Canada z276-2011

Z276-11

Liquefied natural gas (LNG) Production, storage, and handling

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CSA Standards Update Service

Z276-11December 2011

Title: Liquefied natural gas (LNG) Production, storage, and handlingPagination: 99 pages (x preliminary and 89 text), each dated December 2011

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Z276-11Liquefied natural gas (LNG) Production,

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December 2011 iii

Contents

Canadian Standards Association Liquefied natural gas (LNG) Production, storage, and handling

Technical Committee on Liquefied Natural Gas viii

Preface x

0 Introduction 1

1 Scope 1

2 Reference publications 2

3 Definitions 7

4 General requirements 94.1 Future developments 94.2 Retroactivity 104.3 Adoptions 104.4 Control centre 104.5 Safety and loss management system 104.6 Records 11

5 Plant site provisions 115.1 General 115.2 Major site provisions for spill and leak control 125.2.1 General 125.2.2 Impounding area and drainage system design and capacity 125.2.3 Impounding area siting 145.2.4 Container spacing 155.2.5 Vaporizer spacing 165.2.6 Process equipment spacing 175.2.7 Loading and unloading facility spacing 185.3 Buildings and structures 185.3.1 Construction 185.3.2 Ventilation 185.3.3 Other buildings and enclosures 195.3.4 Portable equipment 195.3.5 Odorization 195.4 Designer and fabricator competence 195.5 Soil protection for cryogenic equipment 205.6 Falling ice and snow 205.7 Concrete materials 205.8 Underground LNG containers 21

6 Process equipment 216.1 General 216.1.7 Welding and brazing of process equipment 226.2 Flammable refrigerant and flammable liquid storage 226.3 Process equipment 226.3.1 Siting 226.3.2 Boilers and pressure vessels 226.3.3 Shell and tube heat exchangers 236.3.4 Internal combustion engines and gas turbines 23


Z276-11 Canadian Standards Association

iv December 2011

6.3.5 Boil-off and flash gas handling 236.3.6 Internal vacuum 236.3.7 Equipment depressurizing 236.3.8 Cold boxes 236.3.9 Salt-bath heaters 236.3.10 Air injection 236.3.11 Relief devices 246.3.12 Process equipment supports 24

7 Stationary LNG storage tank systems and pressurized containers 247.1 General 247.1.1 Storage tank systems 247.1.2 Pressurized containers 247.1.3 Inspection 247.1.4 Basic design considerations 257.1.5 Seismic design of land-based field-fabricated tank systems 267.1.6 Wind and snow loads, ice, and flooding 277.1.7 Tank system insulation 277.1.8 Filling volume 287.1.9 Foundations 287.2 Metal containers 297.2.1 Containers designed for operation at 103 kPa (15 psi) and less 297.2.2 Containers designed for operation at greater than 103 kPa (15 psi) 297.3 Concrete containers 317.3.1 Scope 317.3.2 Container structure 317.3.3 Materials subject to LNG temperature 317.3.4 Coating for concrete 317.3.5 Coating drainage 317.4 Marking of LNG containers 317.5 Testing of LNG containers 327.5.1 Leak testing 327.5.2 Reference standard 327.5.3 Tests 327.5.4 Vacuum leaks 327.5.5 Retesting 327.6 Relief devices 337.6.1 General 337.6.2 Installation 337.6.3 Relief device sizing 337.7 Quality assurance personnel qualifications 35

8 Vaporization facilities 358.1 Classification of vaporizers 358.2 Design and materials of construction 358.3 Vaporizer piping and intermediate fluid piping and storage 358.4 Relief devices on vaporizers 368.4.1 Relief-valve capacity 368.4.2 Relief-valve location 378.5 Combustion air supply 378.6 Products of combustion 37

9 Piping systems and components 379.1 General 37



December 2011 v

9.2 Construction materials 389.2.1 General 389.2.2 Piping 389.2.3 Fittings 389.2.4 Valves 399.3 Installation 399.3.1 Bolted connections 399.3.2 Piping joints 399.3.3 Valves 409.3.4 Welding 409.3.5 Pipe marking 419.4 Pipe supports 419.5 Piping identification 419.6 Inspection and testing of piping 419.6.1 Pressure tests 419.6.2 Records of test conditions 419.6.3 Welded pipe tests 429.6.4 Welding examination 429.6.5 Test records 429.6.6 Records and verifications 429.7 Purging of piping systems 439.8 Safety and relief valves 439.8.1 Pressure-relieving safety devices 439.8.2 Thermal expansion relief valves 439.9 Corrosion control 439.9.1 Underground and submerged piping 439.9.2 Austenitic stainless steels and aluminum alloys 439.10 Cryogenic pipe-in-pipe installations 439.10.1 General 439.10.2 Inner pipe 439.10.3 Outer pipe 449.10.4 Vacuum jacket function 449.10.5 Annular space 449.10.6 Operational requirements 449.10.7 Connections 459.10.8 Expansion and contraction joints 459.10.9 Corrosion protection 459.10.10 Pipe-in-pipe integrity 45

10 Instrumentation and electrical services 4510.1 Liquid-level gauging 4510.1.1 LNG containers 4510.1.2 Tanks for refrigerants or flammable process fluids 4610.2 Pressure gauge LNG containers 4610.3 Vacuum gauge 4610.4 Temperature indicators 4610.4.1 Field-erected containers 4610.4.2 Vaporizers 4610.4.3 Liquefaction systems 4610.4.4 Heated foundations of cryogenic containers and equipment 4610.5 Emergency shutdown 4710.6 Electrical equipment 4710.6.1 General 4710.6.2 Classified areas 47



vi December 2011

10.6.3 Seals 4710.6.4 Monitoring 4810.6.5 Venting 4810.7 Electrical grounding and bonding 4810.7.1 General 4810.7.2 Bonding 4810.7.3 Stray or impressed currents 4910.7.4 Lightning protection 49

11 Transfer of LNG and refrigerants 4911.1 General 4911.2 Piping system 4911.3 Pump and compressor control 4911.4 Marine shipping and receiving 5011.4.1 General 5011.4.2 Dock structures 5011.4.3 Protection of loading and unloading piping and components 5011.4.4 Isolation valving and bleed connections 5111.4.5 Isolation valve on shore 5111.4.6 Check valve 5111.4.7 Vapour return line 5111.4.8 Emergency shutdown (ESD) system 5111.5 Highway tank loading and unloading facilities 5211.6 Connection to pipeline systems 5211.7 Hoses and arms 52

12 Fire protection, safety, and security 5312.1 General 5312.1.1 Application 5312.1.2 Evaluation 5312.1.3 Potential hazards 5412.1.4 Detailed provisions 5412.1.5 Sources of electrical power 5412.2 Emergency shutdown systems 5412.3 Fire and leak control 5512.4 Fire-protection water systems 5512.5 Fire-extinguishing and other fire-control equipment 5612.6 Maintenance of fire-protection equipment 5612.7 Security 5612.8 Personnel safety 5712.9 Other operations 5812.10 Communications and lighting 5812.10.1 Communications 5812.10.2 Lighting 58

13 Operation, maintenance, and personnel training 5913.1 General 5913.2 Basic requirements 5913.3 Documentation of operating procedures 5913.3.1 Manual of operating procedures 5913.3.2 Manual contents 5913.3.3 Emergency procedures 6013.3.4 Ignition source control 6113.3.5 Operation monitoring 61



December 2011 vii

13.3.6 Cool-down procedure 6213.3.7 Purging 6213.3.8 Transportation of LNG 6213.3.9 LNG transfer 6313.3.10 Marine shipping and receiving 6313.3.11 Tank vehicle and tank car loading and unloading facilities 6613.3.12 Portable equipment 6713.4 Maintenance 6813.4.1 General 6813.4.2 Maintenance manual 6913.4.3 Site housekeeping 6913.4.4 Purging 6913.4.5 Repairs 7013.4.6 Control systems, inspection, and testing 7013.4.7 Corrosion control 7113.4.8 Records 7213.5 Training 7213.6 Operational security requirements 73

AnnexesA (informative) Seismic design of LNG plants 84B (informative) Guidelines for small LNG facilities 86C (informative) Commentary on certain clauses in CSA Z276 88

Tables1 Radiant heat flux limits to property lines and occupancies 732 Design spills 743 Distances from containers 754 Distances from underground LNG containers 755 Environmental factors 766 Classified areas 77

Figures1 Proximity to tank system of dike or impounding wall 792 Classified areas 793 Classified areas for tank systems with dike height less than distance from outer container to dike

(H < x) 804 Classified areas for tank systems with dike height greater than distance from outer container to dike

(H > x) 805 Classified areas for tank system with liquid level below grade or below the top of the dike 816 Classified areas for full containment tank systems 817 Classified areas for marine terminal loading and unloading areas 828 Maximum filling volume for pressure containers 83



viii December 2011

Technical Committee on Liquefied Natural Gas

N.J. Trusler N.J. Trusler Pipeline Consulting Services, Port Coquitlam, British Columbia

Chair

F. Forsythe Canaport LNG,Saint John, New Brunswick

Vice-Chair

D.S. Alexander Union Gas Limited, Chatham, Ontario

G.M. Atkinson University of Western Ontario,London, Ontario

Associate

A. Azcarraga Canaport LNG, Saint John, New Brunswick

Associate

C. Bergevin Gaz Mtro, Montral, Qubec

R. Brousseau Rgie du btiment du Qubec, Montral, Qubec

P.A. Bryan TransCanada PipeLines Limited, Calgary, Alberta

Associate

R. Caesar British Columbia Ministry of Energy and Mines, Victoria, British Columbia

B. Eisentrout CB&I, Plainfield, Illinois, USA

L.H. Gales Transportation Safety Board of Canada,Gatineau, Qubec

Associate

J. Gillick FortisBC Energy, Nanaimo, British Columbia

D.G. Honegger D.G. Honegger Consulting, Arroyo Grande, California, USA

Associate

J.-P. Lacoursire University of Sherbrooke, Repentigny, Qubec

V. LeBlanc Westport Innovations Inc., Vancouver, British Columbia

J.P. Lewis Braemar Wavespec USA, Inc., Houston, Texas, USA

W. MacLean WorkSafeNB/Travail scuritaire NB, Saint John, New Brunswick



December 2011 ix

M.K. Quesnel TransCanada PipeLines Limited, Calgary, Alberta

J. Renaud Rgie du btiment du Qubec, Montral, Qubec

Associate

F. Shushtarian SNC Lavalin, Vancouver, British Columbia

M. Stone Canadian Welding Bureau,Milton, Ontario

G.W.N. Wassick FortisBC Energy, Surrey, British Columbia

Associate

R.S. Wyman Mustang Engineering LLC, Houston, Texas, USA

P. Fernandez Marchi Canadian Standards Association, Mississauga, Ontario

Project Manager



x December 2011

Preface

This is the ninth edition of CSA Z276, Liquefied natural gas (LNG) Production, storage, and handling. It supersedes the previous editions published in 2007, 2001, 1994, 1989, 1981, 1978, 1973, and 1972.

This Standard contains basic reference data relating to design, supplemented by specific requirements, where necessary, to establish a uniform interpretation of the design requirements.

This Standard was prepared by the Technical Committee on Liquefied Natural Gas, under the jurisdiction of the Strategic Steering Committee on Petroleum and Natural Gas Industry Systems and has been formally approved by the Technical Committee.

December 2011

Notes: (1) Use of the singular does not exclude the plural (and vice versa) when the sense allows.(2) Although the intended primary application of this Standard is stated in its Scope, it is important to note that it remains

the responsibility of the users of the Standard to judge its suitability for their particular purpose.(3) This publication was developed by consensus, which is defined by CSA Policy governing standardization Code of

good practice for standardization as substantial agreement. Consensus implies much more than a simple majority, but not necessarily unanimity. It is consistent with this definition that a member may be included in the Technical Committee list and yet not be in full agreement with all clauses of this publication.

(4) To submit a request for interpretation of CSA Standards, please send the following information to [email protected] and include Request for interpretation in the subject line:(a) define the problem, making reference to the specific clause, and, where appropriate, include an illustrative sketch;(b) provide an explanation of circumstances surrounding the actual field condition; and(c) where possible, phrase the request in such a way that a specific yes or no answer will address the issue.Committee interpretations are processed in accordance with the CSA Directives and guidelines governing

standardization and are published in CSAs periodical Info Update, which is available on the CSA website at standardsactivities.csa.ca.

(5) CSA Standards are subject to periodic review, and suggestions for their improvement will be referred to the appropriate committee. To submit a proposal for change to CSA Standards, please send the following information to [email protected] and include Proposal for change in the subject line:(a) Standard designation (number);(b) relevant clause, table, and/or figure number;(c) wording of the proposed change; and(d) rationale for the change.



December 2011 1

Z276-11Liquefied natural gas (LNG) Production, storage, and handling

0 IntroductionThis Standard establishes essential requirements and minimum standards for the design, installation, and safe operation of liquefied natural gas (LNG) facilities. It is not a design handbook, and competent engineering judgment is necessary for its proper use.

1 Scope

1.1This Standard applies to the(a) design;(b) location;(c) construction;(d) operation; and(e) maintenanceof facilities for the liquefaction of natural gas and facilities for the storage, vaporization, transfer, handling, and truck transport of LNG. It also contains requirements for the training of personnel.

1.2For facilities that load or unload LNG from a marine vessel, this Standard contains requirements for the interconnecting piping between the loading/unloading arm flange and the storage tank(s), and other piping and appurtenances on the pier or jetty itself.

1.3This Standard applies to all containers for the storage of LNG, including those with insulation systems applying a vacuum.

1.4This Standard does not apply to frozen ground containers.

1.5This Standard includes non-mandatory guidelines for small LNG facilities (see the definition of small facility in Clause 3 and see Annex B).

1.6This Standard does not apply to the following:(a) the transportation of refrigerants by any means;(b) the transportation of LNG by railcar or marine vessel;(c) the transportation of LNG or regasified LNG by pipeline beyond the facility boundary, except as

specified in Clause 1.2; and(d) facilities designed to allow the use of LNG as a fuel for highway vehicles, railroad locomotives, or

marine vessels.



2 December 2011

1.7All references to pressure throughout this Standard refer to gauge pressures unless otherwise specified.

1.8All pipe sizes refer to nominal pipe sizes (NPS).

1.9The values given in SI units are the units of record for the purposes of this Standard. The values given in parentheses are for information and comparison only.

1.10In CSA standards, shall is used to express a requirement, i.e., a provision that the user is obliged to satisfy in order to comply with the standard; should is used to express a recommendation or that which is advised but not required; and may is used to express an option or that which is permissible within the limits of the standard.

Notes accompanying clauses do not include requirements or alternative requirements; the purpose of a note accompanying a clause is to separate from the text explanatory or informative material.

Notes to tables and figures are considered part of the table or figure and may be written as requirements.

Annexes are designated normative (mandatory) or informative (nonmandatory) to define their application.

2 Reference publicationsThis Standard refers to the following publications, and where such reference is made, it shall be to the edition listed below, unless the user finds it more appropriate to use newer or amended editions of such publications.

CSA (Canadian Standards Association)A23.1-09/A23.2-09Concrete materials and methods of concrete construction/Test methods and standard practices for concrete

CAN/CSA-A23.3-04 (R2010)Design of concrete structures

B51-09Boiler, pressure vessel, and pressure piping code

B149.1-10Natural gas and propane installation code

B149.2-10Propane storage and handling code

C22.1-09Canadian Electrical Code, Part I

CAN/CSA-ISO 9001-08Quality management systems Requirements

S16-09Design of steel structures



December 2011 3

CAN/CSA-W117.2-06 (R2011)Safety in welding, cutting, and allied processes

W178.1-08Certification of welding inspection organizations

W178.2-08Certification of welding inspectors

Z245.15-09Steel valves

Z246.1-09Security management for petroleum and natural gas industry systems

Z662-07Oil and gas pipeline systems

ACI (American Concrete Institute)350-06Code Requirements for Environmental Engineering Concrete Structures

376-10Code Requirements for Design and Construction of Concrete Structures for the Containment of Refrigerated Liquefied Gases and Commentary

AGA (American Gas Association)Purging Principles and Practice, 2001

API (American Petroleum Institute)RP 2003-2008Protection Against Ignitions Arising Out of Static, Lightning, and Stray Currents

Spec 6D-2008Specification for Pipeline Valves

Std 620-2008Design and Construction of Large, Welded, Low-Pressure Storage Tanks

Std 625-2010Tank Systems for Refrigerated Liquefied Gas Storage

Std 2510-2001Design and Construction of Liquefied Petroleum Gas (LPG) Installations

ASME (The American Society of Mechanical Engineers)A13.1-2007Scheme for the Identification of Piping Systems

B31.3-2010Process Piping

B31.5-2006Refrigeration Piping and Heat Transfer Components



4 December 2011

B31.8-2010Gas Transmission and Distribution Piping Systems

Boiler and Pressure Vessel Code, 2010Section I Rules for Construction of Power BoilersSection IID Materials Part D PropertiesSection VIII Rules for Construction of Pressure Vessels, Divisions 1 and 2Section IX Welding and Brazing Qualifications

ASTM International (American Society for Testing and Materials)E 84-10bStandard Test Method for Surface Burning Characteristics of Building Materials

Canadian Geotechnical SocietyCanadian Foundation Engineering Manual, 2006

CGA (Compressed Gas Association)341-2007Specification for Insulated Cargo Tank for Nonflammable Cryogenic Liquids

CGSB (Canadian General Standards Board)CAN/CGSB-24.3-92Identification of Piping Systems

CAN/CGSB-48.9712-2006/ISO 9712:2005Non-destructive Testing Qualification and Certification of Personnel

EJMA (Expansion Joint Manufacturers Association)Standards of the Expansion Joint Manufacturers Association, Inc., 9th ed. (2008)

Government of CanadaCanada Labour Code, Part II, 1985

Government of the United States29 Code of Federal Regulations, Subtitle B, Chapter XVII, Part 1910.146

GTI (Gas Technology Institute)GRI-89/0176 (1990)LNGFIRE: A Thermal Radiation Model for LNG Fires

GRI-89/0242 (1990)LNG Vapor Dispersion Prediction with the DEGADIS Dense Gas Dispersion Model

NACE International (National Association of Corrosion Engineers)SP0169-2007Control of External Corrosion on Underground or Submerged Metallic Piping Systems

NFPA (National Fire Protection Association)10-2010Standard for Portable Fire Extinguishers

11-2010Standard for Low-, Medium-, and High-Expansion Foam



December 2011 5

11A-1999Standard for Medium- and High-Expansion Foam Systems

12-2011Standard on Carbon Dioxide Extinguishing Systems

12A-2009Standard on Halon 1301 Fire Extinguishing Systems

13-2010Standard for the Installation of Sprinkler Systems

14-2010Standard for the Installation of Standpipe and Hose Systems

15-2007Standard for Water Spray Fixed Systems for Fire Protection

16-2011Standard for the Installation of Foam-Water Sprinkler and Foam-Water Spray Systems

17-2009Standard for Dry Chemical Extinguishing Systems

20-2010Standard for the Installation of Stationary Pumps for Fire Protection

22-2008Standard for Water Tanks for Private Fire Protection

24-2010Standard for the Installation of Private Fire Service Mains and Their Appurtenances

25-2011Standard for the Inspection, Testing, and Maintenance of Water-Based Fire Protection Systems

30-2008Flammable and Combustible Liquids Code

37-2010Standard for the Installation and Use of Stationary Combustion Engines and Gas Turbines

52-2010Vehicular Gaseous Fuel Systems Code

54-2009National Fuel Gas Code

58-2011Liquefied Petroleum Gas Code

59-2008Utility LP-Gas Plant Code



6 December 2011

68-2007Standard on Explosion Protection by Deflagration Venting

69-2008Standard on Explosion Prevention Systems

70-2011National Electrical Code

72-2010National Fire Alarm and Signaling Code

77-2007Recommended Practice on Static Electricity

101-2009Life Safety Code

255-2006Standard Method of Test of Surface Burning Characteristics of Building Materials

600-2010Standard on Industrial Fire Brigades

750-2010Standard on Water Mist Fire Protection Systems

780-2011Standard for the Installation of Lightning Protection Systems

1221-2010Standard for the Installation, Maintenance, and Use of Emergency Services Communications Systems

1901-2009Standard for Automotive Fire Apparatus

1961-2007Standard on Fire Hose

1962-2008Standard for the Inspection, Care, and Use of Fire Hose, Couplings, and Nozzles and the Service Testing of Fire Hose

1963-2009Standard for Fire Hose Connections

2001-2008Standard on Clean Agent Fire Extinguishing Systems

NRCC (National Research Council Canada)National Building Code of Canada, 2010

Users Guide NBC 2005: structural commentaries



December 2011 7

SIGTTO (Society of International Gas Tanker and Terminal Operators Ltd.)Liquefied Gas Handling Principles on Ships and in Terminals, 2000

Transport CanadaTP 743-2001TERMPOL Review Process

ULC (Underwriters Laboratories of Canada)CAN/ULC-S102-10Method of Test for Surface Burning Characteristics of Building Materials and Assemblies

UL (Underwriters Laboratories Inc.)723 (2008)Standard for Test for Surface Burning Characteristics of Building Materials

Other publicationRaj, P.K. 2006. Spectrum of Fires in an LNG Facility: Assessments, Models and Consideration in Risk Evaluations. U.S. Department of Transportation Report.

3 DefinitionsThe following definitions shall apply in this Standard:

Bunkering the loading of a ships bunker or tank with fuel oil for use in connection with propulsion or auxiliary equipment.

Cargo tank vehicle (tank vehicle) a tank truck or trailer designed to transport liquid cargo.

Competent possessing the qualifications, training, and experience needed to perform specified duties.

Components a part, or a system of parts, that functions as a unit in an LNG plant, and includes piping, processing equipment, containers, control devices, impounding systems, electrical systems, security devices, fire control equipment, and communication equipment.

Container a vessel or tank system for storing liquefied natural gas.

Double containment tank system a single containment container tank system surrounded by, and within 6 m (20 ft) of, an open-to-the-atmosphere wall (secondary container) designed to contain LNG in the event of a spill from the primary or inner container.

Frozen ground container a container in which the maximum liquid level is below the normal surrounding grade and that is constructed essentially of natural materials such as earth and rock; is dependent on the freezing of water-saturated earth materials; and has appropriate methods for maintaining its tightness or is impervious by nature.

Full containment tank system a tank system 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 vapour caused by a spill of LNG from the primary container will discharge through the relief valves.

Single containment tank system a single-wall tank system or a double-wall tank system in which only the primary or inner container is designed to contain LNG.

Controllable emergency an emergency where operator action can minimize harm to people or property.



8 December 2011

Deriming (defrosting or de-icing) the removal from low-temperature process equipment by heating and evaporation, sublimation, or solutions, of accumulated constituents, such as water, carbon dioxide, etc., that form solids at cryogenic temperatures.

Design pressure the pressure used in the design of equipment, a container, or a vessel for the purpose of determining the minimum allowable thickness or physical characteristics of its parts. Where applicable, static head is included in the determination of the design pressure.

Dike a structure used to establish an impounding area.

Fail-safe 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.

Fired equipment equipment in which the combustion of fuels takes place, including fired boilers, fired heaters, internal combustion engines, certain integral heated vaporizers, the primary heat source for remote heated vaporizers, gas-fired oil foggers, fired regeneration heaters, and flared vent stacks.

Flame spread index the flame spread index of materials as determined in accordance with NFPA 255 or CAN/ULC-S102, as appropriate.

Hazardous fluid a liquid or gas that is flammable, toxic, or corrosive.

Highway tank the cargo tank component of a tank truck or tank trailer.

Impounding area an area, established by the use of dikes or by site topography, used to contain an accidental spill of LNG or flammable refrigerants.

Liquefied natural gas (LNG) a fluid in the liquid state that is composed predominantly of methane and that can contain minor quantities of ethane, propane, nitrogen, or other components normally found in natural gas.Notes: (1) At sufficiently low temperatures, natural gas liquefies. At atmospheric pressure, natural gas can be liquefied by

reducing its temperature to approximately 162 C (260F). (This temperature applies to methane.)(2) Upon release from the containment to the atmosphere, LNG will vaporize and release gas that, at ambient

temperature, will have about 600 times the volume of the liquid vaporized. Generally, at temperatures below approximately 112 C (170F), this gas is heavier than ambient air at 16 C (60F). However, as its temperature rises, it becomes lighter than air.

(3) For information on the use of LNG as a vehicle fuel, see NFPA 52.

LNG plant a plant whose components are used to store liquefied natural gas and that might also condition, liquefy, or vaporize natural gas.

Maximum allowable working pressure (MAWP) the maximum gauge pressure permitted at the top of completed equipment, a container, or a vessel in its operating position at the design temperature.

Model a mathematical characterization intended to predict a physical phenomenon.

Operating company the individual, partnership, corporation, public agency, or other entity that owns or operates an LNG plant.

Out of service the deactivation of a component for any purpose, including repair or inspection.

Process plant all systems needed to condition, liquefy, or vaporize natural gas in all areas of application as identified under the scope of this Standard.

Safety and loss management system a systematic, comprehensive, and proactive process for the management of safety and loss control associated with design, construction, operation, and maintenance activities.



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Small facility a shop-fabricated process plant that is tested as an assembled and functional plant prior to shipment. The maximum storage volume of a small facility is 265 m3 (70 000 US gal) of liquid.

Tank car (tank wagon) a type of railroad rolling stock designed to transport fluid cargo.

Tank system low-pressure [less than 103 kPa (15 psi)] equipment that is designed for the purpose of storing liquefied natural gas and consists of one or more containers, together with various accessories, appurtenances, and insulation.

Tank vehicle see Cargo tank vehicle.

Transfer area that portion of an LNG plant containing a piping system where LNG, flammable liquids, or flammable refrigerants are introduced into or removed from the facility, such as truck loading or ship unloading areas, or where piping connections are connected or disconnected routinely. Transfer areas do not include product sampling devices or permanent plant piping.

Transition joint a connector fabricated of two or more metals that is used to join piping sections of two different materials that are not amenable to usual welding or joining techniques.

Vaporizer

Ambient vaporizer a vaporizer that derives its heat from naturally occurring heat sources such as the atmosphere, seawater, or geothermal waters.

Heated vaporizer a vaporizer that derives its heat from the combustion of fuel, electric power, or waste heat, or from another process.

Integral heated vaporizer a heated vaporizer in which the heat source is integral to the actual vaporizing exchanger (including submerged combustion vaporizers).

Process vaporizer a heated vaporizer that derives its heat from another thermodynamic or chemical process in order to conserve or use the refrigeration from the LNG.

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, or glycol) is used as the heat transport medium.

Water capacity the amount of water at 16 C (60F) required to fill a container.

4 General requirements

4.1 Future developmentsNew concepts in the production, storage, and use of LNG are still being developed, and it is possible that advancements in engineering and improvements in equipment will result in LNG facility design, equipment fabrication methods, and operating practices that are deviations from those specifically called for in this Standard. Such deviations can, however, provide desirable safety and operation compatible with the intent of this Standard.

An engineering assessment shall be conducted for such deviations. These deviations may be accepted when the authority having jurisdiction has approved them.



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4.2 RetroactivityThe requirements of this Standard are applicable to the operations, maintenance, and upgrading of existing installations; however, unless otherwise specified, it is not intended that existing installations be required to conform retroactively to the requirements of this Standard with regard to design and construction.

Where existing plants, equipment, buildings, structures, and installations meet the applicable design, fabrication, or construction layout provisions of the edition of this Standard in effect at the time of approval or installation, they may remain in use, provided that they do not constitute a significant risk to life or adjoining property.Note: For purposes of the application of retroactivity, the time of approval for a new facility will depend on the approval process of the jurisdiction responsible for the facility and is generally determined through discussions between the facility owner and the authority having jurisdiction.

4.3 AdoptionsThis Standard has been prepared for use in Canada, the United States, and other countries; some clauses reference Canadian and U.S. standards or publications as alternatives. Where a choice exists, the CSA requirement shall be the Canadian standard or publication.

4.4 Control centre

4.4.1Each LNG plant, other than small facilities complying with Annex B, shall have a control centre in the plant facility from which operations and warning devices are monitored.

4.4.2The control centre 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 centre.(c) Each control centre shall have personnel in attendance while any of the components under its control

are in operation, unless the operation is being controlled by another control centre that has personnel in attendance or the facility has an automatic emergency shutdown system.

(d) If more than one control centre is located at an LNG plant, each control centre shall have more than one means of communication with every other centre.

(e) Each control centre shall have a means of communicating a warning of hazardous conditions to other locations within the plant that are frequented by personnel.

4.5 Safety and loss management system

4.5.1For each LNG facility, the operating company shall develop, implement, and maintain a documented safety and loss management system that provides for the protection of people, the environment, and property.

4.5.2The safety and loss management system shall include the following elements:(a) clearly articulated policy;(b) leadership commitment;(c) a suitable organizational structure with well-defined responsibilities and authorities;(d) a process for the management of resources, including the establishment of competency requirements

and an effective training program;



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(e) a communication plan that supports the effective implementation and operation of the safety and loss management system;

(f) a document and records management process for the effective operation of the safety and loss management system;

(g) operational controls, including the development of procedures for hazard identification and risk management, design and material selection, construction, and operations and maintenance;

(h) a change management process; and(i) a continual improvement process, including

(i) performance monitoring for the ongoing assessment of conformance with the requirements of the safety and loss management system, and mechanisms for taking corrective and preventive measures in the event of nonconformance; and

(ii) development of measurable objectives and targets, and periodic audits and reviews of the effectiveness of the safety and loss management system in achieving stated objectives and targets.

4.6 Records

4.6.1Each plant shall maintain records of design, material selection, and construction for components, buildings, foundations, and support systems used for containment of LNG and flammable fluids.

4.6.2The records specified in Clause 4.6.1 shall verify that the material properties meet the requirements of this Standard.

4.6.3The records specified in Clause 4.6.1 shall be maintained for the life of the components, buildings, foundations, and support systems.

5 Plant site provisions

5.1 General

5.1.1An evaluation plan shall address the suitability of the plant site being considered, taking into account the following factors:(a) provision for minimum clearances, as stated in this Standard, between LNG containers, flammable

refrigerant storage tanks, flammable liquid storage tanks, structures, and plant equipment, both with respect to plant property lines and each other;

(b) all-weather accessibility to the plant for personal safety and fire protection, except where provisions are made on site;

(c) the degree to which the plant can, within the limits of practicality, be protected against forces of nature, including severe weather patterns;

(d) adjacent activities; and(e) other factors applicable to the specific site that have a bearing on the safety of plant personnel and

the surrounding public. The review of such factors shall include an evaluation of potential incidents and of the safety measures incorporated into the design or operation of the facility.

5.1.2Site preparation shall include provisions for the retention of spilled LNG, flammable refrigerants, and flammable liquids within the limits of plant property, and provisions for surface water drainage.



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5.1.3Soil studies and general investigations of the site shall be conducted to determine the design basis for the facility.

5.2 Major site provisions for spill and leak control

5.2.1 General

5.2.1.1In order to minimize the potential for an accidental discharge of LNG containers that can endanger adjoining property or important process equipment and structures, or reach waterways, there shall be(a) an impounding area surrounding the container(s), formed by a natural barrier, dike, impounding

wall, or combination thereof, that complies with Clauses 5.2.2 and 5.2.3;(b) an impounding area, formed by a natural barrier, dike, excavation, impounding wall, or combination

thereof, that complies with Clauses 5.2.2 and 5.2.3, plus a natural or artificial drainage system surrounding the container(s) that complies with Clauses 5.2.2 and 5.2.3; or

(c) where the container is constructed below or partially below the surrounding grade, an impounding area formed by excavation that complies with Clauses 5.2.2 and 5.2.3.

5.2.1.2The following shall be graded, drained, or provided with an impounding area in a manner that minimizes the potential for accidental spills and leaks that can endanger important structures, equipment, or adjoining property, or that can reach waterways:(a) process areas;(b) vaporization areas;(c) transfer areas for LNG, flammable refrigerants, and flammable liquids; and(d) areas immediately surrounding flammable refrigerant and flammable liquid storage tanks.

If impounding areas are also required in order to comply with Clause 5.1.2, such areas shall be in accordance with Clauses 5.2.2 and 5.2.3.

5.2.1.3In certain installations, the provisions of Clauses 5.1.2, 5.2.1.1, and 5.2.1.2 that apply to adjoining property or waterways may be waived or altered where such a waiver or alteration does not constitute a distinct hazard to life or property.

5.2.1.4Flammable 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

5.2.2.1Impounding areas serving LNG containers shall have a minimum volumetric holding capacity, V, that includes any useful holding capacity of the drainage area and that makes an allowance for the displacement of snow accumulation, other containers, and equipment, in accordance with the following:(a) 110% of the LNG containers maximum capacity, for an impounding area serving a single container;(b) 110% of the largest LNG containers maximum capacity, for impounding areas serving more than

one container, with provision made to prevent low temperature or fire exposure resulting from leakage from any one container served from causing subsequent leakage from any other container served;



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(c) 100% of all containers maximum capacity or 110% of the largest LNG containers maximum capacity, whichever is greater, for impounding areas serving more than one container without provision made in accordance with Item (b); and

(d) 100% in lieu of 110% in Items (a), (b), and (c), if the impounding area is designed to account for a surge in the event of catastrophic failure.

5.2.2.2Impounding areas, if provided to serve only vaporization, process, or LNG transfer areas, shall have a minimum volumetric capacity equal to the greatest volume of LNG, flammable refrigerant, or flammable liquid that can be discharged from a design spill as defined in Table 2.

5.2.2.3Enclosed drainage channels for LNG shall be prohibited; however, container downcomers used to rapidly conduct spilled LNG away from critical areas may be enclosed, provided that they are sized for the anticipated liquid flow and vapour formation rates.

5.2.2.4Dikes, impounding walls, and drainage systems for LNG and flammable refrigerant containment shall meet the following requirements:(a) They shall be constructed of compacted earth, concrete, metal, or other materials.(b) Dikes and impounding walls may be independent of the container or they may be mounded integral

with, or constructed against, the container.(c) They, 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.

(d) Where the secondary container of a double containment or full containment tank system complies with the requirements of Clause 5.2.1.1, it shall be considered to be the impounding area for the purpose of determining the siting area distances in accordance with Clause 5.2.3. Where the containment integrity of such a secondary container can be affected by a primary container failure mode, an additional impounding area that otherwise satisfies the requirements of Clause 5.2.1.1 shall be provided.

5.2.2.5Double and full containment tank systems shall be designed and constructed such that(a) in the case of a spill and secondary container fire, the secondary container wall will contain the LNG

for the duration of the fire;(b) in the case of a fire confined to the inner container, the secondary container wall shall retain sufficient

structural integrity to prevent collapse, which can cause damage to and leakage from the primary container; and

(c) 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.

5.2.2.6Dikes, impounding walls, and drainage channels for flammable liquid containment shall conform to NFPA 30.

5.2.2.7The dike or impounding wall height and distance from containers operating at 103 kPa (15 psi) or less shall be determined in accordance with Figure 1.



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5.2.2.8Provisions shall be made to clear rain or other water from the impounding area. Automatically controlled sump pumps may be used, provided that they are equipped with an automatic cut-off device that prevents their operation when exposed to LNG temperatures. Piping, valves, and fittings whose failure can allow liquid to escape from the impounding area shall be capable of withstanding continuous exposure to LNG temperatures. If gravity drainage is used for water removal, provisions shall be made to prevent the escape of LNG by way of the drainage system.

The water removal system shall have the capacity to remove water at a minimum rate of 25% of the maximum predictable collection rate from a storm of a ten-year frequency and 1 h duration, except in cases where the design of the impounding area does not allow the entrance of rainfall.

5.2.2.9Insulation systems used for impounding surfaces shall be, in the installed condition, non-combustible and suitable for the intended service, taking into account the anticipated thermal and mechanical stresses and loads. Mitigating measures shall be provided if displacement of the insulation can compromise its intended purpose.

5.2.3 Impounding area siting

5.2.3.1 ExceptionClauses 5.2.3.2 to 5.2.3.7 shall not apply to impounding areas serving only transfer areas at the waters edge of marine terminals.

5.2.3.2 Radiant heat

5.2.3.2.1Provisions shall be made to prevent radiant heat flux on a vertical plane from a fire from exceeding the limits specified in Table 1. Exclusion distances shall be calculated in accordance with the following:(a) the wind speed producing the maximum exclusion distances shall be used, except for wind speeds

that occur less than 5% of the time based on recorded data for the area; and(b) the ambient temperature and relative humidity producing the maximum exclusion distances shall be

used, except for values that occur less than 5% of the time based on recorded data for the area.

5.2.3.2.2Radiant heat distances shall be calculated in accordance with one of the following:(a) the model described in GTI GRI-89/0176, or alternative models that take into account the same

physical factors as the GTI model and have been validated by experimental test data. Exclusion distances shall be calculated using(i) the wind speed producing the maximum exclusion distances, except for wind speeds that occur

less than 5% of the time based on recorded data for the area; and(ii) the ambient temperature and relative humidity producing the maximum exclusion distances,

except for values that occur less than 5% of the time based on recorded data for the area; or(b) models that

(i) take into account impounding area configuration, wind speed and direction, humidity, and atmospheric temperature; and

(ii) have been validated by experimental test data appropriate for the size and conditions of the hazard to be evaluated.



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5.2.3.3 DispersionThe distance from an LNG tank impounding area to the nearest property line that can be built upon shall be sufficient to accommodate vapour cloud dispersion from the design spill defined in Table 2, such that an average concentration of methane in air of 50% of the lower flammability limit (LFL) does not extend beyond the property line. Flammable mixture dispersion distances shall be determined in accordance with the following:(a) Distances shall be calculated in accordance with a vapour dispersion model that takes into account

physical factors influencing LNG vapour dispersion, including gravity spreading, heat transfer, humidity, wind speed, atmospheric stability, buoyancy, and surface roughness.

(b) The vapour dispersion model shall also be validated by experimental test data appropriate for the size and conditions of the hazard to be evaluated. The method used shall be based upon the actual liquid characteristics and the maximum vapour outflow rate from the vapour containment volume (the vapour generation rate plus the displacement due to liquid inflow).

(c) The effects of hazard mitigation designs and methods such as dikes, impounding surface insulation, or water curtains may be taken into account.

Note: A vapour dispersion model that meets the provisions of Items (a) and (b) is available as a public domain model and is described in GTI GRI-89/0242. This reference does not exclude other models.

5.2.3.4 Design spillThe design spill for impounding areas shall be determined as specified in Table 2.

5.2.3.5 Damage to marine carriersLNG container impounding areas shall be located so that the heat flux from a fire over the impounding area does not cause major structural damage to any LNG marine carrier that could prevent its movement.

5.2.3.6 Small containersContainers with an aggregate storage of 265 m3 (70 000 US gal) or less on one site may be installed in accordance with Table 3, provided that the containers are equipped as follows:(a) All connections shall be equipped with automatic fail-safe valves. These automatic valves shall be

designed to close under any of the following conditions:(i) fire detection;(ii) excess flow of LNG from the container, as measured by loss of line pressure or other means;(iii) gas detection; and(iv) manual operation from a local and remote location.

(b) Appurtenances shall be installed as close to the container as practicable to ensure that a break resulting from external strain occurs on the piping side of the appurtenance while maintaining intact the valve and piping on the container side of the appurtenance. The type, quantity, and location of the detection devices shall be in accordance with the requirements of Clause 10.

Relief valves and instrument connection valves shall be exempt from the requirements of Items (a) and (b). Connections used only for flow into the container may be equipped with two backflow check valves in lieu of the requirements of Items (a) and (b).

5.2.3.7 Navigable waterwaysThe distance from the nearest edge of impounded liquid to a property line that can be built upon, or to the near edge of a navigable waterway, shall not be less than 15 m (50 ft).

5.2.4 Container spacing

5.2.4.1 GeneralThe minimum separation distance between LNG containers or tanks containing flammable refrigerants and exposures shall be in accordance with Table 3, or for double and full containment tank systems, in accordance with Clause 5.2.4.2.



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5.2.4.2 Double and full containment tank systems

5.2.4.2.1The minimum separation distance between any type of LNG container of 265 m3 (70 000 US gal) water capacity or less, single containment tank system of greater than 265 m3 (70 000 US gal) water capacity, or tank containing flammable refrigerants and exposures shall be in accordance with Table 3 or, with the approval of the authority having jurisdiction, at a shorter distance from buildings or walls constructed of concrete or masonry, but at least 3 m (10 ft) from any building openings.

5.2.4.2.2Full and double containment tank systems of greater than 265 m3 (70 000 US gal) water capacity shall be separated from adjoining LNG tank systems such that a fire in one tank system does not cause loss of containment from adjacent tank systems. This shall be accomplished by ensuring that no part of the adjacent tank system roof, walls, or impoundment structure reaches a temperature at which the strength of the material of the tank system roof, walls, or impoundment structure is reduced to a level where the tank system roof, walls, or impoundment structure loses structural integrity. Engineering analyses shall be used to determine this temperature as follows:(a) analyses shall be performed for the following:

(i) a fire involving the complete loss of containment of a tank system to an impoundment area that complies with the requirements of Clause 5.2.2.1; and

(ii) a fire over the whole surface of the liquid contained in the tank, assuming that the roof is completely lost; and

(b) the analyses shall account for the following:(i) the duration of the fire, the radiant heat emission characteristics of the fire, and the physical

attributes of the fire under anticipated atmospheric conditions; atmospheric conditions producing the maximum separation distances shall be used, except for conditions that occur less than 5 % of the time based on recorded data for the area. An LNG fire model in accordance with Clause 5.2.3.2.1 shall be used;

(ii) active or passive systems to reduce thermal heat flux incident on the surface or to limit the surface temperature; and

(iii) the materials, design, and methods of construction of the target LNG tank being analyzed.

5.2.4.2.3A water spray or deluge system may be used to limit the radiant heat flux onto the structure.

5.2.4.2.4The separation distance shall not be less than half the diameter of the largest container.

5.2.4.3 Access to isolation valvesA clear space of at least 0.9 m (3 ft) shall be provided for access to all isolation valves serving multiple containers.

5.2.4.4 Containers in buildingsLNG containers with a capacity greater than 0.5 m3 (125 US gal) shall not be located in buildings.

5.2.5 Vaporizer spacingNote: See Clause 8.1 for vaporizer classifications.

5.2.5.1Unless the intermediate heat transfer fluid is non-flammable, vaporizers and their primary heat sources shall be located at least 15 m (50 ft) from any other source of ignition. In multiple-vaporizer installations, an adjacent vaporizer or primary heat source shall not be considered to be a source of ignition.



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Process heaters or other units of fired equipment shall not be considered to be sources of ignition with respect to vaporizer siting if they are interlocked so that they cannot be operated while a vaporizer is operating, or while the piping system serving the vaporizer has either cooled down or is being cooled down.

5.2.5.2Vaporizers shall be located at least 30 m (100 ft) from a property line that can be built upon. Remotely heated, ambient, and process vaporizers may be located within an impounding area.

5.2.5.3Integral heated vaporizers shall be located at least 30 m (100 ft) from a property line that can be built upon (see Clause 5.2.5.2) and at least 15 m (50 ft) from(a) any impounded LNG, flammable refrigerant, or flammable liquid (see Clause 5.2.4), or the paths of

travel of such fluids between any other potential source of accidental discharge and the impounding area;

(b) LNG, flammable liquid, flammable refrigerant, or flammable gas storage containers or tanks, unfired process equipment containing such fluids, or loading and unloading connections used in the transfer of such fluids; and

(c) control buildings, offices, shops, and other occupied or important plant structures.Vaporizers used in conjunction with LNG containers with a capacity of 265 m3 (70 000 US gal) or less

and located in accordance with Clause 5.2.5.2 shall be exempt from the requirements of this Clause.

5.2.5.4Heaters or heat sources of remotely heated vaporizers shall comply with Clause 5.2.5.3, except that if the intermediate heat transfer liquid is non-flammable, the property line clearance and Clause 5.2.5.3(c) shall not apply.

5.2.5.5Notwithstanding Clause 5.2.5.2, vaporizers used in conjunction with LNG containers having a capacity of 265 m3 (70 000 US gal) or less shall be located with respect to property lines in accordance with Table 3, assuming that the vaporizer is a container with a capacity equal to the largest container to which it is connected.

5.2.5.6A clearance of at least 1.5 m (5 ft) shall be maintained between vaporizers.

5.2.6 Process equipment spacing

5.2.6.1Process equipment containing LNG, refrigerants, flammable liquids, or flammable gases shall be located at least 15 m (50 ft) from sources of ignition, a property line that can be built upon, control rooms, offices, shops, and other occupied structures; however, control rooms may be located in a building housing flammable gas compressors, provided that the building construction complies with Clause 5.3.1.

5.2.6.2Fired equipment and other sources of ignition shall be located at least 15 m (50 ft) from any impounding area or container drainage system.



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5.2.7 Loading and unloading facility spacing

5.2.7.1A pier or dock used for pipeline transfer of LNG shall be located so that any marine vessel being loaded or unloaded is at least 30 m (100 ft) from any bridge crossing a navigable waterway. The loading or unloading manifold shall be at least 61 m (200 ft) from such a bridge.

5.2.7.2LNG and flammable refrigerant loading and unloading connections shall be at least 15 m (50 ft) from uncontrolled sources of ignition, process areas, storage containers, control buildings, offices, shops, and other occupied or important plant structures; however, this requirement shall not apply to structures or equipment directly associated with the transfer operation.

5.3 Buildings and structures

5.3.1 Construction

5.3.1.1Buildings or structural enclosures in which LNG, flammable refrigerants, and flammable gases are handled shall be of lightweight, non-combustible construction, with non-load-bearing walls.

5.3.1.2If rooms containing LNG and flammable fluids are located within or attached to buildings in which such fluids are not handled (e.g., control rooms or shops), the common walls shall(a) be limited to no more than two;(b) be designed to withstand a static pressure of at least 5 kPa (0.7 psi);(c) have no doors or other communicating openings; and(d) have a fire-resistance rating of at least 1 h.

5.3.2 Ventilation

5.3.2.1Buildings or structural enclosures in which LNG, flammable refrigerants, and flammable gases are handled shall be ventilated in accordance with Clauses 5.3.2.2 to 5.3.2.4 to minimize the potential for hazardous accumulations of flammable gases or vapours.

5.3.2.2Ventilation may be provided by one of the following:(a) a continuously operating mechanical ventilation system;(b) a combination gravity ventilation system and normally non-operating mechanical ventilation system

that is energized by combustible gas detectors in the event that combustible gas is detected;(c) a dual-rate mechanical ventilation system whose high rate is energized by gas detectors in the event

that flammable gas is detected; or(d) a gravity ventilation system composed of a combination of wall openings and roof ventilators. If there

are basements or depressed floor levels, a supplemental mechanical ventilation system shall be provided.

5.3.2.3The ventilation rate shall be at least 5 L/s of air per m2 (1 cfm of air per ft2) of floor area.



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5.3.2.4If vapours heavier than air might be present, a portion of the ventilation shall be from the lowest level exposed to such vapours.

5.3.3 Other buildings and enclosuresBuildings or structural enclosures not covered by Clauses 5.3.1 and 5.3.2 shall be(a) located, or other provisions shall be made, to minimize the potential for entry of flammable gases or

vapours (see Clause 12.3.1); and(b) designed in accordance with the National Building Code of Canada. Specifically, structural concrete

shall be designed in accordance with CAN/CSA-A23.3 and structural steel in accordance with CSA S16.

Note: Relevant provincial/territorial and municipal requirements should also be considered.

5.3.4 Portable equipmentLNG portable equipment may be used on a temporary basis for peak shaving applications, service maintenance during gas system repair/alteration, or other short-term applications, subject to the following requirements:(a) LNG transport vehicles complying with this Standard shall be used as the supply container.(b) Provisions shall be made to minimize the potential for accidental discharge of LNG that can endanger

adjoining property or important process equipment and structures, or reach surface water drainage. Portable or temporary containment means may be used.

(c) Vaporizer controls shall comply with Clauses 8.3.1, 8.3.2, and 8.4. Each heated vaporizer shall be provided with a means to shut off the fuel source remotely. The device shall also be operable at the installed location.

(d) Equipment and operations shall comply with Item (c) and with Clauses 11 to 13, as applicable. Clearance distance provisions shall not apply.

(e) The LNG facility spacing specified in Table 3 shall be maintained, except in cases where deviations are necessary to provide temporary service on a public right-of-way or on property where the clearances specified in Table 3 are not feasible. In such cases, the following additional requirements shall be met:(i) traffic barriers shall be erected on all sides of the facility that are subject to passing vehicular

traffic; and(ii) if the facility or the operation causes any restriction to the normal flow of vehicular traffic, in

addition to the monitoring personnel required in Item (h), flag persons shall be continuously on duty to direct such traffic.

(f) Reasonable provision shall be made to minimize the potential for accidental ignition in the event of a leak.

(g) Portable or wheeled fire extinguishers recommended by their manufacturer for gas fires shall be available at strategic locations. These extinguishers shall be provided and maintained in accordance with NFPA 10.

(h) The site shall be continuously attended, and provisions shall be made to restrict public access to the site whenever LNG is present.

5.3.5 OdorizationIf odorization is required at the emergency facility, the restrictions of Clause 5.2.4.1 shall not apply to the location of odorizing equipment containing 76 L (20 US gal) of flammable odorant or less within the retention system.

5.4 Designer and fabricator competence

5.4.1Designers, fabricators, and constructors of LNG facility equipment shall be competent in the design, fabrication, and construction of LNG containers, cryogenic equipment, piping systems, fire-protection equipment, and other components of the facility. Supervision shall be provided for the fabrication,



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construction, and acceptance tests of facility components to the extent necessary to ensure that the facilities are structurally sound and otherwise in compliance with this Standard.

5.4.2Prior to the design and construction of an LNG plant, the operating company that proposes to operate the plant shall establish the required level of quality assurance for each component. The quality assurance program shall conform to CAN/CSA-ISO 9001 or an equivalent.

5.4.3The selected quality assurance program should ensure that the design, fabrication, acceptance tests, and installation of components are in accordance with the provisions of this Standard.

5.4.4When a component is designed and fabricated to another recognized code or standard incorporating quality assurance requirements, the requirements of CAN/CSA-ISO 9001 shall not pre-empt the other code or standard.

5.4.5When the quality assurance program requires the appointment of a representative, the representatives responsibilities, authority, and reporting relationship shall be determined prior to construction or fabrication and shall be part of the agreement between the purchaser and supplier.

5.4.6The content of manuals detailing quality assurance requirements, when manuals are required by the program, shall be agreed upon by the purchaser and supplier.

5.5 Soil protection for cryogenic equipmentLNG containers (see Clause 7.1.9), cold boxes, piping and pipe supports, and other cryogenic apparatus shall be designed and constructed such that they will not be damaged by freezing or frost heaving in the soil, or means shall be provided to prevent damaging forces from developing.Note: Soil movement due to freezing of water is of two general types:(a) the freezing of in situ water causes volumetric expansion of moist soil; and(b) frost heave is caused by migration of water to a zone of freezing and a continual growth of ice lenses.

5.6 Falling ice and snowMeasures shall be taken to protect personnel and equipment from falling ice or snow that has accumulated on high structures.

5.7 Concrete materials

5.7.1Concrete used for the construction of LNG containers shall be in accordance with Clause 7.3.

5.7.2Concrete structures that are normally or periodically in contact with LNG shall be designed to withstand the design load, applicable environmental loadings, and anticipated temperature effects. Such structures shall include foundations for cryogenic equipment and comply with the following requirements:(a) their design shall be in accordance with the provisions of Clause 7.3.2; and(b) their materials and construction shall be in accordance with the provisions of Clause 7.3.3.

5.7.3Pipe supports shall comply with Clause 9.4.



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5.7.4All other concrete structures shall be investigated for the effects of potential contact with LNG. If exposure to LNG can lead to a failure of these structures, which in turn can create a hazardous condition or worsen an existing emergency condition, the structures shall be protected to minimize the effects of such exposure, or they shall comply with Items (a) and (b) of Clause 5.7.2.

5.7.5Concrete for incidental non-structural uses, such as slope protection and impounding-area paving, shall meet the requirements of CSA A23.1/CSA A23.2. Reinforcement for crack control shall be a minimum of 0.5% of the cross-sectional area of concrete for crack control, in accordance with CAN/CSA-A23.3 and Appendix G of ACI 350.

5.7.6Concrete that is not constantly exposed to LNG and that has been subjected to sudden and unexpected exposure to LNG shall be inspected, and repaired if necessary, as soon as is practicable after it has returned to ambient temperature.

5.8 Underground LNG containers

5.8.1Underground LNG tanks shall be installed in accordance with Table 4.

5.8.2Buried and underground containers shall be provided with means to prevent the 0 C (32F) isotherm from penetrating the soil. Where heating systems are used, they shall be installed such that any heating element or temperature sensor used for control can be replaced.

5.8.3All buried or mounded components in contact with the soil shall be constructed from corrosion-resistant material or protected from corrosion deterioration. Note: For information on corrosion protection, see NACE SP0169.

6 Process equipment

6.1 General

6.1.1Process equipment containing LNG, flammable refrigerants, or flammable gases shall be(a) installed outdoors for ease of operation (to facilitate manual firefighting and the dispersal of

accidentally released liquids and gases); or(b) installed indoors in enclosing structures complying with Clauses 5.3.1 and 5.3.2.

6.1.2Pumps and compressors shall be constructed of materials suitable for the temperature and pressure conditions that might be encountered.

6.1.3Valving shall be installed so that each pump or compressor can be isolated for maintenance. Where pumps or centrifugal compressors are installed for operation in parallel, each discharge line shall be equipped with a check valve.



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6.1.4Pumps and compressors shall be provided with a pressure relieving device on the discharge to limit the pressure to the maximum safe working pressure of the casing and downstream piping and equipment, unless these are designed for the maximum discharge pressure of the pumps and compressors.

6.1.5Each pump shall be provided with an adequate vent or relief valve, or both, that will prevent over-pressuring the pump case during the maximum possible rate of cool-down.

6.1.6Compression equipment handling flammable gases shall be provided with vents from all points, including distance pieces, where gases can normally escape. Vents shall be piped outside of buildings to a point of safe disposal.

6.1.7 Welding and brazing of process equipment

6.1.7.1All welding or brazing of process equipment shall conform to the requirements of the Standard to which the equipment is designed and constructed (see Clauses 6.3.2 to 6.3.4). Where equipment is not constructed to a specific Standard, welding and brazing shall be in accordance with Clauses 6.1.7.2 to 6.1.7.4.

6.1.7.2All welding or brazing shall be performed using procedures qualified to the ASME Boiler and Pressure Vessel Code, Section IX.

6.1.7.3All welding or brazing shall be performed by personnel qualified to the ASME Boiler and Pressure Vessel Code, Section IX.

6.1.7.4Oxygen-fuel gas welding shall not be used.

6.1.8The manufacturers record of the maximum allowable working pressure shall be documented for process equipment.

6.2 Flammable refrigerant and flammable liquid storageInstallation of storage tanks for flammable refrigerants and liquids shall comply with Clause 5.2, CSA B149.2, NFPA 30, NFPA 58, NFPA 59, or API Std 2510.

6.3 Process equipment

6.3.1 SitingProcess equipment shall be sited in accordance with Clause 5.2.

6.3.2 Boilers and pressure vesselsBoilers shall be designed and fabricated in accordance with CSA B51 or the ASME Boiler and Pressure Vessel Code, Section I, and pressure vessels shall be designed and fabricated in accordance with CSA B51 or the ASME Boiler and Pressure Vessel Code, Section VIII, Division 1 or Division 2. Boilers and pressure vessels shall be code stamped.



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6.3.3 Shell and tube heat exchangersShell and tube heat exchangers shall be designed and fabricated in accordance with CSA B51 or theASME Boiler and Pressure Vessel Code, Section VIII, Division 1, where such components fall within the jurisdiction of these publications.

6.3.4 Internal combustion engines and gas turbinesInstallation of internal combustion engines or gas turbines shall conform to NFPA 37.

6.3.5 Boil-off and flash gas handlingA boil-off and flash gas handling system separate from container relief valves shall be installed for the safe disposal of vapours generated in the process equipment and LNG containers. Boil-off and flash gases shall discharge safely into the atmosphere or into a closed system. The boil-off venting system shall be designed so that it cannot normally draw in air during operation.

6.3.6 Internal vacuumIf internal vacuum conditions can occur in any piping, process vessels, cold boxes, or other equipment, the facilities subject to vacuum shall be designed to withstand the vacuum conditions, or provision shall be made to prevent the development of a vacuum that can create a hazardous condition in the equipment. If gas is introduced to rectify this problem, it shall be of such composition or so introduced that it does not create a flammable mixture within the system.

6.3.7 Equipment depressurizingNote: Consideration should be given to the depressurization of equipment containing gases and liquids in case of fire or failure of the equipment (see Clause 12.2.1 and the Notes to Clause 12.9.1).

6.3.7.1Emergency controls for depressurizing equipment shall be conspicuously marked, with their function designated, and shall be accessible under emergency conditions.

6.3.7.2The discharge of flammable gases or liquids from relief devices shall

Canada z276-2011

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