SY/T 10033-2000 Recommended practices for analysis, design, installation and testing of safety systems for basic topside facilities on offshore production platforms
Some standard content:
ICS75.020
Registration No.: 6953-2000
People's Republic of China Offshore Oil and Gas Industry Standard SY/T 10033—2000
Replaces SY/T4808—92
idt API RP 14C: 1994
Offshore Production Platforms
Recommended Practice for Analysis, Design, Installation and Testing of Basic Surface Safety Systems for Offshore Production Platforms2000-04-10 Issued
State Administration of Petroleum and Chemical Industry
2000-10-01 Implementation
SY/T10033—2000
API Foreword
Policy Statement
Chapter 1 General Provisions
1.1 Introduction
1.2 Scope
1.3 Arrangement of technical content
1.4 Government regulations, rules and regulations
1.5 Industry regulations, standards and recommended practices: 1.6 Unit conversion
Chapter 2 Safety device symbols and signs
2.1 Introduction
2.2 Functional device signs
2.3 Symbols
2.4 Equipment signs
2.5 Sign examples
Chapter 3 Introduction to safety analysis and system design
3.1 Purpose and objects
3.2 Safety program block diagram
3.3 Safety system operation mode
3.4 Basic analysis and design assumptions
Chapter 4 Protection concepts and safety analysis
4.1 Introduction-
4.2 Protection concept
4.3 Safety analysis
4.4 Summary of analysis and design methods
Appendix A (Appendix to the standard)
Appendix B (Appendix to the standard)
Appendix C (Appendix to the standard)
Appendix D (Appendix to the standard)
Appendix E (Appendix to the standard)bzxz.net
Appendix F (Appendix to the standard)
Process equipment analysis
Analysis table
Support system| |tt||Test and Report Methods
Safety Analysis Flowchart and Safety Analysis Function Evaluation (SAFE) Example Hazardous Gas
SY/T10033—2000
In order to meet the needs of my country's development of offshore oil and gas resources, China National Offshore Oil Corporation has adopted the 1994 edition of API RP14C "API Recommended Practice
for Analysis Design, Installation and Testing of Basic Surface Safety Systems for Offshore Production Platfoms" of the American Petroleum Institute, and revised SY/T4808-92 "Recommended Practice for Basic Analysis, Design, Installation and Testing of Safety Systems for Offshore Production Platform Topside Facilities" which is equivalent to the 1986 edition of API RP14C, and released it as a new offshore oil and gas industry standard.
This revision makes its meaning more accurate and easier for users to understand. For example: the name of this standard is changed to "Recommended Practice for Analysis, Design, Installation and Testing of Safety Systems for Basic Top Facilities of Offshore Production Platforms"; the definitions of some special terms in the "Definitions" chapter of this standard are modified where the translation is not accurate.
Compared with the previous version, this standard has added the following new chapters: Chapter 1 1.6 Unit Conversion: Chapter 2 Table 2.1 adds "Hazardous Gas Concentration Detector\Safety Device Symbol: Appendix CC1.4 Adequate Ventilation System.CI6 Sewage Oil Tank: Appendix DD3.8 Hazardous Gas Detector (OSH); Appendix EE2 Natural Ventilation Burners on Pressurized Heat Treaters; Appendix F Hazardous Gases. Compared with the previous version, the following chapters of this standard have been changed significantly: Policy Statement; API Foreword; Definitions; Chapter 1 1.5 Industry Regulations, Standards and Recommended Practices; Chapter 4 4.2 Protection Concepts, 4.3 Safety Analysis Appendix A; Appendix C; Appendix D; Appendix E. Other parts have also been modified, adjusted, added or deleted. For details, see the text. . In accordance with the State Administration of Quality and Technical Supervision's regulations on the standard numbering for the offshore oil and gas industry, the revised number of the original SY/T4808-92 was changed to SY/T10033-2000. In order to facilitate users to consult the original text, the Chinese layout is basically the same as the original text and has not been changed, except for obvious deficiencies (such as the numbering of Appendix B) that have been modified according to the requirements of GB/T1.1. When the laws, regulations and provisions of the government of the country where the original standard is located or other competent authorities are involved in the design, construction and use of offshore oil and gas development projects, the corresponding laws, regulations and provisions promulgated by the government of the People's Republic of China or the government department in charge shall be followed. The original standard on wind, wave, temperature For data or quantitative calculation methods of environmental conditions such as temperature, earthquake, etc., any data or quantitative calculation methods that are in line with my country's actual conditions can be used in reference to drift ice. Otherwise, data and quantitative calculation methods that are in line with my country's actual environmental conditions should be used. Regarding the representation of measurement units, my country's legal measurement units are mainly used. That is, the legal measurement unit value is in front, and the corresponding value of the imperial unit is marked in brackets after it. In order not to change the formula in the original standard and maintain the shape characteristics of the curve, the imperial units used in the original formula and curve are not changed. This standard was issued on April 10, 2000 and will be implemented on October 1, 2000. From the date of its entry into force, this standard will also replace SY/T4808-92. Appendix C, Appendix D, Appendix E and Appendix F are all appendices of the standard. This standard is proposed and managed by China National Offshore Oil Corporation. The compilation unit of this standard is China National Offshore Oil Corporation Production Research Center. The main compiler of this standard is Xu Liying. The chief reviewer of this standard is Chen Rongqi.
SY/T10033—2000
Policy Statement
API's various publications only address issues of a general nature. When it comes to specific situations, local, state and federal laws and regulations should be consulted.
API does not assume the obligation of employers, manufacturers or suppliers to inform, strictly train and equip their employees and other personnel on the health and safety risks and preventive measures. Nor does it assume their responsibilities under local, state or federal laws. The content of any API publication cannot be interpreted by implication or other means as granting any right to manufacture, sell or use any patented method, device or product. Nothing in this publication can be interpreted as relieving anyone of liability for infringement of patent rights. Normally, API standards are reviewed at least every five years and revised, requalified, or withdrawn. Sometimes, this review period can be extended once, up to two years. As an active API standard, this publication will be valid for no more than five years from the date of publication, unless an extension of validity is authorized when it is reprinted. The status of this publication can be inquired from API Development and Production Department (telephone 214-953-1101). API (1220LST., NW,
Washinglon,DC20005 (Tel. 202-682-8375) API Publications and Materials Catalog is published annually and updated quarterly. The American Petroleum Institute (API) recommended practices are published to facilitate the wide dissemination of proven good engineering and operating practices. These recommended practices are not intended to obviate the need for proper judgment as to when and where these recommended practices should be applied. The development and publication of AFI recommended practices are not intended to prohibit anyone from adopting other practices. Any recommended practice is available for use by anyone who wishes to adopt it. API has made unremitting efforts to ensure the accuracy and reliability of the data contained therein. However, the Institute makes no representation, warranty or guarantee with respect to any recommended practice published and hereby expressly disclaims any liability or responsibility for loss or damage caused by the use of these recommended practices, for any violation of any federal, state or municipal regulations that may occur as a result of the use of any API recommended practice that may conflict with such regulations, or for any infringement of patents caused by the use of API recommended practices.
SY/T10033—2000
This specification is promoted as a recommended practice (RP) of the American Petroleum Institute (API). It is managed by the Development and Production Department of the API Offshore Safety and Pollution Prevention Equipment Standardization Committee (OSAPE): It is developed under the guidance of the American Petroleum Institute (AFI), the Offshore Operators Committee (OC) and the Western States Petroleum Association (WSPA): This specification provides a standardized method for the design, installation and testing of the safety system of the upper facilities of the offshore production platform, and is expected to be adopted by design engineers and operators. It uses recognized system analysis methods to determine the requirements of the safety system, and includes methods for providing information for the safety system and verifying whether the system complies with this recommended practice. The API Offshore Safety and Pollution Prevention Equipment Standardization Committee (OSAPE) involves the following Scope: AFI safety and pollution prevention equipment and system standards and recommended practices are applicable to offshore oil and gas production, and focus on manufacturing, equipment testing and system analysis methods that are compatible with these standards. APIOSAPE also developed and published the following standards: 1. API SPEC 14A: Specification for Subsurace Safety Valve Fquipnent. 2. ARIHP 14B: Recommended Practice for the Design, Installation, Repair and Operation of Well F Safety Valve Systems. 3. APLSPEC 14D: Specification for Wellhead Surface Safety Valves and Subsea Safety Valve Systems for (Offshore Servire). 4. AFIRP14E: Recommended Practice for Design and Installation of Offshore Production Platform Piping Systems e5. APIRP14F: Recommended Practice for Design and Installation of Offshore Production Platform Power Systems .6.APIRP14G: Recommended Practice for Fire Prevention and Firefighting on Open Type Offshore: Production Platforms.7.APIRP14Il: Recommended Practice for Installation, Maintenance and Repair of Surface Safety Valves and Underwater Safety Valves Ollshom,8.APIRP14J: Recommended Practice for Design and Hazards Analysis for Offshore Pruduction Facilities.This is the fifth edition of this specification, which replaces all previously issued versions. It includes those amendments to the fourth edition in September 1986 that were approved by letter voting.
Any request for permission to reprint or translate all or part of this specification should be addressed to the person in charge of the Development and Production Department. The address of the department is: 700 N. Pear St., Suite 1840 (IB382), Dallas, TX 752012845. This specification will take effect from the date printed on the cover, but it can also be adopted at the time of publication. Recommended Practice for Analysis, Design, Installation and Testing of Basic Surface Safety Systems for Offshore Production Flatforns SY/T 10033--2000 Replaces SY/T 4808-92 APIRP 14C: 1994 Abnormal Operating Condition: In process equipment, the state when the range of variation of operating parameters exceeds the normal operating limit of the equipment.
Atmospheric Service: The operating pressure (gauge pressure) range is 0.22 kPa (0.5ounce/in2) (vacuum) to 35kPa (5lh/in).
Automatic Fired Vessel: A fired vessel made by an automatic controller of the temperature or pressure in the fuel of the combustion chamber: Backflow: The flow of fluid in the process equipment in the opposite direction to the normal flow direction: Blowdown Valve: An automatically operated normally open valve used to release the pressure of process equipment when shut down. Classified Area: An electrical area classified as Class |, D red t, Class 1 or Class 2 according to AFIRP500. Containment and Discharge Method: Various methods used on offshore platforms to collect and discharge leaked liquid hydrocarbons to a safe location.
Detectable Abnormal Condition: An abnormal operating condition that can be automatically detected. Direct Ignition Source: An ignition source with a sufficiently high temperature and heat capacity to ignite a combustible mixture. Emergency Shutdown System (FSD) Sivstem: A system that causes the platform to shut down when the button on the power station is touched. Excess Temperature: A temperature in a process equipment that exceeds the rated operating temperature. Failure: A normal operating condition that prevents a device or equipment from completing its designed function. Fired Vessel: A vessel in which the temperature increase of the fluid in the vessel is heated by the flame therein. Fusible Loop: A pneumatic control circuit equipped with a temperature sensing element (fusible plug, synthetic tube, etc.) that can shut down the platform when triggered.
Flame Failure: The phenomenon that the flame is not enough to ignite the combustible vapor entering the combustion chamber in an instant. Flawline: A pipeline that transports the parallel flow from the wellhead to the first process equipment downstream. The English words "flowline" and "flowline" both refer to oil pipelines.
Flowline section: A section of the same oil pipeline with a different operating pressure from other parts. Gas blowby: In process equipment, the phenomenon of gas being discharged from the outlet of the liquid. Gas detection system: A control system that can detect the concentration of combustible gas and can perform alarm and shutdown functions when the preset concentration is reached.
High liquid level: The liquid level in Dingyi equipment that exceeds the maximum operating liquid level: Approved by the State Administration of Petroleum and Chemical Industry on April 10, 2000 and implemented on October 1, 2000
SY/T10033-2000
High pressure: In process equipment, the liquid level exceeds the maximum operating pressure but is less than the maximum allowable working pressure ( For pipelines, it refers to the pressure at the maximum allowable operating pressure).
High Temperature: The temperature in process equipment that exceeds the designed operating temperature. Indirect Heated Component: A container or heat exchanger that relies on the heat transfer of a fluid, such as steam, hot water, hot oil or other heat media, to increase the temperature of another fluid. Leak: The state in which liquid and/or gaseous hydrocarbons in process equipment are accidentally discharged into the atmosphere. Liquid Overlow: Liquid in process equipment flows out of the gas (vapor) outlet. Lower Explosive Limit (LEL): The lowest concentration (volume) at which a combustible gas mixed with air can be ignited under ambient conditions.
Low Flow: The flow rate in process equipment that is lower than the minimum operating flow rate. Low Liquid Level (Low Liquid).Level): The liquid level in the process equipment when it is lower than the minimum operating liquid level. Low Pressure: The pressure in the process equipment when it is lower than the minimum operating pressure. Low Temperature: The temperature in the process equipment when it is lower than the minimum operating temperature. Malfuction: A state that causes abnormal operation of a device or equipment but does not prevent it from performing its designed functions. Maximum Allowable Operating Pressure: The highest operating pressure allowed at any point in the pipeline system during normal flow or static state.
Maximum Allowable Working Pressure: The highest operating pressure allowed at any point in the equipment, except the pipeline system, during normal operation or static state. Normally Closed Valve: A valve that moves to the closed position when the power source disappears. Normally Open Valve: A valve that moves to the open position when the power source disappears. Overpressure: The pressure in a process facility that exceeds the maximum allowable working pressure (for pipelines, it means the maximum allowable operating pressure). Pipeline: A pipeline that transports fluids between platforms or between platforms and onshore facilities. Platform Safety System: A safety device and emergency support system that shuts down a platform. The system can be composed of several separate process shutdown systems and can be driven by manual control or by automatic devices that detect abnormal conditions. Platform Shutdown: The state when all process equipment of the platform production system and all auxiliary equipment of the system are shut down. Pneumatic System: The system that supplies pressure to operate the pneumatic actuator. Process Equipment: Production equipment with a single function in the process unit and its associated piping, such as separators, heaters, pumps or tanks. Process System Shutdown: By closing the corresponding shut-off valve (SDV), the designated process unit is isolated from the process system, that is, the fluid is prevented from entering the process unit or the fluid is introduced into other process units. A single or multiple process equipment with a specific process function, such as separation, heating, pumping, etc. Process Station: Execution Qualified Person: According to the promulgated regulations, such as standards or examinations that can examine the individual's completion of a specified task, to measure the expertise or skills acquired by the individual through training or experience or both, those with certain special expertise or skills are qualified personnel. Safety device (Process Device): an instrument or controller used in a safety system. Sensor (Sensor): a device that can detect the normal operating state and transmit a signal to perform a specific shut-off function. Shutdown Valve (SDV): a normally closed valve used to isolate the automatic operation of a process device. Shut-in Tubing Pressure (Srip): the pressure in the tubing when shutting in the well. Subsurface Safety Valve (SSSV): a device installed in an oil well below the wellhead. Its design function is to prevent the flow from losing control when driven.
Subsurface Controlled Subsurface Safety Valve (SSCSV)): a subsurface safety valve driven by the pressure characteristics of an oil (gas) well (SSSV):
Surface Controlled Subsurface Safety Valve (Surface Controlled Subsurface Safety Valve) yValve (SCsSV)): A subsurface safety valve (SSSV) controlled by hydraulic, electric, mechanical or other methods on the platform. 2
SY/T10033—2000
Surface Safety Valve (SSV)): A wellhead valve assembly that can automatically close when the power source disappears. Negative pressure (Underpressure): The pressure in the process equipment is less than the designed collapse pressure. Subsea Safety Valve (USV)): A valve assembly installed at the underwater wellhead position that can automatically close when the power source disappears.
Undesirable Event: Abnormal conditions or states that threaten safety in process equipment or process devices, such as overpressure, negative pressure, overflow, etc.
Vacuum: Pressure in process equipment that is less than atmospheric pressure. Vent: A section of pipe or pipe fitting (such as a flange) on a container that opens to the atmosphere. The vent may include a pressure and/or vacuum relief device.
1.1 Introduction
SY/T10033—2000
Section 1 General Provisions
Over the years, the petroleum industry has developed many documents that reflect the comprehensive knowledge and experience of various stages of oil and gas production operations. As a continuation of this effort, this recommended practice is to systematize proven practical experience and provide a basic top-level design for offshore production platforms. The safety system of the offshore platform is a recommended practice for the design, installation and testing of safety systems for the basic top facilities of offshore production platforms. The basic concepts of platform safety systems are discussed and the protection methods and system requirements are briefly described. a. This recommended practice describes how to use a system analysis method to determine the safety requirements for protecting various process equipment: the actual analysis of major equipment should be such that the safety requirements determined are applicable as long as the equipment is used in the process system. The safety requirements of individual process equipment are summarized as the safety system of the entire platform. This analysis process includes methods for documenting and verifying the integrity of the system. This recommended practice proposes a unified method for identifying and marking safety devices and illustrates the analysis method with examples from process systems. h. In addition to the basic top facility safety system, this recommended practice also includes supporting systems such as pneumatic supply systems and liquid leak collection and discharge systems. Test procedures for common safety devices are also proposed, as well as recommended test data and allowable test tolerances. c. The pneumatic supply system is emphasized in this recommended practice because it is the most common system used on the platform. However, these principles and procedures also apply to hydraulic and electric systems and to systems with combinations of two or more control brakes. This document does not discuss instrument logic circuits because these circuits should be determined by the designer after completing the recommended safety functions. In this recommended practice, rotating machinery is classified as a type of process equipment because it is closely related to the platform safety system. When rotating machinery (such as pumps or compressors) is a set of equipment including several process equipment, each equipment can be analyzed according to this recommended practice. 1.3 Arrangement of technical content
The content of this recommended practice is arranged as follows:
Chapter 2, recommended standard symbols and abbreviations and names for safety devices and process equipment markings. Chapter 3 Basic objectives, functional requirements and basic premises for platform safety system analysis and design. Chapter 4 discusses in detail the recommended safety analysis techniques and protection concepts and the steps for analyzing and establishing design principles that are the basis for the basic production and distribution safety system. Appendix A: Safety analysis of each equipment commonly used in production process systems, including additional criteria that must be considered when the equipment is used in a specific process environment: Appendix B Typical Safety Analysis Table (SAT), Comprehensive Safety Analysis Checklist (SAC) and Typical Safety Analysis Function Evaluation (SAFE) Form. Appendix C discusses the support systems with specific safety functions that are common to the entire platform. Appendix 1) Test procedures and reporting methods for accumulating safety system test data (these data can be used to analyze operations and report on the needs of the management unit). Appendix E An example of a Safety Analysis Function Evaluation (SAFE) form made using the steps proposed in this recommended practice, and Appendix F A discussion of hazardous gas detection procedures and detector arrangements on platforms containing process-hazardous hydrocarbons. 1.4 Government regulations, rules and regulations
Regulatory authorities have established some requirements for the design, installation and operation of offshore production distribution facilities. In addition to federal regulations, certain state and local regulations may also apply. The following federal documents are related to offshore oil and gas development and production and should be used when appropriate. a. Federal regulations and procedures (omitted)
h.(Deleted in this edition).
c. Notice to Lessees and Operators of All Oil, Gas, and Sulfur Mines on the Federal Outer Continental Shelf. 4
1.5 Industry Codes, Standards, and Recommended Practices
SY/T10033—2000
Various organizations have developed many standards, codes, specifications, and recommended practices that are useful references for the design and installation of safety systems for facilities on production platforms. Some of the more commonly referenced documents are listed below. These documents are not considered part of this recommended practice, except for specific sections of those documents that are referenced somewhere in this recommended practice. American National Standards Institute (ANSI)
(1) ANSIR31.3 Petroleum Refinery Piping (2) ANSI B3.4 Liquid Petroleum Transportation Piping Systems (3) ANSI B31.8 Gas Transmission and Distribution Piping Systems (4) ANSI Y32.11 Graphical Symbols for Process Flow Diagrams (5) ANSI/ASME SFPE-1 Quality Assurance and Certification of Safety Equipment Used in Offshore Cil and Cas Operations (6) American Petroleum Institute (API) (1) AFIRP 14B Recommended Practice for Design, Installation, Repair and Operation of Safety Valve Systems (2) API RP14E "Recommended Practice for Design and Installation of Offshore Production Platform Piping Systems". (3) API RP141 "Recommended Practice for Design and Installation of Electrical Systems for Offshore Production Platforms". (4) API RP14C "Recommended Practice for Fire Prevention and Control of Open I'pe Offshore I'rodhiction Platforms". (5) API RP[4H "Recommended Practice for Installation, Maintenance and Repair of Surface and Subsea Safety Valves for Offshore Use" of Surtace Safety Valves and Underwater Safety Valves Offshore. (6) APIRP 14J "Recommended Practice for Design and Hazard Analysis for Offshore Production Facilities" (Reenmumerulerd Practicr: Recommended Practice for Design and Hazard Analysis for Offshore Production Facilities) . (7) APIRP500 "Recommended Practice for Classification of Electrical Installations at Petroleum Facilities" (Rexcomiended Practice for Classification of Electrical Installations at Petroleum Facilities) (8) APiRP520 "Recommended Practice for the Design, Selection and Installation of Pressure Relief Devices in Refineries - Paris Ind Il." (9) AFI RIP21 "Guide for Pressure and Depressuring Systems" (Guide for Pressure and Depressuring Systems) Systems): (10) API RP550 "Refinery Instrumentation and Control Systems Installation Manual" (Maualon Installation of Refinery Instrumentation and Control Systems):
(11) APl Sper: 6A & Parallel Port and Christmas Tree Specifications" (Spex: ifin: alinn [ur Wellheard Fmuipment). (12) API Spec 6D "Specification for Pipeline Valves, Connectors and Swivels". (13) API Spx: 144 "Specification for Subsea Safety Valve Fqpuipment" (14) API Spec 14D "Specification for Subsea Safety Valves and Subsea Safety Valves for Offshure Servire". (15) API Std 2000 "Venting Atmospheric and Low Pressure Storage Tanks": (16) API Guide for Inspection of Refining Equipment, Chapter XV, Instrumentation and Control Equipment (17) API Guide fnr lms [Refinery Equipment Inspection Guide], Chapter XVI, Pressure Relief Devices. C. American Society of Mechanical Engineers (ASME) 5
SY/T10033—2000
(1) ASME Boiler and Pressure Vessel Code-Section VIII,\Pressure Vessels\, Divisions 1 and 2). d. American Instrument Society (ISA)
(1) ISA-RP7.1 "Pneumatic Control Circuit Pressure Test". (2) ISA-RP42.1 "Nomenclature for Instrument Tubing Fittings". 9 "Piping Guide for Control Centers". (3) ISA-RP60.9
(4) ANSVISA-55.1 "Instrumentation Symbols and Identification", (5) ISA-S20K "Specification Foms for Process Measurement and Control Instrument Primary Elements and Control Valves". (6) ANSI/ISA102-198X "Standard for Gas Detector Tube Units (Quick Type) for Toxic Gases and Vapors in Working Environments" (7) ANSI/ISAS12.15 Part I "Performance Requirements, Hydrogen Sulfide Gas Detectors" (8) ANSI/ISAS I2.15 Part II "Installation, Operation and Maintenance of Hydrogen Sulfide Gas Detectors" (Sulfides Detection Instruments)
(Installation, Operation, and
(9)ANSI/ISAS12.13PurI "Performance Requirements, Combustible Gas Detectors".
(10)ANSI/ISAS12.13Pant "Installation, Operation, and Maintenance of Combustible Gas Detection Instruments".intenanceof
e.National Association of Corrosion Engineers (NACE
(1)NACEStandMRO175 "Stand and Material Requin
1.6Unit Conversion
HentsSu
IressCrackingR
Lia ntMetallieMaterialsForOilFieldEquipment) In all cases, English units are preferred. English units are standard units in this specification. The conversion factors with English units are selected from APIStd2564
1 inch (in) = 25:4 mm (mm)
(precise value
1 pound/inch (psi) = 0.06894757 bar (bar) Note: 1 bar (bar) = 100 kilopascals (kPa) Strength or stress
1 pound/inch (pei) = 0.006894757 megapascals (M 1 foot pound (f-Ib) = 1.355818 joule () 1 foot pound (fb) = 1.355818 Newton-meter (Nm) Use the following formula to convert Fahrenheit (F) and Celsius (C) units: C = 5/9 (F-32)
1 pound (Th) = 0.4535924 kilogram (kg) 2.1 Introduction
When describing or involving safety
SY/T10033-2000
Chapter 2 Symbols and signs for safety devices
systems, in order to maintain uniformity, a standard method for marking, abbreviating and symbolizing each safety device is required. This method can be used to represent safety devices on flow charts and other drawings, and can identify individual safety devices for any purpose. The recommended abbreviations and symbols will be based on the American Instrument Society standard ISA-S5.1 as much as possible. Other applications related to this standard can be derived as needed. However, some abbreviations have been widely used in the oil field, and although they are not strictly in accordance with the ISA standard, it is reasonable to continue to use them. Examples of this type are SSV for safety valve, SDV for shut-off valve, and ESD for emergency shut-off. 2.2 Functional device identification
8. Each safety device should be identified by a series of letters that distinguish its function. The functional identification consists of: the first letter indicates the measured or raw variable, followed by one or more letters indicating the function of the device. Element, and used as a sensing element and self-adjusting device.
For example, the word "safety (S)" can be used for emergency protection. b. If two or more devices of the same type are installed on a single device, the devices should be numbered in sequence, and the number should be after the functional mark. If there is only one device, the number can be omitted. 2.3 Symbols
Circles are used to mark special symbols, such as pressure reducing valves. In this case, the connecting line between the circle and the instrument symbol should be drawn close to the instrument symbol but not touching it. In other cases, the circle represents the device itself. Table 2.1 shows the recommended symbols. 2.4 Equipment marking
a. The complete marking of the safety device includes the reference code of the equipment it protects and, if feasible, the equipment mark after the device functional mark or device number. Table 2.2 shows the marking method for equipment. b. The first letter is the equipment type and must be a letter in the equipment type code column.
The letter "z\ represents a device not listed in the table
c. The second or third letter can be used to further explain or modify the first. If there is no modifying letter, Φ is used instead. d. The last four characters identify the special equipment. These characters are user-assigned and must be unique to the equipment at a particular location. 2.5 Marking Examples
An example of the recommended marking method is shown in Figure 2.1. PSy
Pressure Safety
Device Number
ABJ1000
Changzhuang Container
Compressor
Safety Device Marking Examples
Special Tank
No Modifier Letters
Special CompressorNational Association of Corrosion Engineers (NACE
(1) NACE Standard MRO 175 "Stand and Material Requin
1.6 Unit Conversion
Hents Su
Iress Cracking R
Liant Metallie Materials For Oil Field Equipment" gives priority to the use of imperial units in all cases. Imperial units are the standard units in this specification. The conversion factor with imperial units is selected from API Std 2564
1 inch (in) = 25:4 Millimeter (mm)
(Exact value
1 pound/inch (psi) = 0.06894757 bar (bar) Note: 1 bar (bar) = 100 kilopascals (kPa) Strength or stress
1 pound/inch (pei) = 0.006894757 megapascals (MPa) 1 foot pound (f-Ib) = 1.355818 joule () 1 foot pound (fb) = 1.355818 Newton-meter (Nm) Use the following formula to convert Fahrenheit (F) and Celsius (C) units: C = 5/9 (F-32)
1 pound (Th) = 0.4535924 kilograms (kg) 2.1 Introduction
When describing or involving safety
SY/T10 033-2000
Chapter 2 Symbols and Markings for Safety Devices
When the standard is being developed, a standard method for marking, abbreviating, and symbolizing each safety device is needed to maintain uniformity. This method can be used to represent safety devices on flow charts and other drawings, and can identify individual safety devices for any purpose. The recommended abbreviations and symbols will be based on the American Instrument Society standard ISA-S5.1 as much as possible. Other applications related to this standard can be derived as needed. However, certain abbreviations have been widely used in the oil field, and although they are not strictly in accordance with the ISA standard, it is reasonable to continue to use them. Examples of this type are SSV for parallel safety valve, SDV for shut-off valve, and ESD for emergency shutdown. 2. 2 Functional device marking
8. Each safety device shall be marked with a series of letters that distinguish its function. The functional marking consists of: the first letter indicates the measured or raw variable, followed by one or more letters indicating the function of the device.
For example, the word "Safety (S)" may be used for emergency protection b. If two or more devices of the same type are installed on a single device, the devices shall be numbered in sequence, and the number shall follow the functional marking. If there is only one device, the number may be omitted 2.3 Symbols
Circles are used to mark special symbols, such as pressure reducing valves. In this case, the line connecting the circle and the instrument symbol should be drawn close to the instrument symbol but not touching it. In other cases, the circle represents the device itself. Table 2.1 shows the recommended symbols. 2.4 Equipment marking
a. The complete marking of a safety device includes the reference code of the device it protects and, if applicable, the equipment symbol after the device functional marking or device number. Table 2.2 shows the marking method for equipment. b. The first letter is the equipment type and must be the equipment with the letters in the equipment type code column.
The letter "z\" represents an equipment not listed in the table
c. The second or third letter can be used to further explain or modify the first. If there is no modifying letter, Φ is used instead. d. The last four characters identify the special equipment. These characters are specified by the user and must be unique to the equipment in a specific location. 2.5 Marking Examples
An example of the application of the recommended marking method is shown in Figure 2.1. PSy
Pressure safety
Device number
ABJ1000
Changzhuang container
Compressor
Safety device marking example
Special tank
No modifying letters
Special compressorNational Association of Corrosion Engineers (NACE
(1) NACE Standard MRO 175 "Stand and Material Requin
1.6 Unit Conversion
Hents Su
Iress Cracking R
Liant Metallie Materials For Oil Field Equipment" gives priority to the use of imperial units in all cases. Imperial units are the standard units in this specification. The conversion factor with imperial units is selected from API Std 2564
1 inch (in) = 25:4 Millimeter (mm)
(Exact value
1 pound/inch (psi) = 0.06894757 bar (bar) Note: 1 bar (bar) = 100 kilopascals (kPa) Strength or stress
1 pound/inch (pei) = 0.006894757 megapascals (MPa) 1 foot pound (f-Ib) = 1.355818 joule () 1 foot pound (fb) = 1.355818 Newton-meter (Nm) Use the following formula to convert Fahrenheit (F) and Celsius (C) units: C = 5/9 (F-32)
1 pound (Th) = 0.4535924 kilograms (kg) 2.1 Introduction
When describing or involving safety
SY/T10 033-2000
Chapter 2 Symbols and Markings for Safety Devices
When the standard is being developed, a standard method for marking, abbreviating, and symbolizing each safety device is needed to maintain uniformity. This method can be used to represent safety devices on flow charts and other drawings, and can identify individual safety devices for any purpose. The recommended abbreviations and symbols will be based on the American Instrument Society standard ISA-S5.1 as much as possible. Other applications related to this standard can be derived as needed. However, certain abbreviations have been widely used in the oil field, and although they are not strictly in accordance with the ISA standard, it is reasonable to continue to use them. Examples of this type are SSV for parallel safety valve, SDV for shut-off valve, and ESD for emergency shutdown. 2. 2 Functional device marking
8. Each safety device shall be marked with a series of letters that distinguish its function. The functional marking consists of: the first letter indicates the measured or raw variable, followed by one or more letters indicating the function of the device.
For example, the word "Safety (S)" may be used for emergency protection b. If two or more devices of the same type are installed on a single device, the devices shall be numbered in sequence, and the number shall follow the functional marking. If there is only one device, the number may be omitted 2.3 Symbols
Circles are used to mark special symbols, such as pressure reducing valves. In this case, the line connecting the circle and the instrument symbol should be drawn close to the instrument symbol but not touching it. In other cases, the circle represents the device itself. Table 2.1 shows the recommended symbols. 2.4 Equipment marking
a. The complete marking of a safety device includes the reference code of the device it protects and, if applicable, the equipment symbol after the device functional marking or device number. Table 2.2 shows the marking method for equipment. b. The first letter is the equipment type and must be the equipment with the letters in the equipment type code column.
The letter "z\" represents an equipment not listed in the table
c. The second or third letter can be used to further explain or modify the first. If there is no modifying letter, Φ is used instead. d. The last four characters identify the special equipment. These characters are specified by the user and must be unique to the equipment in a specific location. 2.5 Marking Examples
An example of the application of the recommended marking method is shown in Figure 2.1. PSy
Pressure safety
Device number
ABJ1000
Changzhuang container
Compressor
Safety device marking example
Special tank
No modifying letters
Special compressor
Tip: This standard content only shows part of the intercepted content of the complete standard. If you need the complete standard, please go to the top to download the complete standard document for free.