control arrangement; j) snuffing steam nozzles and piping arrangement; k) blow-down and steam-out connections; l) testing facilities; m) convection section (where applicable).7.2.3.2 Equipment description a) item number (this number will also appear adjacent to the equipment); b) service; c) duty (kJ/s); d) design pressure and temperature of coils;7.2.4 Heat exchangers, coolers, reboilers7.2.4.1 The following requirements shall be shown: a) all nozzles, instrument connections, drains and vents, chemical cleaning connections and safety/relief valves as indicated on the equipment data sheet; b) spectacle blinds for the isolation; c) elevations required for process reason (e.g., reboilers, condensers, etc.); d) the connections which allow pressure and temperature survey of heat exchanger facilities; e) the position of high liquid level (HLL), normal liquid level (NLL) and low liquid level (LLL) for kettle type reboilers; f) direction of flow in each side of exchanger.7.2.4.2 Important notesDue considerations should be made for proper indication in the following requirements: a) Generally, direction of flow shall be downflow for cooled media and upflow for heated media. b) Isolation valves shall be provided on inlet and outlet lines where maintenance can be performed on the exchanger with the Unit operating. Provision of by-passing is required for this case. c) Shell and channel piping shall be provided with a valved vent connection and a drain connection unless venting and draining can be done via other equipment. 13 Oct.1996 IPS-E-PR-230 d) At exchangers with circulating heat transfer media, the outlet valve shall be of a throttling type for control of heat duty. e) An inlet and outlet, temperature indicator shall be provided on each exchanger (on either shell or tube side) so that to facilitate checking of heat balance around exchanger. Type of temperature indicator shall be as follows: – A board mounted temperature indicator (TI) shall be provided at the inlet and outlet of all shell and tube process/process exchanger. – For water coolers, the water side outlet shall be provided with a local TI only. The shell side in and out shall be provided with board mounted TIs. – Thermowells (TWs) shall be provided between each shell side and tube side of the same services when the exchangers are in series. – Local indicator type shall be provided for the requirement of local temperature control, such as manual bypass control.7.2.4.3 Equipment description a) equipment item number (this number also appears adjacent to the equipment); b) service; c) duty (kJ/s); d) shell side design pressure and temperature; e) tube side design pressure and temperature; f) indication of insulation.7.2.4.4 Sequence of numbering for stacked exchangers/coolers shall be from top to bottom.7.2.5 Air fin coolers7.2.5.1 The following requirements shall be shown: a) all nozzles and instrument connections; b) blinds for the isolation; c) any automatic control (fan pitch control or louver control) and any alarm (vibration alarm, etc.); d) configuration of inlet and outlet headers and the branches. Only one bundle and fan shall be shown; total number of fans and bundles shall be indicated. When multiple bundles are required, header’s arrangement as separate detailed sketch shall be indicated; e) steam coil and condensate recovery system (if required); f) isolation valves (if required); isolation valves shall be provided in corrosive and fouling services where individual bundles can be repaired and maintained with the Unit operating; g) valved vent and valved drain connection for each header, vent header should be connected to closed system for volatile services; h) a board mounted TI at inlet and outlet, (the TI will monitor the process side of each air fin service). If multiple bundles to be used for fouled services, provide TW’s on the outlet of each bundle.7.2.5.2 Equipment description a) equipment item number (this number will also appear adjacent to the equipment); 14 Oct.1996 IPS-E-PR-230 b) service; c) duty (kJ/s); d) tube side design pressure (internal and external) and design temperature.7.2.6 Rotary machineries7.2.6.1 The following requirements shall be shown:7.2.6.1.1 Pumps a) all nozzles including instrument connections; b) pump suction valve and strainer, and discharge valve and check valve. Provision of wafer type check valve should be avoided unless otherwise specified; c) pump drains and vents piping and destination. d) the type of pump; e) pump auxiliary system connections such as, cooling water, seal oil and lube oil, steam, etc.; f) detail of lube and seal oil /sealing systems, cooling water piping arrangement, and minimum flow bypass line requirement for pumps; g) winterization and/or heat conservation (steam or electrical) where required; h) warm-up and flushing oil lines detail; a DN20 (¾ inch) bypass/drain from the check valve to the pump discharge line shall be provided as warm-up line for the cases specified in item 8.1.4 of this Standard; i) pressure gage located on the discharge of each pump; the gage shall be installed between the pump discharge nozzle and the check valve; j) pressure relief safety valves (if any); k) automatic start-up of standby unit (if required); l) balanced or equalized line for vacuum service.7.2.6.1.2 Compressors and blowers a) type of compressor or blower; b) start-up facilities (i.e., inert gas purge system); c) safety/relief valves; d) suction and discharge valves; e) suction strainer (filter) and discharge check valve; f) suction and discharge pulsation dampener where required; g) valved vents and casing drains; h) winterization (steam or electrical tracing on suction piping) where required; i) lube and seal oil / sealing system and cooling water systems detail arrangement; j) interstage coolers where required; k) surge protection (where required); l) inlet and outlet nozzles; 15 Oct.1996 IPS-E-PR-230 m)all instrument connections.7.2.6.1.3 Steam and gas turbine drivers a) all nozzles and connections; b) detail of all auxiliary systems for steam turbine drivers such as steam supply, condensate return, surface condenser and etc.; c) detail of lube oil, cooling water, etc.; d) all instrumentations such as PI, TI, etc.; e) safety/relief valves; relief valves shall be located between the discharge nozzle and the outlet isolation valve; weep hole at exhaust of the relief valve which opens to atmosphere shall be provided to draw-off the condensate drain. f) warming bypass around inlet isolation valve for steam turbines; the valve on warm-up line shall be DN25 (1 inch) globe type; g) steam traps and condensate recovery system for the steam turbine casing drain and upstream of isolation valve at inlet of the turbine; h) vent line to atmosphere at turbine exhaust; the vent is required for the start-up/test operation of the turbine. i) detail of all firing and control systems for gas turbine drivers.7.2.6.2 Equipment description7.2.6.2.1 Pumps a) pump item number (this number also appears below the pump); b) service; c) capacity, (m³/h, dm³/h for injection pumps); d) differential pressure, (kPa); e) relative density (specific gravity) of pumped fluid at pumping temperature; f) indication of insulation and tracing; g) miscellaneous auxiliary piping (CW, flushing oil, seal oil, etc.).7.2.6.2.2 Compressors and blowers a) equipment item number and stage (this number also appears below the compressor); b) service: c) capacity, (Nm³/h); d) suction pressure, and temperature, [kPa (g)], (°C); e) discharge pressure, and temperature, [kPa (g)], (°C); f) miscellaneous auxiliary piping (CW, lube, oil, seal oil / sealing system, etc.); g) gas horse power, (kW).7.2.6.3 Other requirements a) When a pump or compressor is spared, the data is listed once commonly for both pumps at the bottom of the flow diagram. The spare is identified by the word “Spare” below the pump or compressor. The operating equipment and the spare have the same number but with suffixes “A” and “B”. 16 Oct.1996 IPS-E-PR-230 b) Stage numbers are shown only for multistage compressors. All compressor data for the first stage shall be indicated. For subsequent stages only N m³/h may be omitted.7.2.7 Miscellaneous equipmentDepending on the type of equipment (silensor, flame arrestor, filter, etc.) the following informationshall be presented: a) all nozzles, instrument connections, vents, drains, etc.; b) equipment description at top of the flow diagram and including: – equipment item number; – service; – tracing/insulation requirements; – design pressure and temperature; – capacity.7.3 InstrumentationThe following requirements shall be shown:7.3.1 all instrumentation including test points;7.3.2 isolation valves connecting to instruments (primary connection valve);7.3.3 control valve sizes and air failure action (FC, FO, FL);7.3.4 block and bypass valve sizes at control valve stations;7.3.5 level gages connection type and range, and level controllers connection type, range andcenter of float (where NLL is not shown). Type, material and tracing requirement of level gages shallbe shown (see IPS-E-PR-308);7.3.6 sequence of opening and closing for the split range control valves;7.3.7 solenoid shut-down devices at control valves/shut-off valves;7.3.8 tight shut-off valves requirements (where required);7.3.9 handwheels when provided on control valves;7.3.10 limit switches on control valves when required;7.3.11 mechanical stopper and/or signal stopper on control valves when required;7.3.12 push buttons and switches associated with shut-down systems;7.3.13 the instrument tag number for each instrument;7.3.14 analyzer loop details and special notes as required;7.3.15 winterization of instruments;7.3.16 compressor local board mounted instrumentation;7.3.17 software linkage and alarm and shut-down logic system. Complex shut-down systems shallbe shown as a “black box” with reference made to the logic diagram shown on a separate sheet. Allactuating and actuated devices shall be connected to the “black box”;7.3.18 all elements of advance control and optimization systems;7.3.19 indication of “Readable From” for all local indicators and/or gages which shall be readablefrom a designated valve. 17 Oct.1996 IPS-E-PR-2307.4 Piping7.4.1 General7.4.1.1 All piping shall be shown on P&I Diagrams, including: – process lines; – utility/common facility branch lines (e.g., sealing and flushing lines, cooling water lines, steam-out lines and connection, nitrogen lines, etc.); – flare lines, including safety/relief valves discharge lines; – start-up and shut-down lines; – pump-out lines; – drain and vent lines and connections; – purge and steam-out facilities; – catalyst regeneration lines; – catalyst sulphiding lines; – catalyst reduction lines; – equipment and control valve bypasses; – detail of spool pieces, equipment internals, etc., when required; – steam tracing and steam jacketing.7.4.1.2 All line numbers, sizes and line classification shall be shown. For line numbering system seeIPS-E-PR-308, “Numbering System”.7.4.1.3 The direction of normal flow shall be shown for all lines.7.4.1.4 The points or spec. breaks at which line sizes or line specifications change shall be clearlyindicated.7.4.1.5 All blinds shall be indicated on the drawings, and the symbols used shall distinguishbetween tab blinds and spectacle blinds.7.4.1.6 All vent and drain connections shall be identified whether screw caped or blind flanged, ifrequired.7.4.1.7 Steam traced lines and steam jacketed lines shall be so indicated.7.4.1.8 All equipment flanges, all reducers and non-standard fittings, such as expansion bellows,flexible tubes, shall be shown.7.4.1.9 All valves shall be shown by a symbol representing the type of valve. Any special orientationor location required for process reason and/or operability shall be shown. It is not necessary toshow flanges at flanged valves except for those cases where the flanges deviate from the pipingspecification for the line in question, in which case flange and rating shall be shown. Any isolatingvalve shall be shown locked, normally open or closed.7.4.1.10 Control valve sizes shall be shown.7.4.1.11 All valves shown on the flow diagram shall have their size indicated by the valve, if differentfrom line size.7.4.1.12 Insulation and tracing requirements shall be covered in the line numbering system andshown above the line (see IPS-E-PR-308, “Numbering System”). Tracing requirement shall benoted on P&IDs by a dashed line parallel to the line to be traced.7.4.1.13 Valve boxes/valve pits shall be shown by two embraced squares or rectangulars withindication of “Valve Box” or “Valve Pit”. 18 Oct.1996 IPS-E-PR-2307.4.1.14 Safety relief valves type, inlet and outlet size and rating and set pressure should be shown.7.4.1.15 For pressure ratings designations-nominal size and pipe component-nominal size seeAppendices F & G of this Standard respectively.7.4.2 Special requirements7.4.2.1 High point vents and low point drains are shown only when they are connected to a closedsystem, or are required for process reasons.7.4.2.2 Utility lines originate and terminate adjacent to the equipment involved shall be shown. Onlythe length of line necessary for valving, instrumentation and line numbering is shown. Utility lineorigin and terminus is indicated by reference symbol or abbreviation only. Main utility headers arenot shown on the P&IDs; they are shown on the utility system flow diagrams7.4.2.3 Pertinent information regarding a line such as “do not pocket” or “slope”, etc., shall be notedadjacent to the line.7.4.2.4 Typical air cooler manifold piping arrangement should be shown.7.4.2.5 Connections on process lines which require to be blanked or deblanked for flow directionunder special circumstances to be shown on P&ID.7.4.2.6 Reduction and enlargement in line size are indicated by line size designation, and reducerand expander symbols.7.4.2.7 Calculated wall thicknesses and/or schedules not already prespecified in the individual lineclasses shall be shown on the flow diagrams.7.4.2.8 Corrosion allowances other than the nominal allowances indicated in the individual lineclasses shall be shown on the diagrams.7.4.2.9 All operating drains shall be noted and sized on the flow diagrams and shall be routed to adrain funnel. Destination of the drains shall be according to the relevant specifications (see IPS-E-PR-725). All drains carrying light hydrocarbons (Reid vapor pressure 34.5 kPa absolute or greater)shall be segregated from the oily sewer system, and shall be connected to the flare system.7.4.2.10 Sample and test connections shall be shown on the diagrams where required. Sampleswhich require cooling and connections to the flare, shall be shown with the cooling and flare linesconnections.7.4.2.11 Emergency showers, eye wash fountains and utility stations shall be shown on the UtilityDistribution Flow Diagrams.7.4.2.12 Any locations where slopes, straight runs, minimum mixing runs, etc., are required forprocess reasons must be indicated.7.4.2.13 The necessary instrumentation and piping for start-up, control and shut-down, etc., shouldbe shown for any equipment on P&ID wherever applicable.7.4.2.14 Break points between underground and aboveground piping with insulating flanges (ifrequired) shall be shown.7.4.2.15 Minimum distance requirement for in line blending to be indicated.7.4.2.16 Weep hole requirement to be shown.7.4.3 Piping specialty items7.4.3.1 Piping components not identified by instrument or mechanical equipment numbers, etc., andnot covered by the piping material specification, shall be identified by assigning a Specialty ItemNumber or an Item Code Number for identification symbol and shall be shown on the diagrams.7.4.3.2 Symbol “M” standing for “Monel Trim” should be mentioned on the valves on the P&IDs in 19 Oct.1996 IPS-E-PR-230services where there is a possibility of condensed water and H2S being present except for the lineclasses which provide monel trim valves and other features. Where it is intended that the whole lineshould have monel trim valves it should also be indicated on the line list.7.4.3.3 ASME and non ASME Code change should be indicated for connection whereverapplicable.7.4.4 Steam traps & winterizing systemThe following requirements shall be followed:7.4.4.1 Steam traps pertaining to the winterizing systems (steam tracing) are not shown on theP&IDs except for the following cases: – at dead ends/pockets on steam lines; – at upstream of the Unit battery limit main block valves on steam lines; – at all points which there is possibility of condensation; – at upstream of the first block valve of steam line going to the steam turbine drivers, steam coils or steam reboilers.7.4.4.2 Steam trap and the relevant steam and condensate lines to be shown for all steam reboilers,heaters, coils, etc.7.4.4.3 Steam/electrical tracing requirement shall be noted on P&IDs by a dashed line parallel to theline to be traced.7.5 General NotesGeneral notes to be put on the front sheet of P&I Diagrams of each “Unit” under title of “GeneralNotes”. Reference should be made to the front sheet drawing No. showing “General Notes”, oneach P&I Diagram.7.5.1 The following general notes shall be specified as minimum requirement:7.5.1.1 All dimensions are in millimeters except as noted.7.5.1.2 Elevations shown are above the highest point of paving.7.5.1.3 All valves are line size unless otherwise shown.7.5.1.4 This flow diagram is diagrammatic only. Design of pipe lines must be investigated forventing of gas and vapor pockets in piping and equipment, low points in piping, pumps andequipment for freezing and draining and accessibility of all valves, flanges and instruments includingthermocouples etc.7.5.1.5 All electronic instrumentation shall be installed away from steam lines and high temperatureheat sources.7.5.1.6 For level transmitter center of float is NLL. The range shall cover the difference between LLL& HLL.7.5.1.7 Sample tappings for gas samples shall be from the top of the main line. For liquid samplestapping shall be done from the side.7.5.1.8 Except for process reasons, low point drains and high point vents are not shown.7.5.1.9 All items marked (P) can be supplied as part of package Units.7.5.1.10 Temperature instruments shown with “M” are provided with monel well.7.5.2 The following general notes may be specified as required: 20 Oct.1996 IPS-E-PR-2307.5.2.1 Piping drains and ventsLow point drains and high point vents of piping shall be provided in accordance with the following: a) Drains for all sizes – alloy piping: DN 20 (¾ inch) gate valve with blind flange. – carbon steel piping: DN 20 (¾ inch) gate valve with threaded plug. b) Vents for DN 50 (2 inch) and larger High point vent shall be provided for the piping of DN 50 (2 inch) and larger. Size and type are based on the following: – alloy piping: DN 20 (¾ inch) gate valve with blind flange; – carbon steel piping: DN 20 (¾ inch) gate valve with threaded plug; – the vent provided for hydrostatic testing shall be DN 20 (¾ inch) boss with threaded plug.7.5.2.2 Block valves on orifice tap a) DN 15 (½ inch) single gate valve shall be provided for the all orifices of the piping class of PN 100 (600 #) and less. b) DN 20 (¾ inch) single gate valve shall be provided for the all orifices of the piping class of PN 150 (900#) and over.7.5.2.3 Drain valve of level gages and instruments: a) Drain valves [DN 20 (¾ inch) gate valve] shall be provided. b) The provisions should be made for routing the drain of liquids with RVP of greater than 34.5 kPa (abs) to flare.8. DESIGN CRITERIA FOR PREPARATION OF P&I DIAGRAMSThe following design criteria shall be applied for preparation of P&I Diagrams unless otherwisespecified in the relevant piping and/or equipment specifications of the Company. In case of anyconflict, the specific piping and/or equipment specifications will be governed.8.1 Assembly Piping of Pumps8.1.1 Valve size selection basis for pumpsGenerally, the size is likely different between pump suction line and pump suction nozzle, or pumpdischarge line and pump discharge nozzle.In case that, pump nozzle is one or more sizes smaller than the line size, the size of block valveshall be in accordance with the following: NOZZLE BLOCK VALVE AT PUMP 1- One size smaller than line 1- Same as suction line size SUCTION 2- Two or more sizes smaller than line 2- Select one size smaller than line AT PUMP Smaller than discharge line Select one size smaller than line 21 Oct.1996 IPS-E-PR-230 DISCHARGE8.1.2 Pump strainer8.1.2.1 The suction strainer of pumps shall be selected in accordance with the following criteria: LINE SIZE STRAINER TYPE DN 80 (3 inch) and larger T DN 50 (2 inch) and smaller Y8.1.2.2 Strainers DN150 (6 inch) and larger shall have DN 25 (one inch) drain valve.8.1.3 Pump vents and drainsVent gas from pump casing drains and vents shall be routed to closed system such as flare for thefollowing services: a) fluids containing toxic material; b) fluids with a Reid vapor pressure greater than 34.5 kPa (abs) at pump operating temperature.In addition to the above, the vent of casing for the vacuum service should be routed back to thesuction vessel to make out the pressure balance prior to the pump operation. Drain of hydrocarbonpumps shall also have disposal to oily water sewer in all cases in addition to the aboverequirements unless otherwise specified (see IPS-E-PR-725 for drain destinations).8.1.4 Warming-Up lineThe provisions for warming-up of pump is required for the pump operated at 170°C and higher orwhen the process fluid solidifies at ambient conditions or the fluids are corrosive or toxic.8.1.5 Auxiliary piping of pumpDetails of auxiliary piping such as, cooling water, plant water, steam and condensate, mechanicalseal flush fluid, etc., which are required as per pump data sheet shall be shown on a separatedrawing. Reference to the auxiliary piping drawing shall be noted under the pump description.8.2 Steam-Out, Drain and Vent for Vessels8.2.1 Size and requirement of steam-out, vent and drain nozzles of vessels shall be according tothe requirements stipulated in IPS-E-PR-200, “Basic Engineering Design Data”. The vent valve shallbe directly mounted on the vent nozzle with blind flange.8.2.2 In addition to the vents required in article 8.2.1 above, a blanked off ventilation nozzle shall beprovided on the top of the all horizontal vessels near the end opposite the manway. See IPS-E-PR-200 for size of the blanked off ventilation nozzle.8.2.3 Vent connections must be located on top of the vertical and horizontal vessels.8.2.4 The drain valve will be provided as follows: – For low pressure services, up to design pressure of 3800 kPa, provide single block valve with blind plate. – For high pressure services over design pressure of 3800 kPa, or where the nature of liquid requires it, provide double block valves with blind plate. 22 Oct.1996 IPS-E-PR-2308.3 Bypass for Safety/Relief ValveThe bypass shall be provided for venting the hydrocarbon gas or toxic gas to flare system whileplant shut-down or start-up. Provision of bypass shall be as per following criteria:8.3.1 VesselsBypass shall be provided unless otherwise specified in the relevant Company’s specifications.8.3.2 Piping/Equipment8.3.2.1 Gas service a) If there is other purge line to flare on same stream line, bypass is not required for safety/relief valve. b) In case of no purge line to flare for toxic or flammable hydrocarbon, bypass valve shall be provided. The size of bypass valve and line shall be same as the vent size of piping/equipment.8.3.2.2 Liquid serviceBypass valves are generally not provided for liquid service unless otherwise specified.8.4 Block and Bypass Valves for Control ValveReference to be made to Appendix I of this Standard.8.5 Line Numbering a) For line numbering system reference should be made to IPS-E-PR-308, “Numbering System”. b) Line numbers shall be assigned to all lines with the following origins and destinations: – from individual equipment item to individual equipment item; – from line to individual equipment item and vice versa. Another number is required for the line located at the downstream of equipment; – from line to line (exceptions: control valve bypass, block valve warm-up and equalizing bypasses, and safety/relief valve bypass); – from unique equipment to the same unique equipment item (except level standpipes); – from line or equipment to atmosphere, funnel, or closed drainage system (exception: continuous process vent stacks and process drains). c) Pipe line numbers shall be prefixed, from source to Unit battery limit with the Unit number of the Unit of origin. d) A new line number is required when the pipe design condition can vary (e.g., downstream of the control valve assembly) or when a new piping class is to be specified. e) Line number shall be held up to the point where the line ends to the header or Unit battery limit block valve. All branches to and from header shall have an individual line number. f) All utility headers (systems) including all steam, water and sewer lines shall be numbered with their respective Units. All branches serving a specific Unit will be numbered with that Unit. 23 Oct.1996 IPS-E-PR-230 g) Line numbers shall be selected so that consecutive line numbers are grouped first by common service. Spare line numbers may be left between the groupings. h) All process lines routed from Unit to Unit shall be assigned on interconnecting line number. Within the process Unit(s), Unit line numbers are to be assigned. The interconnecting Unit P&I Diagram is to show every interconnecting process line and indicate the line numbers inside the process Units at the Units battery limits.8.6 Philosophy of Instrumentation InstallationReference to be made to Appendix J of this Standard.8.7 Utility ConnectionsUtility connections to process line and equipment for steam and nitrogen shall be as follows:8.7.1 Connections to process line and/or equipment (see Figs. 5 and 6): 24 Oct.1996 IPS-E-PR-230Notes on utility tie-in:1) The isolation valve may be omitted if the process line is open to atmosphere.2) Provide a drain at downstream of check valve to check the leakage.3) Provide spectacle blind and block valve for N2 service.4) Main block valve for steam service shall be at the branch point from steam header.5) This configuration shall be used for low pressure steam (all sizes). For medium and highpressure steam double block valves with bleeder between the valves is required.8.7.2 Connections to vessel for steam-out8.7.2.1 Permanent steam-out connection (see Fig. 7): Fig. 78.7.2.2 Temporary steam-out connection (see Fig. 8): Fig. 88.8 Unit Battery Limit Installation8.8.1 Process lines (see Figs. 9 and 10): 25 Oct.1996 IPS-E-PR-230 Fig. 9 Fig. 10Notes on Unit battery limit installation requirements:1) Provide for hydrogen, nitrogen, toxic gases and all high pressure fluids (P>3800 kPa),double block valves, spectacle blind and drain as shown in Fig. 10.2) Provide for each process line (not included in item 1 above) an isolation valve, spectacleblind and drain as shown in Fig. 9.3) Provide a flow indicator and recorder shown on board for each process stream enteringand leaving each Unit. Do not duplicate measuring elements in the same stream within oneblock area.4) Provide a board mounted TI on each process stream entering and leaving the Unit where aflow integrator is provided. Do not duplicate with TIs required for other purposes. Generally,the TI to be located at downstream of the flow element.5) Provide a sample station for all products leaving and/or entering the Unit.6) Product streams leaving Units shall be piped at the Unit limits to the relevant slops header(light or heavy slops) as well as for the start-up (off-spec.) operation.7) Provide a local PI on each process stream entering and/or leaving the Unit. Do notduplicate with PIs required on the same streams. PI may be board mounted as required.8) Special attention should be made to the possibility of avoiding duplication of some or allof the above mentioned hardwares on the adjacent Units.8.8.2 Utility lines (see Figs. 11, 12 and 13): 26 Oct.1996 IPS-E-PR-230 Fig. 11 Fig. 12 Fig. 13Notes on Unit battery limit installation requirements:1) Provide valves, drains and instrumentation as shown in Fig. 11 for the following cases: – low pressure steam (all sizes); – medium pressure and high pressure steam [sizes smaller than DN200 (4 inch)]; – boiler feed water.2) Provide valves, drains and instrumentation as shown in Fig. 12 for medium and highpressure steams for DN200 (4 inch) and larger sizes.3) Fig. 13 shall be applied for condensate lines.4) A line size boot at upstream of the first isolation valve shall be provided and shalldischarge condensate to the condensate recovery system through steam trap. The boot andsteam trap requirement is not needed for boiler feed water streams.8.9 Sample ConnectionsFor sample connection symbols, reference to be made to Appendix H and Section A.2.2.1 ofAppendix A of this Standard.8.10 Steam Trap AssemblyFor individual steam trap symbols reference to be made to Section A.2.2.1 of Appendix A of thisStandard.8.10.1 Steam trap assembly with internal strainer for different services: a) Winterizing (see Fig. 14): 27 Oct.1996 IPS-E-PR-230 Fig. 14 The following symbol can be used to demonstrate the steam trap assembly configuration as shown in Fig. 14 above on P&IDs and UFDs in order to avoid duplication. b) Heat Conservation (see Fig. 15): Fig. 15 The following symbol can be used in place of the steam trap assembly shown in Fig. 15 above on P&IDs and UFDs.8.10.2 Steam trap assembly with external strainer (see Fig. 16): 28 Oct.1996 IPS-E-PR-230 Fig. 169. CRITERIA FOR UTILITY FLOW DIAGRAMS9.1 The Utility Flow Diagram(s) (UFDs) shall be prepared as separate drawing titled as “UtilitiesDistribution Flow Diagram”. The distribution of utilities for plant operation shall be shown on thedrawing. The utilities for plant operation are generally classified as follows where applicable: – several grades of steam; – several grades of condensate; – boiler feed water; – cooling water and sea water ; – raw (fresh) water; – plant and potable water; – fuel oil and fuel gas; – instrument and plant air; – nitrogen; – inert gas; – seal oil/flushing oil; – closed circuit hot oil system; – flare and blow-down; – chemical system such as caustic and ammonia.The above utilities are classified into several groups and shown on diagram(s) in accordance withthe next articles. A dedicated drawing shall be prepared for “Flare and Blow-down”.9.2 Utility Flow Diagrams shall be presented in accordance with the requirements stipulated in thisStandard for P&IDs where applicable.9.3 Utility Flow Diagrams shall show main distribution/collection headers and finger headers withtheir isolating facilities and instrumentation. The branch line and subheader arrangement shall beshown as practical as possible.9.4 Indication criteria of connection between P&IDs and UFDs is according to the following generalphilosophy: a) The indication of isolation valve shall not be duplicated on P&ID and UFD. b) Valve and instrument which will be used for the normal operation shall be indicated on P&ID, such as: – block valves for water cooler inlet and outlet; – block valves for snuffing steam of heater; 29 Oct.1996 IPS-E-PR-230 – globe valve for steam injection control; – control valves for fuel control. c) Valves which will be used only for start-up and shut-down shall be indicated on the UFD such as: – header isolation valve for steam purge connection; – isolation valve for fuel gas or fuel oil.9.5 Utility/common facility branch line header valves at the process Unit battery limit shall be shown.The Utility Flow Diagram shall also indicate any valve in utility/common facility individual branchlines required for process and maintenance operations even if these valves may be physicallylocated in the pipe rack or the sequence of branches may allow in the future for a single valve toserve several branch lines.9.6 Isolation facilities shall be indicated for: – finger areas; – process Unit block areas; – at position of change from pipe rack to pipe rack.9.7 The finger area is defined as being the area that serves a particular process area which mayconsist of one or more process Units. In addition to the equipment that is located alongside thefinger pipe rack, the finger area also includes the equipment located alongside the main pipe rack.9.8 Utility Flow Diagram shall be arranged to cover the whole refinery/plant area and these aredivided into separate sheets each with corresponding match lines. Depending on the complexityand extent of the particular utility/common facility, sheets may be combined, extended or omitted asrequired.9.9 All equipment that is supplying a particular utility common facility either from the system (e.g.,steam boilers) or from a process Unit (e.g., waste heat boilers) shall be shown in a “box” ingeographical location. This “box” shall give relevant equipment number(s), Unit number and sheetnumber of the drawing in which the equipment is detailed.10. ABBREVIATIONS/GRAPHICAL SYMBOLS/IDENTIFICATIONS10.1 Graphical symbols presented in Appendix A shall be used throughout the Oil, Gas andPetrochemical projects in order to establish uniform symbols for equipment, piping andinstrumentation on P&IDs and UFDs. This include also Vendor drawings with the same purpose.10.2 The graphical symbols shown for equipment may be turned or mirrored, if their meaning doesnot depend on the orientation. The representation of some graphical symbols (i.e., columns,vessels, etc.) can be adjusted to the actual scale with respect to the process plant.The instrumentation symbol size may vary accordingly as required and as per type of document.However, consistency should be followed in all similar documents.10.3 For complete equipment codes, instrument identification and instrumentation legends,reference should be made to IPS-E-PR-308, “Numbering System”.10.4 For all instrumentation symbols, logic diagrams, loop diagrams and graphical symbols notshown in this Standard and/or in IPS-E-PR-308, reference should be made to the latest revision ofthe following ISA standards: S5.1, “Instrumentation Symbols and Identification” S5.2, “Binary Logic Diagrams for Process Operations” S5.3, “Graphical Symbols for Distributed Control/Shared Display Instrumentation, Logic and Computer Systems” S5.4, “Instrument Loop Diagrams” S5.5, “Graphic Symbols for Process Displays” S18.1, “Annunciator Sequences and Specs” S50.1, “Compatibility of Analogue Signals for Electronic Industrial Process Instruments” S51.1, “Process Instrumentation Terminology”10.5 Reference should be made to IPS-E-PR-308, “Numbering System” for the followingrequirements: 30 Oct.1996 IPS-E-PR-230 – Numbering of all Equipment, Piping and instrumentation. – Unit Identification Number. – Equipment Category Symbol (Equipment Codes). – Instrumentation Identification Letters. – Instrumentation Typical Letter Combinations. – Painting, Insulation and Heat Tracing Designation. – Electrical Equipment Category Code. – System Distinction and Equipment Category Code for Communication Equipment. – Drawing Serial Number. – Fluid Abbreviation Symbols. – Building Drawing Categories. – Definition of Nominal Size.10.6 Package Units are referred to a combination of completely prefabricated equipment with theiraccessories on a skidframe or delivered as prefabricated components for further field erection. SuchUnits are generally tagged with the letter “P”. The extent of a package is shown in a box with lines.The tag numbers of the individual equipment and instrumentation inside a package shall be givenwithin the package Units (see IPS-E-PR-308 for Numbering Procedure).10.7 Appropriate graphical symbol should be provided by the Contractor for any special feature notshown in Appendix A, upon the Company’s approval.11. PREPARATION OF P&I DIAGRAMS11.1 GeneralAs the P&I Diagram contains a large amount of plant design information, its revision will have agreat effect on the subsequent engineering works.Accordingly for the purpose of minimizing the revisions and avoiding unnecessary works, the stepsfor preparing the P&I Diagrams shall be established. The following steps should be realized inpreparing the P&I Diagrams. Upon the information which can be prepared as engineering workproceeds, steps 2, 3 and 4 may be combined or extended to more steps as required. Step 1 Preparatory Step for Preparation of the P&I Diagrams Step 2 P&I Diagrams for Engineering Start Step 3 P&I Diagrams for Piping Layout Step 4 P&I Diagrams for Piping Drawings Step 5 P&I Diagrams for Construction Step 6 P&I Diagrams As-builtIn the case where the P&I Diagrams are prepared by the Licensor, only a part of the above-mentioned steps is applied and the main Contractor shall be responsible to complete the P&IDspreparation steps. The extent of Licensor’s and Contractor’s scope of work will be according to therelevant contracts.11.2 Establishment of P&IDs Preparation Steps11.2.1 Step 1, preparatory step for preparation of P&I diagramsThrough step 1, the basic design philosophy concerning those basic items for the preparation ofP&IDs such as mode of indication, applicable standards, numbering system, valve arrangement andthose other basic items on which agreements shall be made by the Company prior to thepreparation of the P&ID should be clarified.The basic items which should be taken into consideration in step 1 are listed herein below butshould not be limited to the following items: 31 Oct.1996 IPS-E-PR-230a) Vellum and drafting – size and vellum of drawing; – title; – drafting; – arrangement; – equipment description; – interconnection.b) Numbering System – drawing No.; – equipment No.; – instrument tag No.; – line No.c) Symbol – equipment; – piping components; – instrument symbol; – process stream symbol; – utility symbol.d) Valve arrangement around equipment – valve arrangement for drain, vent and purge; – valve arrangement for steam-out; – sizes of the nozzles for installing the instruments; – valve arrangement around the heater and exchanger; – valve arrangement around the pump and compressor; – valve arrangement around the steam turbine.e) Piping – piping classification standards; – valve arrangement at the battery limit; – valve arrangement for drain, vent, purge and steam-out on piping; – valve arrangement around the steam trap; – valve arrangement around the sample point/sample connections; – blow-down; – valve type selection criteria/standards; – strainer type selection standards; – pipe line sizing criteria.f) Instrumentation – valve arrangement around the control valve; – valve arrangement around the safety/relief valve; – valve arrangement around other instruments; – instrument type selection standards; – mode of indication concerning computer control; – software linkage and DCS presentation.g) Miscellaneous – winterizing and heat conservation; – recovery of steam condensate; 32 Oct.1996 IPS-E-PR-230 – disposal of drains and waste water effluent.For the purpose of obtaining a unified design philosophy and appropriate design relations amongthe Units, the illustrated process considerations concerning operation (start-up, normal, shut-down),safety and other features of the Unit shall be achieved by indicating on the Process Flow Diagram(PFD). Where it does not suffice to give more illustrations, additional brief written explanations shallbe provided. The items which should be covered to complete the design and operation philosophyand shown on P&ID (as required) shall include but not be limited to the following requirements(where applicable): 1) Precommissioning and start-up operations: – flushing; – purging; – soda washing(where required); – chemical cleaning; – steaming-out; – evacuation; – drying; – water operation; – cold circulation; – hot circulation; – catalyst pretreating such as sulfiding, reduction, etc.; – feed cut-in; – off-spec. product handling. 2) Normal operation: – recorder and indicator points; – stream analyzer point; – sampling point and type; – control valve block and bypass; – driver type; – chemical injection point and types of chemical; – batch operation; – local start; – instrumentation and control system needed for optimization and/or process control. 3) Shut-down operation – depressuring; – feed cut-out; – cooling; – purging; – steaming-out and flushing; – decoking; – catalyst regeneration. 4) Safety operation – location of safety/relief valves; – failure action of control valves; – prealarm system; -emergency shut-down system; -auto start of equipment/system.Results of hazard analysis and operability (HAZOP) study (if any) note :contractor shall perform the 33 Oct.1996 IPS-E-PR-230HAZOP study (if required by the owner) using PFD, p&ID and plot plan together with equipmentdata sheets and related safety equipment checklist. Contractor shall provide information about thereported accidents in similar process units in the world during HAZOP meetings.The Contractor should prepare both the draft of the basic items for preparation of the P&I Diagramsand all necessary operation and safety features as mentioned above to Company’s review andapproval before issuance of official revision of P&I Diagram for engineering start.11.2.2 Step 2, P&I diagram for engineering startThe following information as minimum requirement shall be reviewed and completed at this stage: 1) Equipment – number of equipment; – type of equipment; – equipment No. and name. 2) Piping – size of main piping; – winterizing/heat conservation requirement; – valve type; – provision of drain and vent; – provision of purge, steam-out, chemical injection and water injection connections and valving; – line No.; – utility services connected to each equipment, piping and packaged Unites. 3) Instrumentation – type of instrument and location of the primary element; – location and discharge destination of the safety/relief valve; – location, type and valve functioning (failure action) of the control valve; – measurement and control method; – instrument tag No.The draft of the P&I Diagram for engineering start shall be sent to the Company’s review. After thejoint meeting between the Company and Contractor, the P&I Diagram for engineering start can beofficially issued based on the established Company’s comments as per the agreed items mentionedin the relevant minutes of meeting.11.2.3 Step 3, P&I Diagram for piping layoutThe purpose of issuing the P&I Diagrams for piping layout is the Company’s approval on the basisof detailed design for piping layout.The minimum information which should be added on the P&ID at this stage shall be as follows: 1) Equipment – elevation of equipment; – size of equipment; – internal of equipment. 2) Piping – line class; – miscellaneous piping size (except around the safety/relief valve and control valve); – thermal and cold insulation; – precautions concerning piping layout; – correct orientation of piping around equipment. 34 Oct.1996 IPS-E-PR-230 3) Instrumentation – size of main control valves; – additions and revisions on the basis of detailed design. 4) Vendors packaged units – The details of some available information concerning the Vendors shall be indicated.11.2.4 Step 4, P&I diagram for piping drawingsThe following information shall be added on the P&IDs at this stage: 1) Piping – piping around the safety/relief valve and control valve; – size of all valves; – additional review of the pipe size and branch by the checking of the piping layout; – hydraulic of system (checking and implementation of the necessary notes). 2) Instrumentation – sizes of the safety/relief valves; – sizes of the control valves; – details concerning level transmitters and level gages; – logic diagram for heaters, incinerators, compressors, and all other main equipment (where applicable). – Consequences of details of cause and effect tables. 3) Vendors information – The necessary information concerning the Vendors, equipment shall be indicated.11.2.5 Step 5, P&I diagram for construction11.2.5.1 At a stage where detailed design has been nearly completed, upon approval of theCompany, the P&I Diagram shall be frozen for the purpose of smooth execution of the constructionwork.11.2.5.2 The P&I Diagram shall be issued for construction after completion of the followingactivities: – piping material table; – piping class and all relevant job specifications; – all job specifications and standard drawings in relation to the preparation of P&I Diagrams; – logic diagram of the main equipment; – hydraulic of system; – size of all piping, valves and instrumentation components; – vendor’s information.11.2.5.3 Absolutely, required revisions after freezing of the P&I Diagram shall be made only byconducting of design activities using the relevant field sketches and executing the requiredmodifications approved by the Company. This is applicable to revisions called for at the designdepartment. The frozen P&I Diagram shall not be revised.11.2.6 Step 6, P&I diagram as-built11.2.6.1 The P&I Diagram as-built shall be prepared upon completion of the project for filing andsubmission to the Company. Since the P&I Diagram is intended for use in conducting operation 35 Oct.1996 IPS-E-PR-230control, maintenance or revamping, therefore, the prepared drawing shall be entirely in conformilywith the completed facilities.11.2.6.2 The P&I Diagram as-built shall be prepared in accordance with the results of line checkingand the final edition of the field sketches.11.2.6.3 The specified piping and instrument take-off and branch points shall be observed as strictlyas possible and shall be implemented on the P&I Diagram. Although bearing no relationship topiping layout, none of the flange, cap, drain pot, spectacle blind and other miscellaneous pipingdesigned for installation at the ends of the drain and vent required for operational purposes shall beomitted.11.3 Handling of Licensed ProcessWhere a licensed process or basic design should be prepared by a Licenser, the Contractor’s scopeof work concerning the completion of the P&I Diagram will be dependent on the type of contract withthe Licenser and Contractor.11.3.1 Licensing contract via the contractorIn this case, the Contractor and the Licenser jointly and severally shall give a process performanceguarantee to the Company.11.3.1.1 Case 1, licenser prepares P&I diagramThe P&I Diagram supplied by the Licenser shall be equivalent to the “P&I Diagram for piping layout”given in this Standard, and shall contain all design philosophies concerning process. The Contractorshall carry out mainly the following activities: – prior to the Licenser’s commencing the preparation of P&I Diagram, the Contractor shall establish the basic items for the preparation of the P&I Diagram as per Article 11.2.1 above and shall submit to the Company for approval. The Licenser should prepare the P&I Diagram based on the above mentioned items; – based on the P&I Diagram and operational guides prepared by the Licenser, review shall be made with regard to operability, safety, conformity to design of the Unit, etc.; – checking of the above-mentioned P&I Diagram against the basic items for preparing the P&IDs and relevant design data; – general review and checking of the drawings against the project requirements; – establishing the result of above-mentioned checking and reviews in a joint meeting with the Licenser. The Licenser should implement all necessary Contractor’s engineering comments and issue the revised P&I Diagram; – the following items of review shall be made by the Contractor on the revised P&I Diagram by the Licenser: – review in accordance with the results of detailed design hydraulic review; – review in accordance with the results of detailed design; – review on the basis of information concerning vendors.The Licenser’s approval should be obtained on any revision which should be made during theexecution of the abovementioned reviews by the Contractor, if it is expected to have an effect onthe process performance.11.3.1.2 Case 2, the contractor prepares P&I diagramP&I Diagram shall be prepared by the Contractor in accordance with Section 11 of this Standardand the following requirements: – required sufficient information for the preparation of the P&I Diagram shall be obtained from the Licenser; – the prepared P&I Diagram shall be subject to the Licenser’s review and approval.11.3.2 Direct contract between company and licenserIn this case, the Licenser shall give a process performance guarantee to the Company. TheContractor will be responsible for hydraulic of system and mechanical guarantee. 36 Oct.1996 IPS-E-PR-23011.3.2.1 Case 1, the Contractors verification is requiredUsually, the verification is limited to mechanical and hydraulic matters. However, extent of theContractor’s verification should be established in detail by the Company.For the purpose of conducting verification, the Contractor shall carry out mainly the following basicitems: – the basic items for preparation of the P&I Diagram as mentioned in Article 11.2.1 above shall be prepared and finalized with the Company; – the required activities shall be performed to complete all design philosophies in relation to the process, operation, safety and other features based on the operational guides and/or P&I Diagram prepared by the Licenser; – P&I Diagram prepared by the Licenser shall be checked against the above-mentioned finalized basic items and design philosophies; – checking of P&I Diagram should be performed against the hydraulic of system and detailed design data; – the results of the above-mentioned activities shall be finalized with the Company and shown on the P&I Diagram as required; – upon the completion of the above-mentioned items, the required steps for preparation of the P&I Diagram as outlined in Section 11.2 of this Standard shall be followed to complete detailed design activities.11.3.2.2 Case 2, verification is not required by contractorIn this case, the following activities shall be conducted by the Contractor: – review for the detailed hydraulic of system; – review for implementation of results of the detailed design; – review for information concerning vendors; – completion of the P&I Diagram preparation steps as stipulated in Section 11.2 of this Standard.11.4 Revisions of P&I Diagram11.4.1 GeneralGenerally P&I Diagram can be revised in the following conditions if complied with the requirementsas outlined in Section 11 of this Standard: – for correction of typographical and/or engineering errors; – as per the Company’s instructions; – implementation of pertinent information in the course of execution of the relevant engineering work on P&I Diagram; – addition of information concerning vendors.Upon agreement with the Company, revisions made after the issuance of the “P&I Diagram forpiping layout” may not be needed by directly revising the P&I Diagram but by issuing the NPIC”Notification of P&I Diagram Change”.11.4.2 RevisionsThe P&I Diagram shall be revised depending on necessity at each step in addition to the requirededition(s) which shall be issued per each step. Accordingly it does not follow that the step No. andrevision No. coincide with each other. At the time of revising the P&I Diagram the NPIC issued up tothat time and information concerning vendors obtained up thereto shall be incorporated on the P&IDiagram.11.4.3 NPICIssuance of Notification of P&I Diagram Change (NPIC) and manner of presentation shall be agreedin advance with the Company. NPIC shall be issued in a NPIC form finalized with the Company. Ingeneral issuance of NPIC should consider: – minimization of P&I Diagram revisions; 37 Oct.1996 IPS-E-PR-230 – not accumulation of a large amount of additions/changes which should be incorporated on the new revisions of P&I Diagram.11.5 Approval of P&I Diagram a) Company’s approval of the basic items for preparation of P&I Diagram (see Article 11.2.1 above) shall be obtained prior to commencement of the P&I Diagram preparation work. b) The Company’s approval at step 2 “P&I Diagram for engineering start” shall be obtained regardless of the cases that P&I Diagram is prepared by the Contractor or Licenser or both. c) Where the P&I Diagram prepared by Licenser has been reviewed or verified in step 3 “P&I Diagram for piping layout” by the Contractor, Company’s approval is needed before any official revision. d) In general, Company’s approval is required for any change, deletion and/or addition on the P&I Diagram through all steps of “preparation of P&I Diagram” as outlined in Article 11.2 above except step 6, “P&I Diagram as-built” mentioned in Article 11.2.6. above. 38 Oct.1996 IPS-E-PR-230 APPENDICES APPENDIX A ABBREVIATIONS/GRAPHICAL SYMBOLS/IDENTIFICATIONSCONTENTS: PAGE No.A.1 Abbreviations ……………………………………………………………………………………………………………. 40 A.1.1 General ………………………………………………………………………………………………………………. 40 A.1.2 Drain / Sewer Symbols………………………………………………………………………………………… 40 A.1.3 Letters at Individual Valves Designations ……………………………………………………………. 41 A.1.4 Piping Abbreviations…………………………………………………………………………………………… 42 A.1.5 Miscellaneous Designations ……………………………………………………………………………….. 42 A.1.6 Utility Services Abbreviations……………………………………………………………………………… 43A.2 Graphical Symbols ……………………………………………………………………………………………………. 44 A.2.1 Instrumentation ………………………………………………………………………………………………….. 44 A.2.1.1 Instrument line symbols……………………………………………………………………………….. 44 A.2.1.2 Interlock logic symbols ………………………………………………………………………………… 45 A.2.1.3 Programmable logic controller (PLC) function symbols ………………………………… 46 A.2.1.4 Computer (data storage) function symbols …………………………………………………… 46 A.2.1.5 Distributed control/shared display symbols ………………………………………………….. 47 A.2.1.6 General instrument or function symbols……………………………………………………….. 47 A.2.1.7 Function identification (Note 1) …………………………………………………………………….. 48 A.2.1.8 Control valve body and damper symbols………………………………………………………. 51 A.2.1.9 Symbols for self-actuated regulators, valves, and other devices …………………… 51 A.2.1.10 Symbols for actuator action in event of actuator power failure ……………………. 52 A.2.1.11 Primary element symbols …………………………………………………………………………… 52 A.2.2 Piping and Miscellaneous …………………………………………………………………………………… 52 A.2.2.1 General………………………………………………………………………………………………………… 52 A.2.2.2 Symbols for manually operated and miscellaneous valves and monitors ………. 63 A.2.3 Equipment ………………………………………………………………………………………………………….. 68 A.2.3.1 Tower, column, vessel and reactor ……………………………………………………………….. 68 A.2.3.2 Strorage tanks ……………………………………………………………………………………………… 72 A.2.3.3 Heaters, exchangers, air coolers and water coolers………………………………………. 74 A.2.3.4 Machinery ……………………………………………………………………………………………………. 80 A.2.3.5 Miscellaneous mechanical equipment…………………………………………………………… 85 A.2.4 Concrete/Birck/Soil …………………………………………………………………………………………… 101 39 Oct.1996 IPS-E-PR-230 APPENDIX A ABBREVIATIONS/GRAPHICAL SYMBOLS/IDENTIFICATIONSA.1 AbbreviationsA.1.1 GeneralSee IPS-E-PR-308, “Numbering System” for: – instrumentation identifications; – equipment abbreviations (codes); – fluid abbreviations; – painting, insulation and heat tracing designations.See IPS-D-AR-010, “Abbreviations & Symbols for HVAC&R Drawings” and IPS-D-AR-011,”General Notes for HVAC & R System” for: – Abbreviations & Symbols for HVAC & Refrigeration Systems.See Appendix D of this Standard for: – Utilities Identifications Table (Typical).See Appendix E of this Standard for: – Nozzles Identifications on Vessels, Reactors and Towers.A.1.2 Drain / Sewer SymbolsAMN Amine DrainsAY Amine Drain FunnelCAU Caustic SewerCDB Concrete Drain BoxDH Closed Drain HeaderCSW Chemical SewerCY Chemical Drain PitDC Drain ConnectionDP Drain PitDWW Desalter Waste WaterNSW Non Oily Water SewerOPD Open DrainOSW Oily Water SewerSSW Sanitary Water SewerSWA Stripped Sour WaterTY Toxic Drain FunnelWSW Storm Water SewerY Drain Funnel (General) (to be continued) 40 Oct.1996 IPS-E-PR-230 APPENDIX A (continued)A.1.3 Letters at Individual Valves DesignationsA Monel Trim (grease sealed seat and packing)B Monel Valve (grease sealed seat and packing)BV Ball ValveCAO Close-Automatic-OpenCC Cable ControlCO Chain OperatedCHV Check ValveCSC Car Sealed ClosedCSO Car Sealed OpenD DrainFB Full BoreFC Fail Close (closes on minimum signal to valve actuator)FD Flex Disc ValveFL Fail LockedFLC Fail Locked Closed: Valve position does not change on loss of actuating medium supply (closes on minimum signal to valve actuator)FLO Fail Locked Open: Valve position does not change on loss of actuating medium supply (open on minimum signal to valve actuator)FO Fail Open (opens on minimum signal to valve actuator)FP Full PortGM Gear Operated and Motorized ValveGO Gear Operated ValveIAV Acoustical Insulated ValveIHV Hot Insulated ValveLC Locked CloseLO Locked OpenM Monel Trim Valve (general)MOV Motorized ValveMT Monel Trim (teflon insert with grease sealed packing)NC Normally ClosedNO Normally OpenNV Needle ValveOV Operating ValvePIVA Post Indicator ValvePSE Rupture Disk Assembly (Pressure Safety Equipment)PSV Pressure Safety Relief ValveP PluggedSR Split RangeSS Soft Seat ValveSSV Stainless Steel ValveST Stellite TrimT TrapTSO Tight Shut-off ValveV VentWV Warning ValveWP(J) Jacketed Plug ValveX Type 316 Stainless Steel Trim Valve (to be continued) 41 Oct.1996 IPS-E-PR-230 APPENDIX A (continued)XCV Steam Trap with Integral StrainerXV Shut-off Valvexx 18-8 Stainless Steel Trim ValveA.1.4 Piping AbbreviationsCM Chrome MolyCS Carbon SteelDN Diameter NominalFF Flat FaceFS Forged SteelHB Hammer BlindLJ Lap JointMI Mallable IronPB Pressure BlindPN Pressure NominalPTP Pipe Tap PluggedRF Raised FaceRS Removable SpoolRSP Ring SpacerRTJ Ring Type JointSF Socket Weld Line Blind with Flexitallic GasketsSB Spectacle BlindSPB Spade BlindSO Slip onSS Stainless SteelST(W) Steam Trap (Winterizing)ST(H) Steam Trap (Heat Conservation)SV Socket Weld Line Blind with Viton GasketsSW Socket WeldVB Vapor BlindWN Weld NeckA.1.5 Miscellaneous DesignationsAG Above GroundBL Battery LimitCOF Center of FloatDCS Distributed Control SystemF FurnishedRO Restriction OrificeF&P Furnished & PipedHCB HydrocarbonHCH Hydrocarbon with HydrogenHHLL High High Liquid LevelHIL High Interface Liquid LevelHLL High Liquid LevelLF Liquid FoamLG Level Gage (to be continued) 42 Oct.1996 IPS-E-PR-230 APPENDIX A (continued)LIL Low Interface Liquid LevelLLL Low Liquid LevelLLLL Low Low Liquid LevelLSHH Level Switch High HighLSLL Level Switch Low LowMW ManwayNIL Normal Interface Liquid LevelNLL Normal Liquid LevelP PressurePB Push BottomPFD Process Flow DiagramPG Pressure GagePI Pressure IndicatorP&ID Piping & Instrumentation DiagramPO Pump OutPT Pressure Test ConnectionRES ResidueRG Refrigerant GasRL Refrigerant LiquidRO Restriction OrificeRS Remote SetpointRTD Resistance Temperature DetectorRVP Reid Vapor PressureSC Sample ConnectionSCL Sample CoolerSG Sight GlassSF Solution FoamSP Set PointSP.GR. Relative Mass Density (Specific Gravity)STO Steam OutTI Temperature IndicatorT/T Tangent to TangentTW Thermo-WellUFD Utility Flow DiagramUG Under GroundVB Vortex BreakerA.1.6 Utility Services AbbreviationsBFW Boiler Feed WaterCLW Chlorinated WaterCOC Cold CondensateCW Cooling WaterCWR Cooling Water ReturnCWS Cooling Water SupplyDMW Demineralized WaterDSW Desalinarted WaterDWA Drinking WaterFLG Fuel GasFLR Flare Discharge (to be continued) 43 Oct.1996 IPS-E-PR-230 APPENDIX A (continued)FOR Fuel Oil ReturnFOS Fuel Oil SupplyFWA Fire WaterHBW High Pressure Boiler Feed WaterHPC High Pressure CondensateHPS High Pressure SteamISA Instrument AirLLPS Low Low Pressure SteamLPC Low Pressure CondensateLPS Low Pressure SteamMBW Medium Pressure Boiler Feed WaterMPC Medium Pressure CondensateMPS Medium Pressure SteamNG Natural GasNIT NitrogenPLA Plant AirPTW Potable WaterPWA Plant Water(service water)QHW Quench WaterRFO Refinery Fuel OilRFW Refrigerated waterRWA Raw WaterSWA Sour WaterTWA Treated WaterWAT WaterA.2 Graphical SymbolsA.2.1 InstrumentationA.2.1.1 Instrument line symbolsISA-S5.1 (latest revision) section 6.2 shall be used with the following amendments: – Electric Signal – Electric Binary Signal – Pneumatic Signal Line – Heat Traced Line – Steam Jacketed LineThe following abbreviations shall be used to denote the types of power supply. These designationsmay also be applied to purge fluid supplies:AS Air Supply – ISA Instrument Air – PLA Plant AirES Electric SupplyGS Gas Supply (to be continued) 44 Oct.1996 IPS-E-PR-230 APPENDIX A (continued)HS Hydraulic SupplyNS Nitrogen SupplySS Steam SupplyWS Water SupplyThe supply level may be added to the instrument supply line, e.g., ISA-600 “a 600 kPa instrumentair supply; ES-24 VDC ” a 24-volt direct current power supply”.A.2.1.2 Interlock logic symbols (to be continued) 45 Oct.1996 IPS-E-PR-230 APPENDIX A (continued)A.2.1.3 Programmable logic controller (PLC) function symbolsA.2.1.4 Computer (data storage) function symbols (to be continued) 46 Oct.1996 IPS-E-PR-230 APPENDIX A (continued)A.2.1.5 Distributed control/shared display symbolsA.2.1.6 General instrument or function symbols (to be continued) 47 Oct.1996 IPS-E-PR-230 APPENDIX A (continued)Note:1) For specific logic symbols, see ANSI/ISA standard S5.2.A.2.1.7 Function identification (Note 1)Refer to list below for identification (Note 2): (to be continued) 48 Oct.1996 IPS-E-PR-230APPENDIX A (continued) (to be continued) 49 Oct.1996 IPS-E-PR-230APPENDIX A (continued) (to be continued) 50 Oct.1996 IPS-E-PR-230 APPENDIX A (continued)Notes:1) The function designations associated with controllers, computing devices, converters andrelays may be used individually or in combination (also, see Table 1, Note 14 of ISA-S5.1).The use of a box avoids confusion by setting off the symbol from other markings on adiagram and permits the function to be used as a stand-alone block on conceptual designs.2) See ISA-S5.1, Table 3 for math equation, graphic representation and definition.A.2.1.8 Control valve body and damper symbolsReference to be made to article 6.4 of ISA-S5.1 with the following additions:A.2.1.9 Symbols for self-actuated regulators, valves, and other devicesSee article 6.6 of ISA-S5.1. (to be continued) 51 Oct.1996 IPS-E-PR-230 APPENDIX A (continued)A.2.1.10 Symbols for actuator action in event of actuator power failureSee article 6.7 of ISA-S5.1.A.2.1.11 Primary element symbolsSee article 6.8 of ISA S5.1A.2.2 Piping and MiscellaneousA.2.2.1 General SYMBOL DESCRIPTION Main process line (arrow of 30 indicates Direction of fluid flow ) Heat traced pipe line Underground pipeline Existing line Future line Vendor package Jackated or double containment pipeline Line crossing (connected) (to be continued) 52 Oct.1996 IPS-E-PR-230APPENDIX A (continued) Line crossing ( unconnected) Lines junction Dripe funnel Platform Removable spoolpice Minimum distance Indication of point of change: a)change in sloop b) change in piping claass c)change in responsibility (to be continued) 53 Oct.1996 IPS-E-PR-230 APPENDIX A (continued)SYMBOL DESCRIPTION Outlet to the atmosphere for steam / gas Flow / motion in diraction of arrow Arrow for inlet or outlet of essential substances Slope Level reference Limit , general Contractor/ vendor Battery limit Hood , general Distribution device for fluids , spray nozzle Siphon with dip length (to be continued) 54 Oct.1996 IPS-E-PR-230 APPENDIX A (continued)SYMBOL DESCRIPTION Open vent Syphon drain( seal leg) Liquid seal, oen Liquid seal ,closed Butsting disc Sight glass Level gage Level gage on standpipe Level gage magnetic float type Level gage bull eye type (to be continued) 55 Oct.1996 IPS-E-PR-230 APPENDIX A (continued)SYMBOL DESCRIPTION Butt welded joint Flanged joint Screwed joint (arrow : 90 ) Socket welded joint Socket and spigot joint Compression joint Swivel joint End cap ,but welded End flanged and bolted End cap ,fillet welded (socket) End cap ,screwed (arrow:90 ) End closure, quick release End socket and spigot End screwed and plugged Quick coupling (hose connection) Union Concentric reducer Eccentric reducer (flush bottom) Eccentric reducer (flush top) (to be continued) 56 Oct.1996 IPS-E-PR-230 APPENDIX A (continued)SYMBOL DESCRIPTION Ring spacer Spade blind Hammer blind Pressure blind in welded line Standard socket weld line blind union W/viton gaskets 6 mm thick blind to blank off equipment (vapor blind) standard socket weld line blind union W/flexitallic gaskets spectacle blind ( normally open) expansion bellow sleeve extension expansion loop steam trap with built-in strainer ( thermostatic or thermodynamic type) steam trap without built-in strainer ( thermostatic or thermodynamic type) steam trap with integral check valve (bucket type) (to be continued) 57 Oct.1996 IPS-E-PR-230 APPENDIX A (continued)SYMBOL DESCRIPTION Desuperheater Ejector Jet mixer Ring header Flame arrestor (general) Explosion-proof flame arrestor (explosion comes From the side of the rectangular) Detonation proof flame arrestor Fire resistant detonation proof flame arrestor with Outlet to the atmosphere Fire_ resistance flame arrestor Silencer Filter for compressor (to be continued) 58 Oct.1996 IPS-E-PR-230 APPENDIX A (continued)SYMBOL DESCRIPTION Bucket (basket )type strainer Temporary strainer ( cone type) T-type strainer Y- type strainer ( with valved drain) Duplex strainer Pulsation dampener Flexible hose with quick coupling Filter (general) Cartridge type filter Propeller mixer In line mixer (static) Turbine mixer Nozzle ( blinded off) (to be continued) 59 Oct.1996 IPS-E-PR-230 APPENDIX A (continued)SYMBOL DESCRIPTION Loading arm (basic symbol) Pull bo % fire alarm ( alarm button) Hydrocarbon detector Halon protected area Portable extinguisher Wheeled extinguisher Foam sylinder (s) Foam chamber Insulation on equipment Spray (to be continued) 60 Oct.1996 IPS-E-PR-230 APPENDIX A (continued)SYMBOL DESCRIPTION Manway Swing elbo Breather Emergency (safety) shower equipped with no freezing drain valve Eyewasher equiped with no freezing drain valve Vortexx breaker Exhaust head (to be continued) 61 Oct.1996 IPS-E-PR-230 APPENDIX A (continued)SYMBOL DESCRIPTION Sample connection (non toxic gas ), see Appendix H for details (type 1) Sample connection (toxic gas or light liquid (PVC 34.5 Kpa) ,see appendix H for details , (type 2) sample connection [ hot oil & low pour point pour point A C ),where A is determinded in the execution of basic design phase for each project]. Sample connection [ hot oil & high pour point (pour point A C ),where A is determinded in the execution of basic design phase for each project]. (to be continued) 62 Oct.1996 IPS-E-PR-230 APPENDIX A (continued)A.2.2.2 Symbols for manually operated and miscellaneous valves and monitors SYMBOL DESCRIPTION Gate valve (basic symbol) Globe valve Check valve (general) Gate valve behind off Angle valve Ball valve Fourway valve Gate valve with body bleed Butterfly valve Hydraulic control Metering cock Needle valve Plug valve S=solenoid valve R= Manual reset when indicated Diaphragm valve (to be continued) 63 Oct.1996 IPS-E-PR-230 APPENDIX A (continued)SYMBOL DESCRIPTION Self contained regulator Treeway valve Spring loading valve Control valve with handweel Rotary valve Slide valve Knife valve Post indicator valve Piston valve Y- type below down valve Y-type stop check valve Y-type globe valve Float valve Motor operated valve (to be continued) 64 Oct.1996 IPS-E-PR-230 APPENDIX A (continued)SYMBOL DESCRIPTION Lift check valve Swing check valve Stop check Stop check , non -return valve Trip valve (low lube oil ppressure) Relief valve ( angle ,vaccum) Relief valve ( angle ,pressure) Flush bottom valve Pressure/ vacum valve Foot valve with strainer (to be continued) 65 Oct.1996 IPS-E-PR-230 APPENDIX A (continued)SYMBOL DESCRIPTION Foot valve Self draining valve Fire hydrant Fire hydrant with monitor Deluge valve Fire monitor Hydrant with water / foam monitor Yard hy drant Hose reel Hose house (to be continued) 66 Oct.1996 IPS-E-PR-230 APPENDIX A (continued)SYMBOL DESCRIPTION Elevated fire monitor Remote fire monitor Foam monitor Elevated foam monitor Remote foam monitor (to be continued) 67 Oct.1996 IPS-E-PR-230 APPENDIX A (continued)A.2.3 EquipmentA.2.3.1 Tower, column, vessel and reactor (to be continued) 68 Oct.1996 IPS-E-PR-230APPENDIX A (continued) (to be continued) 69 Oct.1996 IPS-E-PR-230APPENDIX.A (continued) (to be continued) 70 Oct.1996 IPS-E-PR-230APPENDIX A (continued) (to be continued) 71 Oct.1996 IPS-E-PR-230 APPENDIX A (continued)A.2.3.2 Strorage tanksNote:All tanks and spheres on each flow diagram are to be shown in Approximate relative size toeach other. (to be continued) 72 Oct.1996 IPS-E-PR-230APPENDIX A (continued) (to be continued) 73 Oct.1996 IPS-E-PR-230A.2.3.3 Heaters, exchangers, air coolers and water coolers (to be continued) 74 Oct.1996 IPS-E-PR-230APPENDIX A (continued) (to be continued) 75 Oct.1996 IPS-E-PR-230APPENDIX A (continued) (to be continued) 76 Oct.1996 IPS-E-PR-230APPENDIX A (continued) (to be continued) 77 Oct.1996 IPS-E-PR-230APPENDIX A (continued) (to be continued) 78 Oct.1996 IPS-E-PR-230 APPENDIX A (continued)A.2.3.3.3 Air coolersNote:1) Indicate percentage of fans with automatic-variable pitch.A.2.3.3.4 Film evaporator (to be continued) 79 Oct.1996 IPS-E-PR-230 APPENDIX A (continued)A.2.3.4 MachineryA.2.3.4.1 Pumps (to be continued) 80 Oct.1996 IPS-E-PR-230APPENDIX A (continued) (to be continued) 81 Oct.1996 IPS-E-PR-230APPENDIX A (continued) (to be continued) 82 Oct.1996 IPS-E-PR-230 APPENDIX A (continued)A.2.3.4.2 Compressors and fans (to be continued) 83 Oct.1996 IPS-E-PR-230APPENDIX A (continued) (to be continued) 84 Oct.1996 IPS-E-PR-230 APPENDIX A (continued)A.2.3.5 Miscellaneous mechanical equipmentA.2.3.5.1 Crusher (to be continued) 85 Oct.1996 IPS-E-PR-230 APPENDIX A (continued)A.2.3.5.2 Screen (to be continued) 86 Oct.1996 IPS-E-PR-230APPENDIX A (continued) (to be continued) 87 Oct.1996 IPS-E-PR-230 APPENDIX A (continued)A.2.3.5.4 Drier (to be continued) 88 Oct.1996 IPS-E-PR-230APPENDIX A (continued) (to be continued) 89 Oct.1996 IPS-E-PR-230APPENDIX A (continued) (to be continued) 90 Oct.1996 IPS-E-PR-230 APPENDIX A (continued)A.2.3.5.6 MillA.2.3.5.7 Agitator (mixer) (to be continued) 91 Oct.1996 IPS-E-PR-230APPENDIX A (continued) (to be continued) 92 Oct.1996 IPS-E-PR-230 APPENDIX A (continued)A.2.3.5.9 Separator (to be continued) 93 Oct.1996 IPS-E-PR-230 APPENDIX A (continued)A.2.3.5.10 Filter (to be continued) 94 Oct.1996 IPS-E-PR-230APPENDIX A (continued) (to be continued) 95 Oct.1996 IPS-E-PR-230 APPENDIX A (continued)A.2.3.5.11 Bulk loading Articulated loading arm (road/rail car loading) Telescopic loading lance (road/rail car loading) Marine loading arm Marine loading arm with emergency release system (to be continued) 96 Oct.1996 IPS-E-PR-230 APPENDIX A (continued)A.2.3.5.12 Other miscellaneous equipment (to be continued) 97 Oct.1996 IPS-E-PR-230APPENDIX A (continued) (to be continued) 98 Oct.1996 IPS-E-PR-230APPENDIX A (continued) (to be continued) 99 Oct.1996 IPS-E-PR-230APPENDIX A (continued) (to be continued) 100 Oct.1996 IPS-E-PR-230 APPENDIX A (continued)A.2.4 Concrete/Birck/Soil SYMBOL DESCRIPTION Brickwork Concrete (reinforced) Refractory clay, Refractory bricks Soil 101 Oct.1996 IPS-E-PR-230 APPENDIX BP&IDs/UFDs TITLE BLOCK (TYPICAL) 102 Oct.1996 IPS-E-PR-230 APPENDIX C REFERENCE BLOCKS ON P&IDs1. Reference blocks at the bottom of the drawing (only to be used for process and instrument linesrouting over the subject Unit battery limit).2. Reference blocks at the side of drawing (only to be used for process and instrument lines insidethe same Unit).3. Reference arrows for instrument, control system and software linkage signals at the inside ofdrawing (for the signals terminating or originating at the side or bottom of drawing see items 1 and2 above). 103 Oct.1996 IPS-E-PR-230 APPENDIX DUTILITIES IDENTIFICATION TABLE (TYPICAL) 104 Oct.1996 IPS-E-PR-230 APPENDIX E NOZZLES IDENTIFICATIONS ON VESSELS, REACTORS AND TOWERSThe following symbols will be used for identification of the nozzles: NOZZLE IDENTIFICATION SYMBOL A,A2 Inlets B Outlet C Condensate D Drain or Draw-off E* F Feed G Level gage or gage glass H Handhole J Pumpout K* L Level instrument (also LT, LI) M Manhole N Reboiler connection P Pressure connection (also PT, PI) R Reflux S Steam or sample connection T Temperature connection (also TI, TE, TW) V Vapor or vent W Relief valve connection (Oversize unless actual size known)*Use E or K when non of the other symbols apply. Do not use I, O, Q, U, X, Y, or Z. 105 Oct.1996 IPS-E-PR-230 APPENDIX F PRESSURE RATINGS DESIGNATIONS-NOMINAL SIZE (IMPERIAL-METRIC) IMPERIAL-METRIC IMPERIAL METRIC PRESSURE PRESSURE PN CLASSES CLASSES DESIGNATION 150 20 25 2.5 300 50 125 6 400 68 250 10 600 100 800(1) 16 900 150 800(2) 1500 250 25 2500 420 4500 760Equivalent pressure ratings designations. Rating designations which have not exact equivalentsNotes: 1) As per ANSI B16.1 for cast iron valves. 2) As per API 602 for steel valves. 106 Oct.1996 IPS-E-PR-230 APPENDIX G PIPE COMPONENT-NOMINAL SIZEThe purpose of this Appendix is to present an equivalent identity for the piping components nominalsize in SI system and imperial unit system, in accordance with ISO 6708-1980 (E). TABLE G.1- PIPE COMPONENT-NOMINAL SIZE (METRIC- IMPERIAL) NOMINAL SIZE NOMINAL SIZE NOMINAL SIZE NOMINAL SIZE DN(1) NPS(2) DN NPS DN NPS DN NPS 6 ¼ 100 4 600 24 1100 44 15 ½ 125 5 650 26 1150 46 20 ¾ 150 6 700 28 1200 48 25 1 200 8 750 30 1300 52 1/4 32 1 250 10 800 32 1400 56 40 1/2 300 12 850 34 1500 60 1 50 350 14 900 36 1800 72 65 2 400 16 950 38 1/2 80 2 450 18 1000 40 90 3 500 20 1050 42 1/2 3 1) Diameter Nominal, mm. 2) Nominal pipe Size. Inch. 107 Oct.1996 IPS-E-PR-230 APPENDIX HTYPICAL SAMPLE CONNECTION DETAILS FOR GASES AND LIGHT LIQUIDS (RVP 34.5 KPa) 108 Oct.1996 IPS-E-PR-230 APPENDIX I BLOCK AND BYPASS VALVES FOR CONTROL VALVEI.1 Without Block and Bypass valvesBlock and bypass valve system may not be necessary where the process can be shut-down torepair the control valve without significant economic loss or where the process can not be feasiblyoperated through the bypass. However, the consequences of shutting down a process Unit toperform a simple task ( such as replacing control valve packing) should always be considered. Incases where the block and bypass valves are not used, the control valve should be equipped with ahandwheel or other operating devices.Block and bypass valves are not always necessary in the following cases: a) In instances where it is desirable to reduce the sources of leakage of hazardous fluids, such as hydrogen, phenol, or hydrofluoric acid; b) In clean service where the operating conditions are mild, and mission of valves will not jeopardize the safety or operability of the Unit; c) In temporary services such as start-up or shut-down, and where the other operation modes are possible while the repairing of control valve, such as blending system of oil; d) Pressure self regulating valves; e) Shut-off valvesI.2 With Block and Bypass ValvesThe following services should be provided with block and bypass valves: a) Services where omission of valves will jeopardize the safety or operability of the Unit; b) Services containing abrasive solids or corrosive fluids result in damage of trim of control valve, and require the repair; c) In lethal services; d) In product rundown and feed supplying services; e) In fuel supply system; f) In cooling medium supply service; g) Control valves less than DN 50 (2 inch) size. The block and bypass valves are required due to small diameter of trim, and may have a possibility of plugging of sludge or foreign matters; h) In services that are flashing or at high differential pressure.I.3 Additional Requirements for Control ValvesNotwithstanding the requirements outlined in article I.1 and I.2 above the following notes shouldalso be considered: a) Provide an upstream isolation valve for all control valves unless the upstream system is to be shutdown on control valve failure. b) Provide a downstream isolation valve whenever the downstream side of the control valve can not be isolated from other continuously operating pressure sources. c) Provide a drain valve upstream of all control valves. d) Provide a drain valve downstream of the control valve only when the process fluid is toxic or corrosive and for tight shut-off services.I.4 Sizes of Block and Bypass ValvesFor sizes of block and bypass valves, reference should be made to IPS-G-IN_160,”Control Valves”. 109 Oct.1996 IPS-E-PR-230 APPENDIX J PHILOSOPHY OF INSTRUMENTATION INSTALLATIONJ.1 Flow and quantitySufficient flow metering, temperature and pressure indications shall be installed in feed, rundown,and utility streams to provide information for the operation and the calculation of heat, pressure andmaterial balances for each individual Unit.J.2 Alarm and safeguarding systemIf failure of any piece of plant equipment or its associated instrumentation may give rise to hazardsfor personnel, to consequence with considerable economic loss, or to undue environmentalpollution, alarm and/or safeguarding instruments shall be installed. Where appropriate,safeguarding equipment shall be automatically bring the relevant plant or part of the plant to a safecondition when a desired measurement reaches an unacceptable value.J.4 Separate Instrument connectionsDepending on potential hazards, operational importance, instrument reliability, plugging ofconnections, etc, the need for separate connections from those for normal operation shall bedecided upon in the design stage and indicated on P&IDs.Separate connections are especially required for instrument of shut-down systems, such as: – High or Low pressure point which actuate shut-down system. – High or Low temperature connection which actuate shut-down system. – High High or Low Low Level connection which actuate shut-down system. 110
