Oregon LNG Job No. 07902
Warrenton, OR Doc No. 07902-TS-600-500 Rev 1
Hazard Detection and Mitigation Philosophy Page 1 of 40
HAZARD DETECTION AND MITIGATION PHILOSOPHY
By
H C H H HCH·IV International
REV NUMBER: 0 1ISSUE PURPOSE: Issued for
Client Review INCLUDES APCI DESIGN DATE: 10/17/2007 04/19/2012 BY: OOA ABR CHECKED: RCT JMW
Section
Page
1 INTRODUCTION ... 3
1.1 Scope ... 3 1.2 Regulations, Codes, and Standards... 5 1.3 Equipment Listing and Approvals ... 7
2 SUMMARY OF HAZARD DETECTION AND MITIGATION SYSTEM ... 7 3 TERMINAL DESIGN, LAYOUT, AND FEATURES ... 13
3.1 Description of Spill Impoundment Systems ... 13 3.2 Description of Other Terminal Features that Will Minimize Hazards ... 15
4 HAZARD DETECTION SYSTEM ... 18
4.1 Description of Hazard Detection System ... 18 4.2 Detection System Components ... 22 4.3 Spare Capacity and Expandability ... 27
5 HAZARD MITIGATION SYSTEMS ... 27
5.1 Dry Chemical System ... 27 5.2 Firewater Systems ... 30 5.3 High Expansion Foam Systems ... 36 5.4 Nitrogen Purge System ... 38
6 MOBILE FIRE FIGHTING AND SAFETY EQUIPMENT ... 38
6.1 Portable Fire Extinguishers ... 38 6.2 Personnel Protective Equipment ... 39
7 FIRE BRIGADE ... 39 8 FIRE PREVENTION PLAN ... 40
Oregon LNG Job No. 07902
Warrenton, OR Doc No. 07902-TS-600-500 Rev 1
Hazard Detection and Mitigation Philosophy Page 3 of 40
1 INTRODUCTION
1.1 Scope
This document provides a design philosophy and general overview of the hazard detection and mitigation system that will be provided for the Oregon LNG Terminal ("Terminal") in Warrenton, OR. The Terminal includes:
• A marine facility structure consisting of a pier, loading platform, and loading facilities for one LNG carrier,
• Two 160,000 cubic meter (m3) full-containment above ground LNG storage tanks (T-201),
• Two liquefaction trains using the Air Products and Chemicals, Inc. (APCI) C3- MR (propane and mixed refrigerant) Liquefaction Process, each with a nominal capacity of 4.5 million metric tonnes per annum (MTPA),
• One vaporization train using remote heated vaporizers with a nominal capacity of 500 million standard cubic feet per day (MMSCFD),
• Boiloff Gas Compressor (C-204),
• Ground Flare for the liquefaction trains and a separate flare for the LNG storage and re-gasification process,
• High Voltage Switchyard,
• Propane and Ethane Storage, and
• Utility systems (compressed air systems, nitrogen system, fuel gas system, fire protection systems, potable water system, and wastewater system).
• Natural Gas Pretreatment system that removes impurities from the feed gas. The system uses diethanolamine (DEA) to remove carbon dioxide and hydrogen sulfide from the incoming gas, dehydrators for water removal, and mercury removal beds.
The hazard detection and mitigation philosophy detailed in this document is based on the following safety goals:
• Provide for the life safety and property protection of the public and neighboring facilities in the event of an LNG or hydrocarbon-based refrigerant release from the facility that may result in a fire or explosion.
• Provide for the safety of the Terminal personnel and first responders in the event of hydrocarbon releases/spills, fire/explosion incidents, or releases of hazardous gases.
• Provide for property protection of the Terminal to minimize property damage and downtime that may be experienced as a result of hydrocarbon releases/spills or fire/explosion incidents.
To accomplish the above safety goals, the Terminal design applies Recognized and Generally Accepted Good Engineering Practices that minimize the potential for severe hazardous conditions to occur and their consequence. D esign features will include:
• Process system design features, arrangements and operating procedures/limits that minimize the potential for and magnitude of leaks and spills of LNG, flammable liquids and flammable gases, associated fires and explosions, non- process fires that may damage process equipment, and releases of hazardous gases.
• Containment of LNG, propane, ethane and mixed refrigerant spills and vapor generation to prevent the generation of vapor clouds that exceed 50% of the lower flammability limit of each hydrocarbon at a property line that can be built upon.
• Siting and containment of propane and mixed refrigerant storage and process equipment that minimize off-site consequences.
• Process system, Terminal design features and fire prevention programs that minimize combustible materials and ignition sources.
The Terminal design incorporates a Hazard Detection and Mitigation System (HDMS) that minimizes the magnitude of hazards and minimizes the effects of hazards on the public, neighboring facilities and structures, Terminal equipment and structures, and Terminal personnel as follows:
• Hazard detection systems to detect LNG and refrigerant spills and leaks, natural gas leaks, carbon dioxide leaks, hydrogen sulfide leaks, and fires early during the event to alert personnel of the hazard, to shutdown process equipment and systems (as needed), and to activate hazard mitigation and control systems (as needed).
• Hazard mitigation and control systems to minimize vapor generation, heat release rates of the fire (including fire extinguishment), and/or to heat fluxes to neighboring facilities as well as Terminal equipment and structures.
• Hazard control systems to protect Terminal equipment and structures from fire damage and personnel from fire, smoke, and hazardous gas exposure.
• Hazard detection and mitigation systems designed such that all immediate responses to hazardous conditions are performed automatically or remotely. A preliminary fire safety evaluation has been performed on the front end engineering design to identify the required hazard detection, mitigation, control features and
Oregon LNG Job No. 07902
Warrenton, OR Doc No. 07902-TS-600-500 Rev 1
Hazard Detection and Mitigation Philosophy Page 5 of 40
systems to provide adequate fire safety. This evaluation was performed in accordance with the requirements of Section 9.1.2 of NFPA 59A, 2001 edition (See 07902-TS-600-400).
The fire safety evaluation will be revised during the detailed design of the Terminal to document how the final design provides adequate fire safety.
Where appropriate, automatic fire protection systems will be added to provide additional levels of fire safety.
The detection and mitigation of hazards associated with the shipping of LNG (including carrier hazards, LNG spills on w ater, etc.) is outside the scope of this philosophy. Hazards associated with the loading, storage, vaporization of LNG, and liquefaction of natural gas are included in the scope of this philosophy.
1.2 Regulations, Codes, and Standards
The fire protection system will be designed, manufactured, assembled, installed, tested, and commissioned in accordance with nationally recognized standards, building codes, and federal and state regulations. The following industry codes, standards and guidelines will be used:
1.2.1 US Code of Federal Regulations
• Title 29 CFR, Part 1910.106 -- OSHA Flammable and Combustible Liquids • Title 29 CFR, Part 1910.165 -- OSHA Employee Alarm Systems
• Title 33 CFR, Part 105 -- Maritime Security: Facilities
• Title 33 CFR, Part 127 -- Waterfront Facilities Handling Liquefied Natural Gas and Liquefied Hazardous Gas
• Title 49 CFR, Part 193 -- Liquefied Natural Gas Facilities: F ederal Safety Standards
1.2.2 National Fire Protection Association (NFPA)
• NFPA 10 – Standard for Portable Fire Extinguishers – 2010
• NFPA 11 – Standard for Low, Medium and High Expansion Foam – 2010 • NFPA 13 – Installation of Sprinkler Systems – 2010
• NFPA 14 – Installation of Standpipes and Hose Systems – 2010
• NFPA 15 – Standard for Water Spray Fixed Systems for Fire Protection – 2012 • NFPA 17 – Standard for Dry Chemical Extinguishing Systems – 2009
• NFPA 20 – Standard for the Installation of Stationary Pumps for Fire Protection – 2010
• NFPA 22 – Standard for Water Tanks for Private Fire Protection – 2008
• NFPA 24 – Standard for the Installation of Private Fire Service Mains and Their Appurtenances – 2010
• NFPA 25 – Standard for the Inspection, Testing, and Maintenance of Water- Based Fire Protection Systems – 2011
• NFPA 30 - Flammable and Combustible Liquids Code - 2012 • NFPA 54 - Fuel Gas Code - 2012
• NFPA 58 – Liquefied Petroleum Gas Code - 2011 • NFPA 59 – Utility LP-Gas Plant Code – 2012
• NFPA 59A – Standard for the Production, Storage, and Handling of Liquefied Natural Gas (LNG) – 2001/2009 (whichever is more conservative)
• NFPA 70 – National Electric Code – 2011 • NFPA 72 – National Fire Alarm Code – 2010
• NFPA 214 - Standard on Water-Cooling Towers - 2011
• NFPA 307 – Standard for the Construction and Fire Protection of Marine Terminals, Piers, and Wharves – 2011
• NFPA 497 – Recommended Practice for the Classification of Flammable Liquids, Gases, or Vapors and of Hazardous (Classified) Locations for Electrical Installations in Chemical Process Areas – 2012
• NFPA 600 – Standard on Industrial Fire Brigades – 2010 • NFPA 750 - Water Mist Fire Protection Systems - 2010
• NFPA 1901 – Standard for Automotive Fire Apparatus – 2009 • NFPA 1961 – Standard on Fire Hose – 2007
• NFPA 2001 – Standard on Clean Agent Fire Extinguishing Systems – 2012 1.2.3 Oil Companies International Marine Forum (OCIMF)
• Guide on Marine Terminal Fire Protection and Emergency Evacuation – 1987 1.2.4 American Petroleum Institute
• API 650 – Welded Steel Storage Tanks for Oil Storage – 2008 with Addendum • API 2510 –Design and Construction of Liquefied Petroleum Gas (LPG)
Oregon LNG Job No. 07902
Warrenton, OR Doc No. 07902-TS-600-500 Rev 1
Hazard Detection and Mitigation Philosophy Page 7 of 40
• API 2510A – Fire-Protection Considerations for the Design and Operation of Liquefied Petroleum Gas Storage Facilities – 1996
• API RP500 – Recommended Practice for Classification of Locations for Electrical Installation at Petroleum Facilities Classified As Class I, Division 1 and Division 2 – 2002
1.2.5 American National Standards Institute
• ANSI/ASA S3.41, Audible Emergency Evacuation Signal – 1990 (R2001) 1.2.6 American Society for Testing and Materials ASTM
• ASTM F 1211-87, Standard Specification for International Shore Connections for Marine Fire Applications (1993)
1.2.7 Instrument Society of America
• ISA 12.13.01, Performance Requirements for Combustible Gas Detectors
• ISA 12.13.02, Recommended Practice for Installation, Operation and Maintenance of Combustible Gas Detectors
1.3 Equipment Listing and Approvals
When required within this philosophy or by NFPA codes/standards, hazard detection and fire protection equipment provided shall be Underwriter Laboratories, Inc. (UL) listed or Factory Mutual (FM) approved.
2 SUMMARY OF HAZARD DETECTION AND MITIGATION SYSTEM
The Hazard Detection and Mitigation System (HDMS) will be based on providing a Proprietary Supervising Station Fire Alarm System that meets the requirements of NFPA 72 with the Central Station (main fire alarm panel) located in the Main Control Room, which will be attended 24-hours per day. Hazard detection equipment will monitor the Terminal and signal the main fire and gas alarm panel through local panels and a fiber optic network that serves the HDMS. Table 2.1 provides a hazard, detection and mitigation matrix for the Terminal to show the types of features, detectors, and mitigation systems available to address specific expected hazards. Selection of systems and components and their design conditions will be documented within the NFPA 59A Fire Protection Evaluation 07902-TS-600-400.
Table 2.1 Types of Hazards and Their Control Features, Detection Methods and Mitigation Methods
Hazard Control Features Detection Mitigation
LNG Spill - Vapor Dispersion
- Vapor Cloud Ignition (delayed ignition) - Pool Fire (immediate or delayed ignition)
• Piping materials designed for LNG temperatures. • Piping design considers
anticipated loads
• Process control to minimize operational deviations.
• Minimization of the use of flanges.
• Spill collection troughs/ curbed areas/ trenches under all LNG piping/equipment that route LNG to spill containment basins. • Minimization of ignition
sources in the process areas.
• Non-flammable and heat resistant/fireproofing materials used for process structures.
• Distances between process equipment to reduce fire exposures and heat fluxes. • Spacing of air intakes for
fired equipment and building ventilation systems away from sources of vapor. • Low temperature detectors in troughs/trenches and basins to detect LNG spills.
• Gas detection along spill paths and around process equipment to detect releases. • Flame and/or high
temperature detectors around process equipment, transfer areas, vents, troughs/ trenches, basins, and other potential spill locations to detect fires.
• Manual detection via operators and closed circuit television.
• Audible and visual alarms locally and within the control room.
• Emergency Shutdown (ESD) (manual and/or automatic) to minimize spill duration.
• Hi-Expansion foam in basins to minimize vapor cloud formation and pool fire heat release rates.
• Dry chemical extinguishers/ hose systems near LNG spill curbed areas, trenches/ troughs, and collection basins.
• Water spray systems/ Monitors/hydrants with hoses to provide cooling to process equipment/ structures potentially exposed to at least 9,500 Btu/hr/ft2 thermal radiation for over 10 minutes. • Monitors/hydrants with
hoses to provide increased vapor dispersion.
LNG Tank Failure/Fire • Full containment design, 110% net capacity. • Overpressure/vacuum
protection.
• Site layout to minimize exposure to structures or people off-site and on-site. • Area around tanks designed to contain capacity
• Flame detection on roof.
• Gas Detection on roof. • Manual detection.
• Audible and visual alarms locally and within the control room.
• Deluge system to cool other tank (as needed) from radiant energy of fire.
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Hazard Detection and Mitigation Philosophy Page 9 of 40
Hazard Control Features Detection Mitigation
Liquid Propane/Mixed Refrigerant
Spill/Release - Vapor Dispersion - Vapor Cloud Ignition (delayed ignition) - Pool Fire (immediate or delayed ignition) - Jet/Spray Fire - Vapor Cloud Explosion - BLEVE • High integrity construction for refrigerant systems, hydrocarbon liquids collection systems. • Minimization of the use of
flanges.
• Minimization of ignition sources in the process areas
• Electrical design in accordance with electrical area classifications to minimize electrical ignition sources. • Mounding of propane
storage tanks for passive fire protection.
• Grading/sloping of areas to prevent pooling of refrigerant liquid leaks under equipment • Spill impoundment
systems (dikes, curbs, etc.) to route spills to impoundments (e.g., basins or drainage swales) • Distances between process
equipment to reduce fire exposures and heat fluxes • Spacing of air intakes for
fired equipment and building ventilation systems away from sources of vapor
• Thermal insulation to serve as passive fire protection for large liquid propane and large liquid mixed refrigerant containing vessels.
• Combustible gas detection in areas with process equipment • Visual detection via
operator rounds and closed circuit
television monitors and manual local
emergency buttons • Gas detection at air
intakes for fired equipment and building ventilation systems to shutdown equipment
• Flame and heat detectors around process equipment, transfer areas, vents, troughs,
impoundments, and other potential spill locations to detect fires
• Audible and visual alarms locally and within the control rooms
• ESD (manual and/or automatic) to minimize spill/release duration • Dry chemical systems
and extinguishers in areas with process equipment
• Water spray systems protecting exposed tanks and process equipment with liquid refrigerants.
• Monitors, hydrants with hoses and water spray systems to provide protection and cooling of process equipment/structures from adjacent equipment fires
Hazard Control Features Detection Mitigation
Flammable Gas (natural gas, propane, ethane, MR) Leak/ Rupture - Vapor Dispersion - Vapor Cloud Ignition (delayed ignition) - Jet Fire (immediate or delayed ignition)
• Piping materials designed for process temperatures. • Piping design considers
anticipated loads
• Process control to minimize operational deviations.
• Minimization of the use of flanges.
• Overpressure
protection/vent system to flare.
• Electrical design in accordance with electrical area classifications to minimize electrical ignition sources.
• Minimization of ignition sources in the process areas.
• Process equipment enclosures are equipped with non-load bearing walls to mitigate consequences of explosions due to gas/LNG leaks. • Process equipment enclosure ventilation systems provided to control gas concentration below flammability limits. For enclosures containing systems with heavier than air gases, ventilation draws air from the lower area of the buildings. • Spacing of air intakes for
fired equipment and building ventilation systems away from sources of vapor.
• Gas detection located around process equipment to detect releases. For cold heavier than air hydrocarbons, gas detection is located low to the ground. • Gas detection located
within enclosures with LNG/NG process equipment.
• Gas detection within ventilation system air intakes for other buildings.
• Gas detection within air intakes for fired equipment.
• Flame and/or Heat detection within enclosures to detect fires.
• Manual detection.
• Audible and visual alarms locally and within the control room.
• ESD (manual and/or automatic) to minimize leak duration.
• Dry chemical systems and extinguishers in areas with process equipment.
• Water spray systems/ monitors/ hose systems to cool process equipment exposed to jet fires.
• Water systems/hose systems to fight non- LNG/gas fires in process areas.
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Warrenton, OR Doc No. 07902-TS-600-500 Rev 1
Hazard Detection and Mitigation Philosophy Page 11 of 40
Hazard Control Features Detection Mitigation
Carbon Dioxide or Hydrogen Sulfide Gas Releases (Gas Pretreatment Area)
• High Integrity construction for systems with high concentrations. • Outdoor locations for
better dispersion • Relief to flare system
• Fixed gas detection at exposed operator stations
• Portable gas detectors during maintenance work
• Audible and visual alarms locally and within the control room.
Gas Venting/Flaring - Relief valve - Flare
• Relief valve layout to minimize ignition sources near valves.
• Site layout to minimize effects of flaring on on- site structures and personnel, and on off-site structures and people during Flare operation. • Flare design to include
features to prevent flash back of flame into piping system.
• Flame detection located at LNG storage tank relief valve vents. • Manual detection.
• Audible and visual alarms locally and within the control room.
• Dry chemical systems for LNG storage tank relief valve discharge pipes.
• Nitrogen purging system for Flare header to minimize oxygen within the Flare stack. • Monitors for cooling
water for other equipment near relief valves.
Fires caused by Other Flammable
Liquids/Gases (e.g., collected liquids, refrigerants, lube oil, fuel oil, heat transfer oil)
• High integrity construction for hydrocarbon liquids collection systems, refrigerant systems, lube oil systems, and fuel oil systems.
• Minimization of threaded connections
• Spill impoundment systems (dikes, curbs, etc.).
• Combustible gas detection in areas with equipment.
• Heat and/or smoke detection within enclosures to detect fires.
• Flame and/or Heat detection in outdoor areas with equipment. • Manual detection.
• Audible and visual alarms locally and within the control room. • Ventilation systems within enclosures to control gas concentration below flammability limits. • Dry chemical systems
and extinguishers in areas with process equipment.
• Sprinkler systems/ hose systems to fight non-process fires, lube oil fires, and fuel oil fires, and to cool equipment and structures.
Hazard Control Features Detection Mitigation
Electrical Systems – Failure/Fire
• Electrical design in accordance with electrical area classifications. • Fault protection.
• Fire Separation of oil- insulated transformers. • Fire resistant cable
insulation.
• High sensitivity smoke detection in areas with electrical, computer, and/or control system components.
• Heat detection within areas with high voltage, oil insulated equipment.
• Manual detection.
• Audible and visual alarms locally and within the control room.
• Clean Agent systems in remote, unoccupied electrical or control rooms.
• Carbon dioxide portable extinguishers in areas with electrical equipment.
• Hose systems with fog nozzles in electrical areas.
Exposure Fires • Minimize use of flammable or combustible materials in construction. • Use of fire rated
construction materials for critical structures.
• Facility layout to separate combustibles from ignition sources to greatest degree practical.
• Fire prevention program to minimize transient combustibles and ignition sources.
• Smoke detection. • Heat detection. • Manual detection.
• Audible and visual alarms locally and within the control room.
• Appropriate portable extinguishers in area. • Suppression systems
appropriate for the hazard. • Hose systems. Fired Equipment (including combustion engines) • Facility layout to minimize potential for natural gas vapors to enter the combustion air inlets. • Facility layout to separate
fired equipment from potential sources of natural gas vapors and other combustible materials to extent possible.
• Combustible gas detectors in air inlets. • Heat detection. • Manual detection
• Audible and visual alarms locally and within the control room. • Automatic shutdown of fired equipment. • Suppression systems. • Hose systems. Diethanolamine
Releases • Spill impoundment system to prevent release to environment.
• Manual Detection • Hose systems with fog nozzles
• Dry Chemical portable extinguishers in area
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Hazard Detection and Mitigation Philosophy Page 13 of 40
3 TERMINAL DESIGN, LAYOUT, AND FEATURES
3.1 Description of Spill Impoundment Systems
All areas with piping, tanks, and process equipment that contain LNG, liquid propane, liquid ethane or liquid MR will be designed to capture and contain any leaks and spills. This helps minimize vapor generation and dispersion rates as well as reduce the potential for and consequences of fires.
The impoundment system will be designed and located in accordance with NFPA 59A-2001 and 49 CFR193 to avoid or minimize impact on t he public due to the