LNG Oregon Design Basis Appendix13c-2

8/16/2019 LNG Oregon Design Basis Appendix13c-2

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Oregon LNG Job No. 07902

Warrenton, OR Doc No. 07902-TS-000-002 Rev 4

Design Basis Page 1 of 32

This document contains information that is proprietary to CH·IV International, which is to be held in confidence. No disclosure orother use of this information is permitted without the express authorization from Oregon LNG Development Co. or CH·IVInternational.

DESIGN BASIS

by

H

C

H

HH

CH·IV International

REV NUMBER: 0 1 2 3 4

ISSUE PURPOSE: Draft forClient

Review

RevisedClient

Review

RevisedClient

Review

RevisedClient

Review

RevisedClient

Review

DATE: 05/17/07 7/5/07 9/17/07 10/16/07 12/31/07

BY: OOA AAR AAR OOA AAR

CHECKED: TOA RCT OOA JAK RCT

APPROVED: AAR AAR AAR AAR AAR


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1. GENERAL............................................................................................................... 5

1.1. Reference Documents ................................................................................................5

1.2. Definitions of Units and Conversion Factors...............................................................5

1.3. Glossary of Terms and Abbreviations.........................................................................6

1.4. Design LNG Compositions..........................................................................................6

1.5. Sendout Requirements: ..............................................................................................6

1.6. Vaporization Facilities .................................................................................................7

1.7. Gas Transmission Line ...............................................................................................7

1.8. Design Sendout Cases: ..............................................................................................7

2. PROCESS DESCRIPTION..................................................................................... 8

2.1. LNG Sendout Mode without Carrier Unloading...........................................................8

2.2. LNG Sendout Mode with Carrier Unloading Mode......................................................8

3. BASIS OF DESIGN AND SITE CONDITIONS .......................................................9

3.1. Barometric Pressure ...................................................................................................9

3.2. Air Temperature ..........................................................................................................9

3.3. Wind Speeds...............................................................................................................9

3.4. Coordinate and Elevation References ........................................................................9

3.5. Seawater Temperature .............................................................................................10

3.6. Seismic Information...................................................................................................10

4. CODES AND STANDARDS ................................................................................. 11

5. DESIGN LIFE........................................................................................................ 12

6. LNG CARRIERS................................................................................................... 13


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6.1. Design Requirements – LNG ....................................................................................13

6.2. Terminal Design Requirements – BOG.....................................................................13

7. LNG STORAGE TANKS ...................................................................................... 14

7.1. Description ................................................................................................................14

7.2. Operating Limitations ................................................................................................14

7.3. Other Design Considerations....................................................................................15

8. VAPOR HANDLING SYSTEMS ........................................................................... 16

8.1. Vapor Handling Priority .............................................................................................16

8.2. Flare Design Basis....................................................................................................16

9. LNG PUMPS......................................................................................................... 17

9.1. Description ................................................................................................................17

9.2. Design Considerations..............................................................................................17

10. LNG VAPORIZATION .......................................................................................... 18

10.1. Description ................................................................................................................18

11. MECHANICAL ...................................................................................................... 19


12. UTILITY / AUXILIARY SYSTEMS ........................................................................ 20

13. CIVIL DESIGN......................................................................................................21

14. INSTRUMENTATION AND CONTROL SYSTEMS..............................................22


15. COMMUNICATIONS AND SECURITY SYSTEMS............................................... 24

16. FIRE, HAZARD AND SAFETY SYSTEMS........................................................... 25


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17. TERMINAL RELIABILITY AND EQUIPMENT SPARING PHILOSOPHY............ 26

APPENDIX A: UNIT CONVERSIONS (SI TO ENGLISH).............................................27

APPENDIX B: GLOSSARY OF TERMS AND ABBREVIATIONS ............................... 29

APPENDIX C: APPLICABLE CODES & STANDARDS............................................... 32


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1. GENERAL

This document outlines the basic design criteria to be used for the proposed Oregon LNGImport Terminal (“Terminal”).

The Terminal will be located on the East Skipanon Peninsula near the confluence of the

Skipanon and the Columbia Rivers in Warrenton, Clatsop County, Oregon. The Oregon

LNG Development Company holds a long term sub-lease for the 96 acre parcel of land upon

which the Terminal will be sited.

The Terminal will be designed with a base-load natural gas sendout capacity of 1.0 billion

standard cubic feet per day (“Bscfd”) and a peak of up to 1.5 Bscfd. The Project will

receive LNG discharged from oceangoing LNG carriers, which will be stored in three (3)

160,000 cubic meter (“m3”) aboveground, full containment LNG storage tanks. LNG will be vaporized into natural gas, and sent out from the terminal via an approximately 121-mile

sendout pipeline. LNG carriers will arrive at the Oregon LNG Project via marine transit

through the Skipanon Channel.

The scope of this document includes the on-shore LNG import terminal up to its battery

limit and the piping systems and associated equipment on the marine facility. Excluded

from the scope of this document is the marine facility structure itself and the off-site natural

gas sendout piping system.

1.1. Reference Documents

The document is supported by the following project specific documents:

• Plot Plan (Drawing No. 07902-DG-000-001)

• Process Flow Diagram (Document No. 07902-PF-000-001)

• Heat & Material Balance Diagrams (Document No. 07902-PF-000-011)

• Engineering Development Standard (Document No. 07902-TS-000-001)

• Design Codes and Standards (Document No. 07902-TS-000-022)

1.2. Definitions of Units and Conversion Factors

The units used for this project are English units. See Appendix A for a table of units

and conversion factors.


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1.3. Glossary of Terms and Abbreviations

See Appendix B for a Glossary of Terms and Abbreviations used throughout this

document.

1.4. Design LNG Compositions

The Import Terminal shall be designed to receive LNG from several possible LNG

production facilities. Table 1.4 presents the range of compositions that will be used

in the design of the Import Terminal systems and equipment.

Table 1.4 Design LNG Compositional Range

LNG Light Heavy

Component Units Composition Composition

Source Camisea(Peru)

Australia

Methane Mol % 89.05% 86.11%

Ethane Mol % 10.38% 9.04%

Propane Mol % 0.02% 3.60%

n-Butane Mol % 0.00% 0.42%

i-Butane Mol % 0.00% 0.52%

n-Pentane Mol % 0.00% 0.01%

i-Pentanes Mol % 0.00% 0.00%

Nitrogen Mol % 0.54% 0.30%

Molecular Weight 17.57 18.76

Gross Heating Value Btu/scf 1088.3 1156.5Hydrogen Sulfide ppm by vol. nil nil

Total Sulfur ppm nil nil

Mercaptan Sulfur ppb nil nil

1.5. Sendout Requirements:

• All sendout rates indicated are net, i.e., exclusive of internal shrinkage and

consumption within the Terminal.

• The Terminal sendout natural gas at a base-load rate of 1.0 bscfd and a peak

sendout rate of 1.5 bscfd.

• Natural gas from the Terminal will connect to the Williams Northwest Pipeline

System at the Molalla Gate Station, which is approximately 121 miles from the

Terminal. Natural gas quality will comply with the requirements of the Williams

Northwest Pipeline System tariff (Third Revised Volume No. 1 is in effect at

present). The key provisions of the tariff are summarized in Table 1.5.


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Table 1.5: Specification Limits

Characteristic and Compounds Units Limit

Gross Heating Value Btu/scf 985 Minimum

Total Inert Gas Composition Maximum 3 mol%

Temperature °F Maximum 120°F

1.6. Vaporization Facilities

• Baseload Natural Gas Sendout Rate...........................................................1.0 bscfd

• Peak Load Natural Gas Sendout Rate.........................................................1.5 bscfd

• Minimum Natural Gas Sendout Rate (no flaring, no carrier unloading) . 0.15 bscfd

• Base and Peak load First Stage Vaporization Heat Source .................. Ambient Air

• Base and Peak load Second Stage Vaporization Heat Source.............Fired Heaters

• Battery Limit Natural Gas Maximum Discharge Pressure ......................... 1440psig

• Battery Limit Natural Gas Discharge Temperature..........................................40 °F

1.7. Gas Transmission Line

• Diameter of Pipeline Leaving Site.................................................................36 inch

• Maximum Allowable Working Pressure is 1440 psig (in accordance with pipeline

design)

• Normal Operating Pressure at Pipeline Interconnect ................................ TBD psig

1.8. Design Sendout Cases:

Case 1 - Zero Sendout, No Carrier Unloading

Case 2 - Minimum Sendout Rate required for full vapor handling (no flaring), NoCarrier Unloading

Case 3 - Minimum Sendout Rate required for full vapor handling (no flaring),With Carrier Unloading

Case 4 - Peak Sendout (1.5 bscfd), With Carrier Unloading

Case 5 - Peak Sendout (1.5 bscfd), No Carrier Unloading


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2. PROCESS DESCRIPTION

The following describes the normal operating modes of the Terminal.

2.1. LNG Sendout Mode without Carrier Unloading

When operating in this mode the in-tank, column mounted LNG pumps circulate

LNG through a small diameter circulation line to the marine facility and back through

the LNG transfer pipeline to the LNG storage tank(s) in order to keep these piping

systems cold. LNG is also sent from the storage tank to the BOG condenser and

suction drum of the HP pumps prior to vaporization and sendout.

In this operating mode boiloff gas (BOG) is continuously generated in the tanks due

to heat leak into the system piping, heat leak through the insulated tank walls, and

heat added by the in-tank LNG pumps. BOG will be compressed by the BOGCompressors and condensed in the BOG Condenser. The condensed BOG will be

routed to the HP Pumps for sendout.

2.2. LNG Sendout Mode with Carrier Unloading Mode

A single LNG carrier will moor at the unloading berth. Following cooldown of the

unloading arms, the carrier will use onboard pumps to transfer the LNG through the

unloading arms and the LNG transfer pipeline to the LNG storage tanks. The LNG

unloading and transfer system will be designed to unload a carrier at a maximum rate

of 14,000 m3/hr.

During carrier unloading, vapor in the LNG storage tanks will be displaced by the

LNG pumped into the storage tanks. Some of the displaced vapor will be returned to

the carrier by the vapor return system via vapor return blowers, a vapor return

pipeline and a vapor return arm connected to the carrier. Vapor return rate will be

controlled to maintain the pressure in the carrier’s tanks.

Additional BOG will be generated due to the heat added by the carrier’s transfer

pumps and the heat leak into the tank and piping systems. Any excess BOG not

returned to the carrier will be compressed by BOG compressors and condensed in a

BOG Condenser. The condensed BOG will be routed to HP Pumps for sendout.

LNG is also sent from the storage tank to the BOG condenser and suction drum of theHP pumps prior to vaporization and sendout.


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3. BASIS OF DESIGN AND SITE CONDITIONS

3.1. Barometric Pressure

• Average Barometric Pressure .................................................................. 1017 mbar

• Maximum Barometric Pressure .............................................................. 1040 mbar

• Minimum Barometric Pressure ................................................................. 980 mbar

• Maximum Rate of Change per Hour of Barometric Pressure........................ 1 mbar

3.2. Air Temperature

• Maximum Design Temperature .......................................................................96 °F

• Minimum Design Temperature ..........................................................................6 °F

• Basis for heat leak calculations..........................................................................95°F

3.3. Wind Speeds

• Basis for heat leak calculations..................................................................... 10 mph

• LNG Storage Tank Wind Velocity Design Basis1...................................... 150 mph

• Process Equipment Wind Velocity Design Basis2.............100 mph (3 second gust)

• Buildings Wind Velocity Design Basis2............................100 mph (3 second gust)

Notes:

1 Per 49 CFR 193.2067

2 The site is located in a “Special Wind Region” as defined in ASCE 7-05. The design wind speed

value of 100 mpg is based upon information presented in “SEAW Commentary on Wind Code

Provisions,” Volume 1, Section 4.3

3.4. Coordinate and Elevation References

The Oregon State Plane, North zone, NAD83, International Feet, grid coordinates

will be used in the design. More specifically, Horizontal Coordinates: State Plane -

Oregon North, NAD83 (CORS96)(EPOCH:2002.0000), International Feet based on

OPUS solutions to certain points, and Static ties to the others.

Elevations are North American Vertical Datum of 1988 (NAVD88) computed with

Geoid 03 and OPUS positions and heights.


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Tidal datum for the site relates to NAVD88 datum (in feet) as follows

• El. 0 (NAVD88) = El. 0

• El. 0 (MLLW) = El. -0.44

• El. 0 (MLW) = El. 0.81

• El. 0 (MTL) = El. 4.24

• El. 0 (MSL) = El. 4.24

• El. 0 (MHW) = El. 7.66

• El. 0 (MHHW) = El. 8.36

Please note that this tidal information is not specific to the site but is taken from

National Oceanic Atmospheric Administration (NOAA) tidal station No. 9439026

located at Astoria, Young’s Bay. .

3.5. Seawater Temperature

• Annual Maximum .............................................................................................68 °F

• Annual Minimum..............................................................................................42 °F

• Annual Average ................................................................................................55 °F

3.6. Seismic Information

Seismic information to be provided upon completion of geotechnical investigation of

site.


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4. CODES AND STANDARDS

The Terminal shall be designed in accordance with NFPA 59A, “Standard for the

Production, Storage, and Handling of Liquefied Natural Gas (LNG),” 2001 edition and also49 CFR Part 193: Liquefied Natural Gas Facilities Federal Safety Standards. Where the

2006 edition of NFPA 59A provides more stringent requirements, the Terminal shall be

designed in accordance with the more stringent 2006 requirements.

Document 07902-TS-000-022 includes a listing of other codes and standards to be used in

the design, construction and operation of the Terminal. Additional codes and standards may

be applicable and substitutions for the listed codes and standards may be used, if approved

by LNG Development Company. All applicable local codes and standards that have not

been included in the list shall be satisfied in the design.


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5. DESIGN LIFE

The minimum design life for all facilities, excluding marine, shall be 25 years. After 25

years operation, the Terminal may be subject to a program of refurbishment to extend thelife. Equipment and components normally subject to wear and deterioration need not have a

life of 25 years. These pieces of equipment shall, however, be designed to have maximum

practical life and shall be designed so as not to prevent Terminal operation at full load

except for scheduled maintenance activities arranged in accordance with the operating and

maintenance instructions. For marine structures and facilities the minimum design life shall

be 40 years.


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6. LNG CARRIERS

6.1. Design Requirements – LNG

• The Terminal is expected to receive LNG tankers that range in from 70,000 m3 to

266,000 m3.

• The Terminal will have a single berth.

• The Terminal will be capable of unloading LNG at a maximum rate of 14,000 m3/hr via

3 x 16” LNG unloading arms. A single 16” vapor return arm will be used to return

vapors displaced from the LNG storage tanks to the carrier.

• The minimum available pressure at the carrier’s LNG unloading manifold flange is 330

feet of head (approximately 65 psig, but is a function of LNG specific gravity).

6.2. Terminal Design Requirements – BOG

• The maximum allowable saturation pressure of a carrier’s cargo on arrival at the

Terminal is 2.5 psig. Note: this is the equilibrium pressure and is not to be confused

with the carrier tank vapor pressure.

• The vapor return requirements from the Terminal to the carrier, as measured at the

carrier’s vapor return flange, are:

• The maximum required vapor flow returned to the carrier is to include a normal

boiloff rate from the carrier. A design boiloff rate of 0.15% of the full contents per

day at 95°F ambient for newer carriers and a maximum boiloff rate of 0.25% of the

full contents per day at 95°F ambient for older carriers is to be used.

• Design pressure at carrier vapor return flange = 1.45 psig

• Maximum temperature at carrier vapor return flange = -180°F


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7. LNG STORAGE TANKS

7.1. Description

The terminal shall have a total LNG storage capacity of 480,000m3 (net). LNG will

be stored in three identical 160,000 m³ (net) LNG storage tanks.

The LNG storage tanks shall be flat-bottomed, vertical, cylindrical, full containment

type design. The inner tank will be constructed of a suitable cryogenic alloy such as

9% nickel steel, as the primary liquid containment. The outer tank walls and roof

shall consist of reinforced concrete and will be designed to contain the vapor as well

as provide secondary containment of the LNG in the unlikely event of an inner tank

failure. Outer tank walls will also include post-tensioned cables as required by the

design.

The LNG storage tank and foundation design shall be based on the results of the site

specific geotechnical investigation and site specific seismic hazard evaluation.

If the outer tank base is in direct contact with the ground, a tank foundation heating

system will be provided to prevent subsoil freezing and frost heave below the tank.

The base heating system for each tank will be fully redundant.

7.2. Operating Limitations

The maximum allowable working pressure of the tank will be 4.3 psig with the

following operating set points:• LNG Tank Relief Valve Set Point .............................................................4.3 psig

• Discretionary Vent PIC Set Point ...............................................................4.0 psig

• Normal Operating Pressure Range .....................................................0.5 to 3.7 psig

• Operating Pressure to Size BOG Compressor .............................................. 3.5 psig

The tank minimum design LNG density is 29.3 lb/ft3.

The minimum design LNG temperature is -270°F.

The LNG tank floor and exposed wall shall be designed to accommodatetemperatures of -320°F in case liquid nitrogen is to be used during the initial cool

down procedure.


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7.3. Other Design Considerations

The maximum allowable design vacuum on the tank will be determined by the tank

designer but shall not be less than 2.0" w.c. A tank pressure maintenance system will

be provided to prevent vacuum conditions from occurring during normal operation.

A vacuum relief system will be installed on the tank and will be sized for the worst

case conditions.

The heat leak into the LNG storage tank will give a maximum boil-off of 0.05% per

day at 95°F ambient temperature, based on pure methane and a full tank.

The tank will be designed to handle the full discharge rate from the LNG carrier

through either top or bottom fill connections.

Instrumentation will be provided for continuous level, temperature and density

measurements throughout the level of the tank inventory to monitor for stratificationof the tank contents. Features shall be provided in the design to rapidly circulate the

stored LNG to thoroughly mix the contents, should stratification start to develop.


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8. VAPOR HANDLING SYSTEMS

8.1. Vapor Handling Priority

• The LNG tank shall first be protected from low pressure by introducing re-

vaporized LNG into the BOG Header.

• The LNG carrier’s tanks shall next be protected from low pressure by returning

BOG to the carrier through the Vapor Return Arm.

• Excess vapor (indicated by rising LNG tank pressures) will be condensed in the

BOG Condenser and sent out through the vaporization system. The BOG

Condenser shall be sized to condense the BOG gas stream generated during

tanker offloading and normal sendout operations. The BOG Condenser shall be

sized for the minimum sendout rate of 300 mmscfd during LNG carrier offloading

operations. The operating pressure of the BOG Condenser shall be optimized for

the vapor compression and LP Pump requirements.

• During extended periods of zero sendout or with loss of the BOG Compressors

and Vapor Return Blowers during LNG carrier unloading with the LNG storage

tank operating near the vent pressure setpoint, excess vapor will be safely flared

through the Flare Stack.

8.2. Flare Design Basis

The Terminal will be designed to minimize fugitive emissions with no flaring during

all normal operations using a Closed Vent/Drain System. All LNG and Natural Gas

relief valves (excluding LNG Storage Tank, Fuel Gas Drum and the LNG Vaporizer process relief valves) will be vented into a closed vent flare system that is common

with the LNG storage tank vapor spaces.

In case of excess relief system pressure an atmospheric flaring system will be

installed. The following are abnormal situations that will result in venting of natural

gas:

• Initial Cooldown of the Terminal

• Extended Power Outage

• Extended ESD Events

• Unexpected loss of vapor handling equipment during carrier unloading with the

LNG tank operating near maximum normal operating pressure


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9. LNG PUMPS

9.1. Description

There are two LNG pumping systems: LP (Low Pressure) Pumps and HP (High

Pressure) Pumps.

• The LP Pumps are column mounted submerged motor type and will be located

inside and near the bottom of the LNG storage tanks.

• The HP Pumps will be multi-stage centrifugal submerged motor type and will be

mounted in individual sealed and insulated suction vessels.

9.2. Design Considerations

All pumps will be provided with an individual minimum flow recycle line and flowcontrol to protect the pump from insufficient cooling and to maintain bearing

lubrication at low flow rates.

All pumps will have remotely monitored pressure, flow, vibration and motor

amperage signals.

All pumps will be designed to be isolated and safely maintained without requiring

other pumps to be removed from service. The LP Pumps will be removable for

maintenance while maintaining an operating level in the LNG storage tank.

LP pumps will be sized such that two pumps are needed for the base load sendout of1.0 bsfcd; a third pump will operate during higher sendout flows. To allow maximum

operating flexibility, the LP pump piping system for each tank will be sized to allow

simultaneous full flow from each of the tank's two LP pumps.

Each HP Pump will be supplied from a common suction manifold and discharge into

a common manifold supplying the vaporizers. Valves will be provided to safely

isolate each pump from the system.


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10. LNG VAPORIZATION

10.1. Description

The vaporization system will be designed such that it will be an integrated system

utilizing ambient air vaporizers and a supplementary heating system that will consist

of either a natural gas fired heating system or a waste heat recovery system.

Gas sendout temperatures shall be designed for a minimum of 40°F at the Import

Terminal battery limit.


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11. MECHANICAL


11.1.1. Unloading Arms

There will be three 16" liquid unloading arms and one 16" vapor return arm at the

berth. The unloading arms will have full-bore, emergency release valves and

couplings (ERC) at the outboard end of each arm.

11.1.2. Cryogenic Insulation

Cryogenic insulation systems will consist of multiple layers of insulation

polyurethane foam (PUF), polyisocyanurate foam (PIR) or cellular glass foam

(Foamglas™) with vapor barrier membrane installed between each layer and a sealed

weatherproof metallic (stainless steel or owner approved alternative) outer jacketing.

Adequate insulation expansion joints will be included.

11.1.3. Vapor Handling Equipment

Compressors and blowers for BOG service shall not use any oil that could contact the

process gas and be returned to the LNG tanks or carriers through any possible flow

path.

11.1.4. Cryogenic Piping

Any equipment or piping to be used in cryogenic service will be internally clean, freeof surface contaminants and completely free of any residual water, condensable water

or oil prior to initial cooldown.

11.1.5. Pressure Vessels and Containment Equipment

All pressure vessels, heat exchangers and fired heaters will be designed, built and

code stamped to the appropriate ASME, API or TEMA Standard as listed in

Document 07902-TS-000-022. Additionally, all pressure vessels will be registered

with the U.S. National Board.


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12. UTILITY / AUXILIARY SYSTEMS

The Terminal will be designed with the following utility and auxiliary systems, as required,

to support the operation of the Terminal in each of the operating cases defined.• Electrical Power Generation and Distribution, including: Power Substations,

Transformers, Switchgear, Multiple Voltage Distribution, Emergency Generation and

UPS Systems.

• Nitrogen

• Potable Water

• Service Water

• Mechanical Handling Systems including Fixed Cranes and Lifting Devices

• Sanitary Sewer and Waste Water Treatment

• Storm Sewer and Disposal

• Waste/Oily Water Collection and Treatment System

• Utility Air and Instrument Air

• Diesel Fuel Oil Storage and Distribution

• Heat Transfer Fluid Storage and Makeup System

• Ammonia (for control of emissions from gas-fired heating equipment)


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13. CIVIL DESIGN

The civil design of the Terminal will cover, at minimum, the following areas:

• Soil Improvement

• Foundations

• Paving

• Curbing (both roadway and LNG diversion, where appropriate)

• LNG Containment and Impoundment Design and Insulation Needs

• Pipe Supports

• Buildings

• Culvert / Bridge / Piping / Road Requirements

• Shoreline Stabilization

• Equipment Grouting


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14. INSTRUMENTATION AND CONTROL SYSTEMS


A Terminal Control and Monitoring System (PCMS) will be designed that will

consist of field instrumentation and a number of microprocessor based sub-systems

that will be located in strategically placed control centers throughout the Terminal.

Primary operator interfaces will be provided at the Main Control Room (MCR) and at

the Platform Control Room (PCR).

Sub-systems that make up the PCMS will include the Distributed Control System

(DCS), Safety Instrumented System (SIS), Hazard Detection and Mitigation System

(HDMS), Analyzer System, Gas Metering System, LNG Tank Gauging System,

Vibration Monitoring System, and the Marine Instrumentation System

The DCS will include a Supervisory Station that will be located in the Main Control

Room (MCR) and will access (Read Only) process monitoring and alarm data. The

Supervisory Station will be used to generate various operational and management

reports. The DCS will communicate with each instrument sub-system via Modbus

RTU protocol, utilizing Ethernet or serial connections, or hard-wired connections.

The Terminal will be controlled primarily from the MCR, which will be the primary

operator interface and monitoring center for the Terminal. The MCR will be

equipped with pushbuttons that activate the Emergency Shutdown (ESD) system.

Operations personnel in the MCR will monitor critical alarms and process variables

and will be able to manually shutdown the unloading operation.

The Platform Control Room will be the control center for unloading operations and

will be located on the unloading platform and manned during LNG unloading

operations. The PCR will be equipped with pushbuttons that activate the ESD

system.

Local Control Station (LCS) shelters will be located in the vicinity of packaged

equipment and will contain instrument cabinets and packaged equipment cabinets.

Field instruments will be connected via remote distributed I/O panels located in

weatherproof enclosures or via marshalling racks in equipment rooms.

A completely independent, stand-alone, high integrity Safety Instrumented System

(SIS) will be designed to implement process safety related interlocks.

A stand-alone independent Hazard Detection and Mitigation System (HDMS) will be

designed to continuously monitor and alert the Technician of hazardous conditions

throughout the Import Terminal due to fire or LNG/NG leaks. Monitoring capability


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will be provided via video display units and/or mimic panel displays located in the

MCR and the PCR. In response to the Fire and Gas leak alerts, operating personnel

will have the ability to manually initiate appropriate fire fighting and/or shutdown

actions via hard-wired switches provided on the MCR and the PCR control consoles.Fire alarms and overview graphic displays depicting the location of detectors will be

repeated on the DCS.

A LNG Storage Tank Gauging System will be designed that will consist of a

microprocessor based networked inventory management system that will consolidate

all level, temperature and density measurement associated with the LNG storage

tanks. The system will be interfaced with the DCS via non-redundant Ethernet or

serial link.

A Vibration Monitoring System will be designed to monitor shaft vibration, axial

displacement, and bearing temperatures of major rotating machines. A dedicated

machine monitoring workstation will be provided in the MCR. Common alarms will

be provided on the DCS. Trip signals will be hard-wired to the machine safeguarding

system and alarmed on the DCS.

A Marine Monitoring System will be designed to aid LNG carrier berthing and

navigation and will include the following control systems that will be provided and

monitored at the PCR:

• Mooring Load Monitoring System;

• LNG carrier Berthing Monitoring System; and

•

Weather Monitoring System


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15. COMMUNICATIONS AND SECURITY SYSTEMS

The Terminal shall have communications and security systems including:

• Telephone System – Internal and Outside Access

• Radio Communications (walkie-talkie system for internal Terminal use)

• Marine Ship-to-Shore Radio Communications as Required to Communicate with

Approaching/Departing LNG Carriers

• Cable Connections for Data Transfer and Communications with Carriers at the Dock

• Intercom/Paging System

• Local Alarm and Hazard Warning Signals

• Security Fencing/Gates

• Security and Safety CCTV Monitoring with Digital Video Feed and recordingcapabilities.


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16. FIRE, HAZARD AND SAFETY SYSTEMS


16.1.1. Hazard Detection

A comprehensive hazard monitoring system shall be provided. Elements

of these systems may include:

• Flammable gas detectors

• High and low temperature detectors

• Smoke detectors

• UV/IR flame detectors

• Manual local emergency shut down (ESD) activation push buttons

All hazard signals will alarm both in the control room and locally. Local

signals will be both audible and visual (strobe lights) and have distinctive

alarms and colors for fire and flammable gas (leak) hazards. Where

appropriate a hazard trip may initiate automatic shutdown of equipment

and systems and may activate the ESD system.

The Terminal will have a hazard monitoring philosophy that will define

the proper equipment and how it will integrate with the DCS.

16.1.2. Hazard Mitigation

Fire water and, where appropriate, deluge systems shall be provided to

protect personnel, equipment and facilities.

Hazards from potential LNG spills and ignition shall be mitigated by a

combination of fire and vapor suppression systems, which may include:

• Dry chemical systems

• Dedicated fire water system

• Dedicated water deluge and sprinkler applications

• High expansion foam systems


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17. TERMINAL RELIABILITY AND EQUIPMENT SPARING PHILOSOPHY

The Terminal will be designed to operate with an availability of 95% and will assume a

minimum (n+1) sparing philosophy for all process equipment critical to gas sendout andcarrier unloading for the base-load sendout cases.


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Appendix A: Units


AppendixA: Unit Conversions (SIto English)

Quantity(Base Units) From SI To English Multiply By

Electric Current Ampere (A) Ampere (A) 1.0

Length meter (m) feet (ft) 3.2808

Mass kilograms (kg) pound mass (lbm) 2.2046

Temperature degrees Celsius (°C) degrees Fahrenheit (°F) (°C x 1.8)+32

degrees Kelvin (°K)=°C plus 273.15

degrees Rankine (°R)= °F plus 459.67

°K x 1.8

Time second (s) second (s) 1.0

Amount of Substance mole (mol) mole (mol) 1.0

Area square meter (m2) square feet (ft2) 10.764

Density kilograms per cubicmeter (kg/m3)

pounds per cubic foot(lb/ft3)

0.062428

Dynamic Viscosity centipoises (µ) pounds mass per foot-second (lbm/ft-s)

0.00067222

Electric Resistance Ohm (Ω) Ohm (Ω) 1.0

Electromotive Force Volt (V) Volt (V) 1.0

Energy, Work, Quantity of

Heat

Joule (J) British thermal unit (Btu) 0.0009478

Enthalpy Joule (J) British thermal unit (Btu) 0.0009478

Entropy Joule per degree Celsius(J/°C)

British thermal unit perdegree Fahrenheit

(Btu/°F)

0.000526

Feed Composition mole percent (Mole%) mole percent (Mole%) 1.0

Force Newton (N) pound force (lb) 0.2248

Frequency Hertz (Hz) Hertz (Hz) 1.0

Fluid Flow Rate

(Volumetric)

cubic meters per hour

(m3/h) or kiloliters perhour (kl/h)

U. S. gallons per minute

(gpm)

4.4028

Gas Flow Rate(Volumetric)

normal cubic meters perhour (Nm3/hr)

standard cubic feet perday (scfd)

895.92

Linear Acceleration meters per secondsquared (m/s2)

feet per second squared(ft/s2)

3.2808


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Appendix A: Units


Quantity(Base Units) From SI To English Multiply By

Linear Velocity meters per second (m/s) feet per second (ft/s) 3.2808

LNG Trade metric tons standard cubic feet (scf)(approx.)

46,865

Mass Flow Rate kilograms per hour (kg/h) pounds mass per hour(lbm/h)

2.2046

Moment of Force Newton meter (N-m) foot-pound (ft-lb) 0.73756

Power Watts (W) British thermal unit perhour (Btu/h)

3.4134

Watts (W) horsepower (hp) 0.0013405

Pressure Pascals (Pa) or Newtonsper square meter (N/m2)

pounds per square inch –gage or absolute (psi)

0.0001450

bar pounds per square inch 14.5038

Quantity of Electricity Coulomb Coulomb 1.0

Rotational Velocity revolutions per minute(rpm)

revolutions per minute(rpm)

1.0

Specific Enthalpy Joule per kilogram (J/kg) British thermal unit perpound mass (Btu/lbm)

0.00042992

Specific Entropy Joule per kilogram

degree Kelvin (J/kg-°K)

British thermal unit per

pound mass degreeRankine (Btu/lbm-°R)

0.00023885

Stress Newtons per squaremeter (N/m2)

pounds per square inch(psi)

0.00014504

Thermal Conductivity Watt per meter degreeCelsius (W/m2-°C)

British thermal unit inchper hour foot squared

degree Fahrenheit (Btu-in/hr-ft2-°F)

6.9335

Time Minute (min) minute (min) 1.0

hour (h) hour (h) 1.0

Volume cubic meters (m3) cubic feet (ft3) 35.314

Volume (Liquid) liters U. S. gallons 0.2642

Weight Metric tons pounds (lbs) 2204.62


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Appendix B: Glossary of Terms and Conditions


AppendixB: Glossaryof Terms andAbbreviations

100 Year Event ......................Something that based on historical data would not occur more than

once in 100 years.

ACI.........................................American Concrete Institute

API .........................................American Petroleum Institute

ASCE .....................................American Society of Civil Engineers

ASME ....................................American Society of Mechanical Engineers

ASTM ....................................American Society for Testing and Materials

Bathymetric............................Relating to the measurement of depths of water in oceans, seas,

and lakes.

Battery Limit..........................The exterior limit of the terminal equipment or land, beyond which

the terminal has no immediate responsibility.BBL (bbl)...............................barrel, 42 U.S. gallons

Berth.......................................The location where a carrier lies when it is at anchor.

Boiloff ....................................The cold -160°C [-260°F] gas that has evaporated from LNG. It is,

in all practicality, pure methane.

Cathodic Protection................A means of protecting metals against corrosion by supplying a

small electric charge (negative) to the surface, preventing the

accumulation of corrosive ions.

Centrifugal Pump...................A pump in which the fluid flows axially through an inlet into an

impeller and is accelerated by a rotating element, increasing thevelocity and as a result, the pressure.

CGA .......................................Compressed Gas Association

Cryogenic...............................Temperatures colder than -75°C [-100°F].

DB..........................................Design Basis

DCS........................................Distributed Control System

Deluge ....................................A system used to cover or spray essential equipment with water in

the event of a fire.

Dolphin ..................................A buoy or cluster of closely driven piles used as a fender for a

dock or as a mooring or guide for boats.Dry Gas Seals.........................Seals on compressors that use dry gas as the sealing medium as

opposed to liquids such as oil.

ed............................................Edition

ESD........................................Emergency Shut Down


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FEED......................................Front End Engineering and Design

Frost Heave ............................A condition that occurs when the moisture in soil expands when

frozen. This can develop very high upward forces whenconstrained under foundations such as those supporting LNG

tanks.

Full Containment (FCT) ........An LNG storage tank design in which concrete surrounds a two

wall tank such that in the event of an inner tank rupture, the LNG

will be fully contained within the concrete wall boundary.

Gross Heating Value..............The total heat obtained from the combustion of a specified amount

of fuel which is at 60°F when combustion starts, and the

combustion products of which are cooled to 60°F before the

quantity of heat released is measured.

Head .......................................The pressure differential that causes a fluid in a pipeline or systemto flow. Usually measured in terms of the height of liquid in a

column.

Heat Leak...............................A general term used to describe heat added to the process fluid

from the surroundings at any location in the terminal.

HP ..........................................High Pressure

HTF........................................Heat Transfer Fluid

Impoundment .........................An area defined through the use of dikes or site topography for the

purpose of containing any accidental spill of LNG or flammable

refrigerants.LNG .......................................Liquefied Natural Gas

NEHRP ..................................National Earthquake Hazards Reduction Program

NFPA .....................................National Fire Protection Association

P&ID......................................Piping and Instrumentation Diagram

ppm ........................................Parts per million

ppb..........................................Parts per billion

Phase I....................................First phase of terminal development that encompasses all the work

included in this project scope.

Phase II ..................................A possible future expansion of facilities that shall be taken into

consideration in the current project scope. Such things as tie-in

locations and plot plan space will be provided in this project scope.

Radiograph.............................A picture produced on a sensitive surface by a form of radiation

other than light, such as X-ray or Gamma ray.


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Relief Valve ...........................A valve that opens at a designated pressure and bleeds a system in

order to prevent a build-up of excessive pressure that might

damage the system.RFP ........................................Request for Proposal

RFQ........................................Request for Quotation

RTD........................................Resistance Temperature Detector

Saturation Pressure ................The pressure at which a vapor confined above a liquid will be in

stable equilibrium with it. Below saturation pressure, some of the

liquid will change to vapor, and above saturation pressure, some of

the vapor will condense to liquid.

Seismic Zone..........................The site-specific seismic conditions that determine the level of

design required for the components in the terminal such that theycan withstand a probabilistic maximum considered earthquake.

SIGGTO.................................Society of International Gas Tankers and Terminal Operators

Slug Cooldown.......................To introduce LNG into piping or equipment without requiring

prior gradual cooldown.

Stages .....................................Higher pressure increases in a centrifugal pump can be achieved

by using multiple “stages” in which two or more impellers are

mounted in series on a common shaft. The velocity and pressure

of the fluid increases as it is accelerated through each stage.

Submerged Electric Motor.....A motor used to power cryogenic pumps in which the motor

components and bearings are submerged in the process fluid,helping to keep the device lubricated and cooled.

TBD........................................To Be Determined

TEMA ....................................Tubular Exchanger Manufacturers Association

UPS ........................................Uninterruptible Power Supply

UV/IR.....................................Ultraviolet/Infrared

Vacuum..................................A pressure below atmospheric pressure.

Vapor Handling System.........A pressure controlled system used to guarantee a prioritized

distribution of boiloff gas to the appropriate components within the

terminal.

Vaporizer ...............................A device used to convert LNG to natural gas by adding heat.

VJ ...........................................Vacuum Jacketed

w.c..........................................Water Column


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Appendix C: Design Codes and Standards

endixC: Applicable Codes &Standards

The Terminal shall be designed in accordance with NFPA 59A, “Standard for the Production,Storage, and Handling of Liquefied Natural Gas (LNG)”, 2001 edition and also 49 CFR Part

193: Liquefied Natural Gas Facilities Federal Safety Standards. Where the 2006 edition of

NFPA 59A provides more stringent requirements, the Terminal shall be designed in accordance

with the more stringent 2006 requirements.

Other codes and standards to be used in the design, construction and operation of the LNG

Terminal are listed in document 07902-TS-000-022. All applicable local codes and standards

that have not been included in the list shall be satisfied in the design.

Where there is a conflict between an international standard and a local one, the most stringent

requirements shall apply.

AppendixD: Bathymetric Data