標準編號:	GB/T 20368-2012
中文名稱:	液化天然氣(LNG)生產、儲存和裝運
英文名稱:	Production,storage and handling of liquefied natural gas(LNG)
中標分類:	E24    天然氣
行業分類:	GB    國家標準
ICS分類:	75.060 75.060    天然氣 75.060
發布機構:	國家質量監督檢驗檢疫總局，國家標準化管理委員會
發布日期:	2012-12-31
實施日期:	2013-7-1
標準狀態:	superseded
被新標準替代:	GB/T 20368-2021 液化天然氣（LNG）生產、儲存和裝運
被替代日期:	2022-3-1
替代舊標準:	GB/T 20368-2006 液化天然氣(LNG)生產、儲存和裝運
翻譯語言:	英文
文件格式:	PDF
中文字符數:	84000 字
翻譯價格(元):	2500.0
交付時間:	付款后 1 個工作日

Production, Storage and Handling of Liquefied Natural Gas (LNG) 液化天然氣（LNG）生產、儲存和裝運 1 *Scope This Standard specifies the relevant requirements of fire protection and safety for siting, design, construction, security, operation and maintenance of LNG plant. This Standard is applicable to facilities for liquefy natural gas, store, vaporize, transfer, and handle liquefied natural gas (LNG), training of all personnel involved with LNG, and the design, location, construction, maintenance, and operation of all LNG facilities. This standard is not applicable to frozen ground containers, portable storage containers stored or used in buildings, and all LNG vehicular applications, including fueling of LNG vehicles. Note 1: An asterisk (*) following the number or letter designating a paragraph indicates that explanatory material on the paragraph can be found in Appendix A. Note 2: Unless otherwise specified, all pressure values specified in this Standard are gauge pressure. 2 Normative References The following document is essential for the application of this Standard. For dated references, only the edition cited applies. For undated references, the latest edition (including any amendments) is applicable to this document. ACI 301 Specifications for Structural Concrete, 2005 ACI 304R Guide for Measuring, Mixing, Transportation and Placing of Concrete, 2000 ACI 311.4R Guide for Concrete Inspection, 2000 ACI 318 Building Code Requirements for Reinforced Structural Concrete and Commentary, 2008 ACI 318R Building Code Requirements for Structural Concrete, 2005 ACI 350 Code Requirements for Environmental Engineering Concrete Structures, 2006 ACI 372R Design and Construction of Circular Wire-and Strand-Wrapped Prestressed Concrete Structures, 2003 ACI 373R Design and Construction of Circular Prestressed Concrete Structures with Circumferential Tendons, 1997 ACI 506.2 Specification for Shotcrete, 1995 API 6D Specification for Pipeline Valves, 2007 API 620 Design and Construction of Large, Welded, Low-Pressure Storage Tanks, 2008 API 2510 Design and Construction of Liquefied Petroleum Gas(LPG)Installations, 2001 ASCE 7 Minimum Design Loads for Buildings and Other Structures, 2005 ASME Boiler and Pressure Vessel Code, 2004 ASME B31.3 Process Piping, 2004 ASME B31.5 Refrigeration Piping, 2001 ASME B31.8 Gas Transmission and Distribution Piping Systems, 2007 ASTM A 82 Standard Specification for SteelWire, Plain, for Concrete Reinforcement, 2002 ASTM A 416 Standard Specification for Steel Strand, Uncoated Seven — Wire for Prestressed Concrete, 2006 ASTM A 421 Standard Specification for Uncoated Stressed—Relieved Steel Wire for Prestressed Concrete, 2005 ASTMA 496 Standard Specification for Steel Wire, Deformed, for Concrete Reinforcement, 2007 ASTM A 615 Standard Specification for Deformed and Plain Billet-Steel Bars for Concrete Reinforcement, 2008 ASTM A 722 Standard Specification for Uncoated High-Strength Steel Bar for Prestressing Concrete, 2007 ASTM A 821, Standard Specification for SteelWire, Hand Drawn for Prestressing Concrete Tanks, 2005 ASTM A 996, Standard Specification for Rail-Steel and Axle-Steel Deformed Bars for Concrete Reinforcement, 2006 ASTM A 1008 Standard Specification for Steel, Sheet, Cold-Rolled, Carbon, Structural, High-Strength Low-Alloy and High-Strength Low-Alloy with Improved Formability, 2007 ASTM C 33 Standard Specification for Concrete Aggregates, 2007 ASTM E 136 Standard Test Method for Behavior of Materials in a Vertical Tube Furnace at 750 ℃, 2004 CGA 341 Standard for Insulated Cargo Tank Specification for Cryogenic Liquids, 2007) CGA S-1.3 Pressure Relief Device Standards — Part 3 — Compressed Gas Storage Containers, 2005 CSA A23.1 Concrete Materials and Methods of Concrete Construction, 2004 CSAA23.3 Design of Concrete Structures, 2004 CSA A23.4 Precast Concrete — Materials and Construction/Qualification Code for Architectural and Structural Precast Concrete Products, 2004 IEEE/ASTM SI 10, Standard for Use of the International System of Units (SI): The Modern Metric System, 2002 NACE RP 0169 Control of External Corrosion of Underground or Submerged Metallic Piping Systems, 2007 NFPA 10 Standard for Portable Fire Extinguishers, 2007 edition NFPA 11 Standard for Low-, Medium-, and High-Expansion Foam, 2005 edition NFPA 12 Standard on Carbon Dioxide Extinguishing Systems, 2008 edition NFPA l2A Standard on Halon 1301 Fire Extinguishing Systems, 2009 edition NFPA l3 Standard for the Installation of Sprinkler Systems, 2007 edition NFPA 14 Standard for the Installation of Standpipe and Hose Systems, 2007 edition NFPA 15 Standard for Water Spray Fixed Systems for Fire Protection, 2007 edition NFPA 16 Standard for the Installation of Foam-Water Sprinkler and Foam-Water Spray Systems, 2007 edition NFPA 17 Standard for Dry Chemical Extinguishing Systems, 2009 edition NFPA 20 Standard for the Installation of Stationary Pumps for Fire Protection, 2007 edition NFPA 22 Standard for Water Tanks for Private Fire Protection, 2008 edition NFPA 24 Standard for the Installation of Private Fire Service Mains and Their Appurtenances, 2007 edition NFPA 30 Flammable and Combustible Liquids Code, 2008 edition NFPA 37 Standard for the Installation and Use of Stationary Combustion Engines and Gas Turbines, 2006 edition NFPA 54 National Fuel Gas Code, 2009 edition NFPA 58 Liquefied Petroleum Gas Code, 2008 edition NFPA 59 Utility LP-Gas Plant Code, 2008 edition NFPA 70? National Electrical Code?, 2008 edition NFPA 72? National Fire Alarm Code?, 2007 edition NFPA 101? Life Safety Code?, 2009 edition NFPA 255 Standard Method of Test of Surface Burning Characteristics of Building Materials, 2006 edition NFPA 385 Standard for Tank Vehicles for Flammable and Combustible Liquids, 2007 edition NFPA 600 Standard on Industrial Fire Brigades, 2005 edition NFPA l221, Standard for the Installation, Maintenance, and Use of Emergency Services Communications Systems, 2007 edition NFPA 1901 Standard for Automotive Fire Apparatus, 2009 edition NFPA 2001 Standard on Clean Agent Fire Extinguishing Systems, 2008 edition NFPA 5000? Building Construction and Safety Code?, 2009 edition 3 Terms and Definitions For the purpose of this document, the following terms and definitions apply. 3.1 *Approved Acceptable to the authority having jurisdiction. 3.2 *Authority having jurisdiction An organization, office, or individual responsible for enforcing the requirements of a code or standard, or for approving equipment, materials, an installation, or a procedure. 3.3 Bunkering The loading of a ship’s bunker or tank with fuel oil for use in connection with propulsion or auxiliary equipment. 3.4 Cargo tank vehicle, tank vehicle A tank truck or trailer designed to transport liquid cargo. 3.5 Components Apart, or a system of parts, that functions as a unit in an LNG plant and could include, but is not limited to, piping, processing equipment, containers, control devices, impounding systems, electrical systems, security devices, fire control equipment, and communication equipment. 3.6 Container A vessel for storing liquefied natural gas. 3.6.1 Single containment container A single wall container or a double wall tank where only the self-supporting primary or inner container is designed to contain LNG. 3.6.2 Double containment container A single containment container surrounded by and within 6 m of a containment wall (secondary container) that is open to the atmosphere and designed to contain LNG in the event of a spill from the primary or inner container. 3.6.3 Full containment container A container in which the inner (primary) container is self standing and is surrounded by a separate self-standing secondary container designed to contain LNG in the event of a spill from the inner container, and where the secondary container is enclosed by a steel or concrete roof designed such that excess vapor caused by a spill of LNG from the primary container will discharge through the relief valves. 3.6.4 Frozen ground container A container in which the maximum liquid level is below the normal surrounding grade, that is constructed essentially of natural materials, such as earth and rock, that is dependent on the freezing of water-saturated earth materials, and that has appropriate methods for maintaining its tightness or that is impervious by nature. 3.6.5 Membrane container A container consisting of a thin metal primary container together with thermal insulation and a concrete container jointly forming an integrated, composite structure that provides liquid containment, where hydrostatic loads and other loadings on the membrane are transferred via the load-bearing insulation onto the concrete container such that the vapors are contained by the tank roof. 3.6.6 Prestressed concrete container A concrete container where the concrete is placed into compression by tendons or by external wire wrapping. (Also called post-tension container.) 3.7 Controllable emergency An emergency where operator action can minimize harm to people or property. 3.8 Design pressure The pressure used in the design of equipment, a container, or a pressure vessel for the purpose of determining the minimum allowable thickness or physical characteristics of its parts. 3.9 Dike A structure used to establish an impounding area or containment. 3.10 Failsafe A design feature that provides for the maintenance of safe operating conditions in the event of a malfunction of control devices or an interruption of an energy source. 3.11 Fired equipment Any equipment in which the combustion of fuels takes place. 3.12 Flame spread index A number obtained according to NFPA 255. 3.13 Hazardous fluid A liquid or gas that is flammable, toxic, or corrosive. 3.14 Impounding area An area defined through the use of dikes or the site topography for the purpose of containing any accidental spill of LNG or flammable refrigerants. 3.15 Liquefied natural gas A fluid in the cryogenic liquid state that is composed predominantly of methane and that can contain minor quantities of ethane, propane, nitrogen, and other components normally found in natural gas. 3.16 LNG plant A facility whose components can be used to store, condition, liquefy, or vaporize natural gas. 3.17 Maximum allowable working pressure The maximum gauge pressure permissible at the top of completed equipment, a container, or a vessel in its operating position for a design temperature. 3.18 Model A mathematical characterization intended to predict a physical phenomenon. 3.19 Noncombustible material A material that, in the form in which it is used and under the conditions anticipated, will not ignite, burn, support combustion, or release flammable vapors when subjected to fire or heat. Materials that are reported as passing ASTME 136, shall be considered noncombustible materials. 3.20 Out-of-service The deactivation of a component for any purpose, including repairs or inspections. 3.21 Overfilling Filling to a level above the maximum design liquid level. 3.22 *Transfer area The portion of a LNG plant containing a piping system where LNG, flammable liquids, or flammable refrigerants are introduced into or removed from the plant or where piping connections are connected or disconnected routinely. 3.23 Transition joint A connector fabricated of two or more metals used to effectively join piping sections of two different materials that are not amenable to the usual welding or joining techniques. 3.24 Vaporizer A equipment for vaporizing liquid. 3.24.1 Ambient vaporizer A vaporizer that derives its heat from naturally occurring heat sources, such as the atmosphere, seawater, or geothermal waters. 3.24.2 Heated vaporizer A vaporizer that derives its heat from the combustion of fuel, electric power, or waste heat, such as from boilers or internal combustion engines. 3.24.2.1 Integral heated vaporizer A heated vaporizer in which the heat source is integral to the actual vaporizing exchanger (including submerged combustion vaporizers). 3.24.2.2 Remote heated vaporizer A heated vaporizer in which the primary heat source is separated from the actual vaporizing exchanger, and an intermediate fluid (e.g., water, steam, isopentane, glycol) is used as the heat transport medium. 3.24.3 Process vaporizer A vaporizer that derives its heat from another thermodynamic or chemical process to utilize the refrigeration of the LNG. 3.24.4 Water capacity The amount of water at 16℃ (60℉) required to fill a container. 4 General Requirements 4.1 Corrosion control overview 4.1.1 Components shall not be constructed, repaired, replaced, or significantly altered until a qualified person reviews the applicable design drawings and materials specifications from a corrosion control viewpoint and determines that the materials involved will not impair the safety or reliability of the component or any associated components. 4.1.2 The repair, replacement, or significant alteration of components shall be reviewed only if the action to be taken involves or is due to one of the following: a) A change in the original materials specified b) A failure caused by corrosion c) An inspection that reveals a significant deterioration of the component due to corrosion 4.2 Control center 4.2.1 Each LNG plant, other than those complying with Chapter 13, shall have a control center from which operations and warning devices are monitored as required by 4.4. 4.2.2 A control center shall have the following capabilities and characteristics: a) It shall be located apart from or be protected from other LNG facilities so that it is operational during a controllable emergency. b) Each remotely actuated control system and each automatic shutdown control system required by this standard shall be operable from the control center. c) Each control center shall have personnel in attendance while any of the components under its control are in operation, unless either the control is being performed from another control center that has personnel in attendance or the facility has an automatic emergency shut-down system. f) If more than one control center is located at an LNG plant, each control center shall have more than one means of communication with every other center. e) Each control center shall have a means of communicating a warning of hazardous conditions to other locations within the plant frequented by personnel. 4.3 Sources of power 4.3.1 Electrical control systems, means of communication, emergency lighting, and fire-fighting systems shall have at least two sources of power that function so that failure of one source does not affect the capability of the other source. 4.3.2 Where auxiliary generators are used as a second source of electrical power, the following shall apply: a) They shall be located apart from or be protected from components so that they are not unusable during a controllable emergency. b) The fuel supply shall be protected from hazards. 4.4 Records 4.4.1 Each plant shall have a record of materials of construction for components, buildings, foundations, and support systems used for containment of LNG and flammable fluids. 4.4.2 The records shall verify that the material properties meet the requirements of this standard. The records shall be maintained for the life of the components, buildings, foundations, and support systems. 5 Plant Siting and Layout 5.1 Plant site provisions 5.1.1 A written site evaluation addressing the following factors: a) It shall take into consideration of the provision in this standard on the minimal clear spacing between the LNG container, flammable cryogen container, flammable liquid container, structures, plant equipment and plant's property line. b) It shall take into consideration of the capacity of the plant resisting natural forces in the practical limitation. c) It shall take into consideration of other factors which may impact the security of the plant personnel and around public and concern with the specific positions. When these factors are assessed, the possibility of accidents and the safety precautions adopted in design or operation shall be considered to make integral assessment. 5.1.2 All-weather accessibility to the plant for personnel safety and fire protection shall be provided except where provisions for personnel safety and fire protection are provided on the site in accordance with Chapter 12. 5.1.3 Site preparation shall include provisions for retention of spilled LNG, flammable refrigerants, and flammable liquids within the limits of plant property and for surface water drainage. 5.1.4 *Soil and general investigations of the site shall be made to determine the design basis for the facility. 5.2 Site provisions for spill and leak control 5.2.1 General 5.2.1.1 Provisions shall be made to minimize the potential of accidental discharge of LNG at containers endangering adjoining property or important process equipment and structures or reaching waterways, in accordance with one of the following methods: a) An impounding area surrounding the containers that is formed by a natural barrier, dike, impounding wall, or combination thereof complying with 5.2 and 5.3. b) An impounding area formed by a natural barrier, dike, excavation, impounding wall, or combination thereof complying with 5.2 and 5.3, plus a natural or man-made drainage system surrounding the containers that complies with 5.2 and 5.3. c) Where the container is constructed below or partially below the surrounding grade, an impounding area formed by excavation complying with 5.2 and 5.3. 5.2.1.2 The following areas shall be graded, drained, or provided with impoundment in a manner that minimizes the possibility of accidental spills and leaks that could endanger important structures, equipment, or adjoining property or that could reach waterways: a) Process areas b) Vaporization areas c) Transfer areas for LNG, flammable refrigerants, and flammable liquids d) Areas immediately surrounding flammable refrigerant and flammable liquid storage tanks If impounding areas also are required in order to comply with 5.2.3, such areas shall be in accordance with 5.2 and 5.3. 5.2.1.3 The provisions of 5.1.3, 5.2.1.1, and 5.2.1.2 that apply to adjoining property or waterways shall be permitted to be waived or altered at the discretion of the authority having jurisdiction where the change does not constitute a distinct hazard to life or property or conflict with applicable federal, state, and local (national, provincial, and local) regulations. 5.2.1.4 Flammable liquid and flammable refrigerant storage tanks shall not be located within an LNG container impounding area. 5.2.2 Impounding area and drainage system design and capacity 5.2.2.1 The minimal capacity of LNG container impounding area V includes the dischargeable capacity of the drainage area, and leaves space for snow retention, other container and equipment. It shall be determined according to the following provisions: a) Impounding areas serving one LNG container: 1) V = 110 percent of the maximum liquid capacity of the container. 2) V = 100 percent where the impoundment is designed to withstand the dynamic surge in the event of catastrophic failure of the container. 3) V = 100 percent where the height of the impoundment is equal to or greater than the container maximum liquid level. b) Impounding areas serving multiple LNG containers: 1) V = 100 percent of the maximum liquid capacity of all containers in the impoundment area. 2) V = 110 percent of the maximum liquid capacity of the largest container in the impoundment area, where provisions are made to prevent leakage from any container due to exposure to a fire, low temperature, or both from causing subsequent leakage from any other container. 5.2.2.2 For the impounding area of gasification area, process area or LNG transfer area, the minimal capacity shall equal to maximum volume of the LNG, inflammable cryogen and inflammable liquid may discharged into the impounding area from any source of leaks with in 10 min or even short periods of time stated by the surveillance and parking approved by the authority having jurisdiction. 5.2.2.3 Close type LNG drain shall be prohibited. Exception: Where enclosed container down comers are used to rapidly conduct spilled LNG away from critical areas, they shall be sized for the anticipated liquid flow and vapor formation rates. 5.2.2.4 The fending groin, impounding wall and drainage system in the LNG and flammable cryogen container area shall be constructed of compacted earth, concrete, metal, or other materials. These structures shall be mounted integral to the container, installed against the container, or independent of the container. Dikes, impounding walls, drainage systems, and any penetrations thereof shall be designed to withstand the full hydrostatic head of impounded LNG or flammable refrigerant, the effect of rapid cooling to the temperature of the liquid to be confined, any anticipated fire exposure, and natural forces, such as earthquakes, wind, and rain. Where the outer shell of a double-wall tank complies with these requirements, the dike shall be either the outer shell or as specified in 5.2.1.1. Where the containment integrity of such an outer shell can be affected by an inner tank failure mode, an additional impounding area that otherwise satisfies the requirements of 5.2.1.1 shall be provided. 5.2.2.5 Double and full containment containers shall be designed and constructed such that in the case of a spill and secondary container fire, the secondary container wall will contain the LNG for the duration of the fire. a) In the case of a fire confined to the inner tank, the secondary container wall shall retain sufficient structural integrity to prevent collapse, which can cause damage to and leakage from the primary container. b) The tanks shall also be designed and constructed such that in the case of a fire in the primary or secondary container of an adjacent tank, the secondary container shall retain sufficient structural integrity to prevent collapse, which can cause damage to and leakage from the primary container. 5.2.2.6 Double and full containment containers shall have no pipe penetrations below the liquid level. 5.2.2.7 Dikes, impounding walls, and drainage channels for flammable liquid containment shall conform to NFPA 30. 5.2.2.8 Insulation systems used for impounding surfaces shall be, in the installed condition, noncombustible and suitable for the intended service, considering the anticipated thermal and mechanical stresses and loads. If flotation of the insulation can compromise its intended purpose, mitigating measures shall be provided. 5.2.2.9 The dike or impounding wall height and the distance from containers operating at 100 kPa (15 lbf/in2) or less shall be determined in accordance with Figure 1. Notes: x — the distance from the inner wall of the container to the closest face of the dike or impounding wall. y — the distance from the maximum liquid level in the container to the top of the dike or impounding wall. x shall equal or exceed the sum of y plus the equivalent head in LNG of the pressure in the vapor space above the liquid. Exception: When the height of the dike or impounding wall is equal to or greater than the maximum liquid level, x may have any value. Figure 1 Dike or Impoundment Wall Proximity to Containers 5.2.2.9 Drain measures of water and other water in the impounding area shall be established. The auto-control draining pump is allowed to use, but the automatic knock-off block shall avoid exposing to the LNG temperature. The liquid may flow out of the impounding area when the pipe, valve and pipe fittings go out of order, it shall be able to continue working under LNG temperature conditions. If the free drainage is adopted, measures shall be adopted to prevent LNG from out-flowing through the drainage system. 5.2.2.10 The heat(thermal)insulation system used on the impounding surface shall be incombustible after installation, and shall fit for its usage, while considering the expectant heat stress, mechanical stress and load. If floating problem appears, it shall adopt braking measure. 5.2.3 Impounding area siting 5.2.3.1 The provisions of 5.2.3 shall not apply to impounding areas that serve only transfer areas at the water’s edge of marine terminals. 5.2.3.2 It shall adopt measures according to the following requirements to minimize the hazard caused by fire spreading beyond property line: a) Measures shall be adopted to prevent fire calorific radiation when exceeding the following limits under the atmospheric conditions of Grade 0, temperature 21℃ (70 ) and relative humidity 50%; 1) On the property line, due to the spillage on fire, the design radiant heat flux is 5000 W/m2 [1600 Btu/(h·ft2)]; 2) Beyond the plant property line, the nearest location of outdoors meeting point of fifty persons, due to LNG burning in the impounding area (LNG capacity V is determined according to 5.2.2.1), the radiant heat flux is 5000 W/m2 [1600 Btu/(h·ft2)]; 3) Beyond the plant property line, for the closest point of the plant, school, hospital, lockup and prison or residential area building or structures according to NFPA 101 "Life Safety Code" when the plant location is determined, due to the LNG burning in the impounding area (the LNG capacity V is determined according to 5.2.2.1), the radiant heat flux generated is 9000 W/m2 [3000 Btu/(h·ft2)]; 4) On the property line, due to the LNG burning in the impounding area(the LNG capacity V is determined according to 5.2.2.1), the radiant heat flux generated is 30000 W/m2 [10000 Btu/(h·ft2)]. b) Heat distance shall be calculated according to the following methods: 1) The shape of the impounding area, wind speed, wind direction, humidity and air temperature are considered. 2) Test data suitable to assessing the risk scale and condition has been demonstrated. 3) Provides details of the physics, analysis, and execution process Models employed shall incorporate the following: — In calculating exclusion distances, the wind speed producing the maximum exclusion distances shall be used except for wind speeds that occur less than 5 percent of the time based on recorded data for the area. — In calculating exclusion distances, the ambient temperature and relative humidity that produce the maximum exclusion distances shall be used except for values that occur less than 5 percent of the time, based on recorded data for the area. 5.2.3.3 *The spacing of an LNG tank impoundment to the property line that can be built upon shall be such that, in the event of an LNG spill as specified in 5.2.3.4, an average concentration of methane in air of 50 percent of the lower flammability limit does not extend beyond the property line that can be built upon.

Foreword IV 1 *Scope 2 Normative References 3 Terms and Definitions 4 General Requirements 4.1 Corrosion control overview 4.2 Control center 4.3 Sources of power 4.4 Records 5 Plant Siting and Layout 5.1 Plant site provisions 5.2 Site provisions for spill and leak control 5.3 Buildings and structures 5.4 Designer and fabricator competence 5.5 *Soil protection for cryogenic equipment 5.6 Falling ice and snow 5.7 Concrete materials 5.8 Portable LNG facility 6 Process Equipment 6.1 Installation of process equipment 6.2 Pumps and compressors 6.3 Flammable refrigerant and flammable liquid storage 6.4 Process equipment 7 Stationary LNG Storage Containers 7.1 Inspection 7.2 Design considerations 7.3 Metal containers 7.4 Concrete containers 7.5 Marking of LNG containers 7.6 Testing of LNG containers 7.7 Container purging and cool down 7.8 Relief devices 8 Vaporization Facilities 8.1 Classification of vaporizers 8.2 Design and materials of construction 8.3 Vaporizer piping, intermediate fluid piping, and storage valves 8.4 Relief devices on vaporizers 8.5 Combustion air supply 8.6 Products of combustion 9 Piping Systems and Components 9.1 General 9.2 Materials of construction 9.3 Installation 9.4 Pipe supports 9.5 *Piping identification 9.6 Inspection and testing of piping 9.7 Purging of piping systems 9.8 Safety and relief valves 9.9 Corrosion control 9.10 Pipe-in-pipe systems 10 Instrumentation and Electrical Services 10.1 Liquid level gauging 10.2 Pressure gauging 10.3 Vacuum gauging 10.4 Temperature indicators 10.5 Emergency shutdown 10.6 Electrical equipment 10.7 Electrical grounding and bonding 11 Transfer of LNG and Refrigerants 11.1 *General requirements 11.2 Piping system 11.3 Pump and compressor control 11.4 Marine shipping and receiving 11.5 Tank vehicle and tank car loading and unloading facilities 11.6 Pipeline shipping and receiving 11.7 Hoses and arms 11.8 Communications and lighting 12 Fire Protection, Safety, and Security 12.1 Basic requirements 12.2 Emergency shutdown systems 12.3 Fire and leak detection 12.4 Fire protection water systems 12.5 Fire extinguishing and other fire control equipment 12.6 Maintenance of fire protection equipment 12.7 Personnel safety 12.8 Security 13 Requirements for Stationary Applications Using ASME Containers 13.1 General 13.2 Basic requirements 13.3 Containers 13.4 Container filling 13.5 Container foundations and supports 13.6 Container installation 13.7 Automatic product retention valves 13.8 LNG spill containment 13.9 Inspection 13.10 Shop testing of LNG containers 13.11 Shipment of LNG containers 13.12 Field testing of LNG containers 13.13 Welding on containers 13.14 Piping 13.15 Container instrumentation 13.16 Fire protection and safety 13.17 Gas detectors 13.18 Operations and maintenance 14 Operating, Maintenance, and Personnel Training 14.1 General requirements 14.2 Manual of operating procedures 14.3 Operating manual contents 14.4 Maintenance manual 14.5 Marine shipping and receiving 14.6 LNG product transfer 14.7 Loading or unloading operations of LNG and refrigerants 14.8 *Other operations 14.9 Site housekeeping 14.10 Control systems, inspection, and testing 14.11 Corrosion control 14.12 Records 14.13 Personnel training Appendix A (Informative) Explanatory Material Appendix B (Informative) Seismic Design of LNG Plants Appendix C (Informative) Security Appendix D (Informative) Training Appendix E (Informative) Performance-Based Alternative Standard for Plant Siting Bibliography