appendix 13l-storage tanks

8/9/2019 Appendix 13L-Storage Tanks

1/103


2/103


3/103


4/103

Oregon LNG, LLC Job No. 07902Warrenton, OR Doc No. 07902-TS-200-108, Rev. ELNG Storage Tank and Foundation Specification Page 3 of 38

5.3 Purging 38


5/103


1 GENERAL REQUIREMENTS

1.1 Scope of Requirements

This Specification covers technical requirements for the design, supply, fabrication,

construction, inspection, and testing of full containment refrigerated LNG storage tanks

T-201A/B and associated foundations for the proposed Oregon LNG Terminal. Each

tank shall have a net working capacity of 160,000 m3at a temperature of -270F and a

maximum internal pressure of 4.3 psig.

The tanks shall consist of a 9% nickel open top inner tank. The outer tank shall be of

reinforced concrete consisting of a post tensioned concrete wall connected rigidly to

the outer tank concrete slab with a roof constructed of reinforced concrete. Both the

inner and outer tanks shall be capable of holding the gross volume of cryogenic liquid

without loss of containment, liquid leakage or uncontrolled vapor release.

1.2 Technical Requirements

The following technical requirements are applicable to the design of the LNG storage

tanks and associated foundations.

1. Surface and sub-surface site preparation shall be in accordance with the sitespecific geotechnical investigation. Contractor will specify the requirements for

a foundation heating system which, if required, shall be fully redundant.

2. A 9% nickel steel open top inner tank to contain the LNG.

3. A reinforced concrete outer tank consisting of a post tensioned concrete wallconnected rigidly to the outer tank concrete bottom, with a roof constructed of

reinforced concrete. The inside of the concrete outer tank shall be lined with a

carbon steel vapor barrier.

4. A 9% nickel steel Secondary Bottom and 9% nickel steel insulated ThermalCorner Protection (TCP) are required and will be linked together. The

Secondary Bottom shall be placed above the lower system of Cellular Glass

bottom insulation.

5. A carbon steel roof liner, which forms an integral structure with the reinforced

concrete roof.

6. A suspended inner deck, supported by hangers from the concrete roof and roof

liner. The suspended deck shall be made of aluminum.

7. A tank insulation system including insulation under the inner tank bottom

(below the secondary bottom, and between the secondary bottom and the inner

tank bottom), insulation in the annular space between the 9% Ni steel inner tank

shell and the concrete outer tank, and insulation on top of the suspended inner

deck.


6/103


8. In-tank pump columns including pump lifting mechanisms, cables (includingelectrical power supply and instrumentation) from the top of the column to the

pump, and junction boxes located at the top of the columns, and internal piping.

The pumps shall be provided by others.

9. Platform, staircase, stairs, walkways, caged ladders, monorails, cranes, handrails

as further detailed within this specification.

10.Instrumentation for level, pressure and temperature monitoring, leak/gas

detection, cooldown control, density monitoring and any other instrumentation

specified for supply by the Contractor.

11.Relief valves for pressure and vacuum protection.

12.A fire detection and control system for extinguishing the relief valve stack.

13.Design, supply and erection of all piping associated with the tank.

14.During detailed engineering design, the design of the piping systems on the tankwill be modeled to determine pipe loads that anchors must accommodate.

1.3 Codes and Industry Standards

The Full-Containment LNG Tanks shall be designed in accordance with the following

Codes and Industry Standards:

1.3.1 American Petroleum Institute (API)

API 620, 11th

Edition, February 2008, with Addendum 1, March 2009,

Design and Construction of Large, Welded, Low Pressure StorageTanks.

API 650, 11th

Edition, June 2007, with Addendum 1, November 2008,

Welded Tanks for Oil Storage.

API 2000- 5th

Edition, April 1998, Venting Atmospheric and Low

Pressure Storage Tanks.

API 2003, 6th

Edition, September 1998, Protection Against Ignitions

Arising Out of Static, Lightning and Stray Currents.

API - MPMS C2 S2B - Calibration of Upright Cylindrical Tanks by the

Optical Reference Line Method (R2002).


7/103


1.3.2 American Society of Mechanical Engineers (ASME)

ASME Boiler and Pressure Vessel Code, 2007 Edition, including all

mandatory addenda:

Section II Material Specifications

Part A Ferrous Materials

Part C Welding Rods, Electrodes, and Filler Metals

Section V Nondestructive Examination

Section VIII, Div. 1 Pressure Vessels, as applicable

Section IX Welding and Brazing Procedures, Welders,

Brazers, and Welding and Brazing Operators

ASME B31.3 with year 2006 Addenda, Process Piping.

1.3.3 American Concrete Institute (ACI)

ACI 318-2008, Building Code Requirements for Structural Concrete (ACI

318-08) and Commentary, for prestressed and reinforced concrete portions

of the tank.

ACI 373, 1997 Edition, Design and Construction of Circular Prestressed

Concrete Structures with Circumferential Tendons.

1.3.4 American Society of Civil Engineers (ASCE)

ASCE-7 2005 Minimum Design Loads for Buildings and Other

Structures.

1.3.5 American Institute of Steel Construction (AISC)

AISC Manual of Steel Construction, Allowable Stress Design, Ninth

Edition.

AISC 3rd Edition, January, 2003 Load and Resistance Factor Design

Manual of Steel Construction.

1.3.6 American Society for Testing and Materials (ASTM)

ASTM C549-81, Perlite Loose Fill Insulation (R1986).

ASTM C520-98, Standard Test Methods for Density of Granular Loose

Fill Insulations.


8/103


1.3.7 FEMA

FEMA 450: NEHRP Recommended Provisions and Commentary for Seismic

Regulations for New Buildings and Other Structures. 2003 Edition

1.3.7.1 FERC

Draft Seismic Design Guidelines and Data Submittal Requirements for LNG

Facilities dated January 23, 2007.

1.3.8 National Fire Protection Association (NFPA)

NFPA 59A-2001 and NFPA 59A-2006, Production, Storage and

Handling Of Liquefied Natural Gas (LNG).

NFPA 780-2000, Standard for Installation of Lightning Protection

Systems.

1.3.9 Perlite Institute (PI)

PI-201-77, Compacted Density.

1.3.10 Federation Internationale De La Precontrainte (FIP)

FIP-Recommendation, Acceptance and Application of Post-Tensioning

Systems 1981.

FIP-Recommendation, FIP Recommendations for the Approval, Supply

and Acceptance of Steels for Pre-stressing Tendons.


9/103


2 DESIGN REQUIREMENTS

2.1 Tank Design

2.1.1 General

The LNG storage tanks (T-201A/B) shall be full containment type tanks,

with a primary inner container and a secondary outer container. The tanks

shall be designed and constructed so that the self-supporting primary

container and the secondary container shall be capable of independently

containing the LNG. The primary container shall contain the LNG under

normal operating conditions. The secondary container shall be capable of

containing the LNG (110% capacity of inner tank and which shall be

demonstrated by calculation by Contractor) and of controlling the vapor

resulting from product leakage from the inner container. The insulated

tank shall be designed to store a net volume of 160,000 m3 (1,006,000

barrels) of LNG at a temperature of -270F and a maximum internal

pressure of 4.3 pounds per square inch gauge (psig).

The double-walled tank shall consist of:

A 9% nickel steel open top inner container;

A pre-stressed concrete outer container wall;

A reinforced concrete dome roof;

A reinforced concrete outer container bottom;

A friction pendulum isolation system;

A secondary tank bottom on a pile cap foundation; and

An insulated aluminum deck over the inner container suspended from

the roof.

The aluminum support deck shall be insulated on its top surface with

fiberglass blanket insulation material. The vapor pressure from the LNG

shall be equalized through ports in the suspended deck and contained by

the outer container. The internal design pressure of the outer container

roof shall be 4.3 psig.

The space between the inner container and the outer container shall be

filled with expanded Perlite that shall be compacted to reduce long term

settling of the insulation. The insulation shall allow the LNG to be stored

at a minimum temperature of -270F while maintaining the outer container

at near ambient temperature.


10/103


The insulation beneath the inner container shall be cellular glass load-

bearing insulation that shall support the weight of the inner container and

the LNG.

Contractor shall determine if a foundation heating system is required and,if so, the design shall provide full redundancy.

The outer container shall be lined on the inside with carbon steel plates.

This carbon steel liner shall serve as a barrier to moisture migration from

the atmosphere reaching the insulation inside the outer concrete. This

liner also forms the barrier to prevent vapor escaping from inside the tank

in normal operation.

There shall be no penetrations through the tank inner container or outer

container sidewall or tank bottom. All piping into and out of the tank

inner or outer containers shall enter from the top of the tank.

The inner container shall be designed and constructed in accordance with

the requirements of API Standard 620 Appendix Q. The tank shall meet

the requirements of NFPA 59A and 49 CFR Part 193.

Table2.1.1.1 LNG Tanks Basis of Design

Number of tanks 3

Net capacity of each inner container 160,000 m3

(1,006,000 bbl)

Maximum internal design pressure 4.3 psig

Minimum internal design pressure -0.073 psig

Operating pressure 0.5 to 3.7 psig

Design wind load 150 mph

Inner tank minimum design metal

temperature-270F

Corrosion Allowance of inner

container

None

Allowable Boiloff Rate 0.05% per day

2.1.2 Service Conditions

The inner and outer tank and associated foundation shall be designed for

all specified loading conditions/combinations which may occur during

construction, testing, commissioning, operation, maintenance and de-

commissioning of the tank.

The following specific design loading cases shall be taken into account:

Hydrotest of the inner tank to a height based on the hydrotest pressure

at the base of the inner tank being 1.25 times the maximum design


11/103


product pressure at the base of the inner tank. But, water level shall be

the maximum level that does not increase the tank foundation over that

required for product.

Normal operation of the tank containing LNG at maximum designproduct level.

The external pressure on the inner tank shell, exerted by the Perlite

insulation in the annular space, in particular for the situation of an

empty inner tank.

2.1.3 Wind Loads on Outer Tank

The outer container shall be designed to withstand a wind velocity of 150

mph in accordance with 49 CFR Part 193.2067.

Also, the seismic isolators shall be studied for wind loads according toASCE 7-05 Sec.17.2.4.2 requirements.

2.1.4 Earthquake

Seismic design of the inner and outer tank shall be in accordance with site

specific design criteria in addition to NFPA 59A. Seismic design spectra

used for calculation of earthquake load conditions shall be taken from the

seismic design response spectra contained in the site specific seismic

design basis. Seismic isolation systems shall be designed for the

recommended SSE ground motions provided in the site specific seismic

design basis report.

Seismic isolator may be used to reduce the seismic force to the LNG tank.

In that case, all design and construction shall be in accordance with the

requirements in ASCE 7-05 Chapter 17.

2.1.4.1 Inner Tank:

The inner tank shall be designed using the methods in API 620 Appendix L,

modified as appropriate to apply site specific Operating Base Earthquake

(OBE) and Safe Shutdown Earthquake (SSE) criteria as described in the

seismic design response spectra and as required by NFPA 59A. It shall be

assumed that the inner tank is filled with LNG to its maximum normaloperating level (which is not an overfill or alarm level). When designing for

the SSE condition, allowable stresses shall be determined in accordance with

NFPA-59A.


12/103


13/103


2.1.4.3.1 Damping:

Structural Damping factors shall be as follows,

OBE = 5%, SSE = 5% for the steel tank, and liquid sloshing = 0.5% for

the inner tank contents

OBE = 2%, SSE = 5% for the outer post tensioned concrete wall

OBE = 2%, SSE = 5% for the reinforced concrete roof and base slab

(Reference; Earthquake Engineering Research Institute (EERI)

publication, Earthquake Spectra and Design, by Newmark & Hall,

page 54, Table 3).

When seismic isolators are used and a model is developed for Finite

Element Analysis, the vertical model damping for the isolators may be

taken as 2% for OBE and SSE.

2.1.4.3.2 Soil Structure Interaction and Reduction Factors

Soil Structure Interaction (SSI) and/or flexibility of a pile foundation system,

analysis shall be performed per the requirements of NFPA 59A.

A Reduction factor (R) for the SSE from over-strength, or ductility, and/or

other phenomena may be used if justified by proper analysis.

The use of SSI damping ratios and reduction factors in addition to total

system damping is subject to approval of the Owner/EPC Contractor and

jurisdictional regulatory authorities.

In evaluating vertical earthquake loads using the response spectra approach,it shall be confirmed that the loads used in the static analysis are at least 80%

of the loads that would occur if soil-structure interaction is not accounted

for.

2.1.4.3.3 Sloshing:

Seismic slosh wave shell freeboard allowances shall be added to the NMLL

(Normal Maximum Liquid Level) to determine required inner tank shell

height. Calculate shell freeboard allowance including slosh wave per the

API 620 L.4.2.8 for OBE and L.4.3.2 for SSE.

For the SSE condition the SSE calculated slosh wave height may be added toNMLL without any extra allowance.

Alternative sloshing height calculation methods may be used providing the

calculated sloshing height is not less than 80% of the value required by these

provisions, subject to approval by Owner/EPC Contractor and jurisdictional

regulatory authorities.


14/103


The response acceleration for the sloshing mode shall be computed using the

horizontal seismic design spectra without consideration of the resultant of

two horizontal ground motion acceleration components.

2.1.4.4 Maximum allowable stresses for the inner tank design shall be in accordancewith API 620, Appendix Q.

An allowable stress strength increase factor which is based on operating

temperature properties of welded 9% nickel material at the component

location under consideration may be applied to the SSE seismic design case

and for OBE load combinations that include vertical acceleration

(hydrodynamic amplification) pressure components as shown below.

Operating temperature allowable stress data may be taken from ASME

Section VIII, Division 1/2, Part ULT, Table ULT-23 for Welded

Construction.

Allowable Table ULT-23 stress values in tension are factored as

follows:

Table ULT-23 value x 3.5*/3.0**x (4/3)***

*ASME Section VIII, Appendix P, Table P-1 factor on tensile strength

**API 620-Q, Q.3.3.2 factor on tensile strength

***API 620, 5.5.6 permitted allowable stress increase factor for design loading, except as

permitted in Appendix L

2.1.4.4.1 Compliance with Requirements of Draft Seismic DesignGuidelines issued by FERC

In addition to the above requirements, the Contractor shall design the tanks

in accordance with the requirements of the draft "Seismic Design Guidelines

and Data Submittal Requirements for LNG Facilities" issued by FERC on

January 23, 2007. This includes submittal of the following documents as

required by the guidelines:

Tank and Containment Preliminary Design Drawings and Calculations

(sufficient to meet the requirements of Part II, Section 3.9 of the

guidelines); this includes preliminary structural calculations for the

tanks, based on seismic information to be provided by Oregon LNG.

A list of codes, standards, specifications, regulations, general design

criteria, and other industry standards used in the design, fabrication, and

construction, along with a list of the specific edition (per Part II, Section

3.13 of the guidelines); A study of the determination and acceptability of LNG liquid levels for

seismic forces and freeboard (per Part II, Section 3.15 of the guidelines).

2.1.5 Heat Leak

The total heat in-leak shall be such that the boiloff rate shall not exceed

0.05% of the gross tank contents per day.


15/103


2.1.6 Hazard Design Conditions

2.1.6.1 Heat Radiation/Fire Exposure

The outer tank roof and sidewalls shall be capable of withstanding fireexposure and heat radiation from a relief valve discharge fire with the relief

valves discharging at the maximum relieving rate.

2.1.6.2 LNG Spill Conditions

In addition to the specified service loading, the post-tensioned concrete tank

wall and its connection to the foundation shall be designed to contain LNG

in the annular space. The outer tank shall be capable of containing 110% of

the full inner tank contents and Contractor shall provide calculations

confirming this. Such calculations will provide data substantiating

assumptions made for the volume taken up by insulating materials (e.g.,

Perlite and fiberglass) in the annular space.

The temperature gradient shall also be analyzed during detailed design for

critical steady state spill levels. Since the annular space will fill gradually,

there is no specified leakage rate. Note that NFPA-59A requires that the

impounding system (the outer concrete tank wall and bottom) be designed to

withstand an OBE by holding the volume V, which is the full inner tank

contents. After an OBE, there shall be no loss of containment capability.

2.1.6.3 Combination of Loading Conditions

The inner 9% nickel container and outer post-tensioned concrete tank shall

be designed for all service and hazard loading conditions.

2.1.6.4 Impact Loads

During detailed design, the maximum acceptable projectile impact load for

outer tank wall and roof shall be calculated.

2.1.7 Hazard Protection Requirements

2.1.7.1 LNG Spill Protection

Spill protection of the LNG storage tank roof shall be designed to comply

with the requirements of NFPA 59A. The protection shall extend over theedge of the roof dome. Any structural carbon steel on the roof shall be

protected from potential spills.

2.1.7.2 Relief Valve Discharge Lines

Tailpipes of relief valves discharging to atmosphere shall be provided with a

dry chemical snuffing system for the RV discharge pipes to extinguish

accidental fire during pressure venting.


16/103


2.2 Concrete Outer Tank Design

2.2.1 Design Requirements

The outer tank shall be designed to contain the product pressure at ambienttemperature and shall contain the insulation system.

The outer tank shall be designed for the following conditions:

The specified maximum and minimum pressures of 4.3 psig and -1.17

ounce per square inch (-0.073 psig), respectively.

The specified wind design speed of 150 mph as specified in 49 CFR

Part 193, Section 2067.

Seismic loads in accordance with NFPA 59A and the site specific

seismic design basis.

Internal pressure imposed by insulation loads.

Sensitive analysis of soil stiffness shall be incorporated in dynamic

analysis according to ASCE 7-05 Sec.12.13.3.

Roof and platform dead loads shall be in accordance with the following:

Roof live load (to be determined during detailed design) applied to the

entire projected area of the roof and combined with the specified

external pressure of 1.17 ounce per square inch (-0.073 psig) and the

platform global live load.

Platform live load (to be determined during detailed design) combinedwith a crane handling live load that shall be determined during detailed

design and external pressure load of 0.5 ounce per square inch. Roof

live load shall not be combined with the platform live load.

The suspended deck shall be composed of B209-5083-O aluminum. The

suspended deck hangers shall be Type 304 stainless steel.

2.2.1.1 Tank Bottom

The LNG Storage Tank foundation design shall be based on the detailed site

specific geotechnical investigations and seismic design basis. For the access

for inspection and replacement of isolators, required by ASCE 7-05

Sec.17.2.4.8.a, there are 4 spacebetween the outer container bottom and the

secondary tank bottom and isolators shall be fixed by bolts/nuts.

2.2.1.2 Tank Wall

The wall shall be a monolithic connection to the foundation. A monolithic

connection shall also be made between the wall and concrete roof.


17/103


The outer tank wall shall be constructed of post-tensioned concrete. Pre

stressing shall be accomplished with an impermeable duct and tendon

system. Vertical post-tensioning (if used) shall be accomplished with a duct

and tendon system.

2.2.1.3 Tank Roof

The roof shall be spherical in shape, and made of reinforced concrete with an

interior steel vapor barrier (liner). The steel liner located on the inside of the

roof shall be used as formwork for concrete placement.

During construction, concrete may be poured in layers to restrict loading on

the liner. As part of the construction sequence, the construction contractor

shall demonstrate by analysis that the roof plates and framing are adequately

designed for non-symmetrical loading due to the concrete pouring sequence.

2.2.1.4 Ringbeam Under Inner Tank Shell

A concrete ringbeam shall be installed under the inner tank shell. The

ringbeam shall be designed such that the shell loads are properly distributed

onto the bottom insulation under the ringbeam. Horizontal forces, caused by

possible movements of the annular plate, shall be determined during detailed

design.

The concrete ringbeam shall be reinforced with cryogenic rebar or

carbon steel rebar if alternative deigned in accordance with NFPA

59A.

2.2.2 Concrete Tank Design Code

The design of the prestressed concrete outer tank, and reinforced concrete

roof and base slab (pile cap) shall be in accordance with ACI 318.

2.2.3 Design/Analysis

2.2.3.1 Tank Wall Design Method

The foundation and prestressed concrete wall shall be designed for the

following two states:

Serviceability Limit States (SLS), Includes construction, normaloperating, and spill load conditions. This design state shall be utilized to

determine concrete crack widths for construction and normal operating

loads, and liquid tightness of the wall for the spill condition. All

material and load factors shall be taken as 1.0.

Ultimate Limit States (ULS). Includes all load conditions. This design

state shall be utilized to determine concrete section adequacy per the

strength requirements of ACI 318. ACI 318 designs consider the material


18/103


strength reduction factors (Table 2.2.3 1) and the load factors (Table

2.2.3 2)

All appropriate load cases and combinations shall be incorporated in the

design of the concrete outer tank during the detailed design phase. Uponcompletion of detailed design a detailed loading summary table, such as

shown in Table 2.2.3 3, shall be prepared to cover all phases of the tank

lifetime.

Seismic load combinations shall consider all possible combinations of the

sum of 100% of the effect in one direction (horizontal or vertical) and 40%

of the effect in the other direction.

Adverse and beneficial effects of the pre-stress and shrinkage loads shall be

considered for construction, maintenance and normal operating load

conditions.

In all cases the detailed design shall take into account the effects of the

loads, shrinkage strains, and prestressing forces during and after tensioning,

and conditions of edge restraint at the wall junctions with the foundation and

roof.

2.2.3.2 ACI 318 Strength Design ULS Material Strength Reduction Factors

Table 2.2.3-1 ACI 318 Strength Design ULS Material Strength Reduction Factors

Concrete Strength ParameterNormal, Test, andOBE Eq Conditions

EmergencyConditions

Flexure without axial load 0.90 1.00Axial tension w/flexure 0.90 1.00

Axial compression w/flexure 0.70 1.00

Shear and torsion 0.85 1.00

Bearing on concrete 0.70 1.00


19/103


2.2.3.3 ACI 318 Strength Design ULS Load Combinations and Load Factors

Table 2.2.3-2 ACI 318 Strength Design ULS Load Combinations and Load Factors

Load Component and Load Factor

Load Combination

Dead

Prestress

Shrinkage

Test

Loads

Operating

Loads

RoofLive

Load

OBE

Seismic

Loads

SSE

Seismic

Loads

Spill

Condition

Loads

Construction or Maintenance C, M 1.4 1.2 1.4 -- -- 1.7 -- -- --

Test T 1.4 1.2 -- 1.3 -- -- -- -- --

Uplift Case 0.9 1.0 -- 1.3 -- -- -- -- --

Operating (Empty) O1 1.4 1.2 1.0 -- 1.6 1.7 -- -- --

Uplift Case 0.9 1.0 1.0 -- 1.6 -- -- -- --

Operating (Full) O2 1.4 1.2 1.0 -- 1.6 1.7 -- -- --Uplift Case 0.9 1.0 1.0 -- 1.6 -- -- -- --

Operating (Empty)+OBE EQ O3 1.05 1.05 1.0 -- 1.28 -- 1.4 -- --

Uplift Case 0.9 1.0 1.0 -- 1.2 -- 1.3 -- --

Operating (Full)+OBE EQ O4 1.05 1.05 1.0 -- 1.28 -- 1.4 -- --

Uplift Case 0.9 1.0 1.0 -- 1.2 -- 1.3 -- --

Operating (Empty)+SSE EQ U1 1.0 1.0 1.0 -- 1.0 -- -- 1.0 --

Operating (Full)+SSE EQ U2 1.0 1.0 1.0 -- 1.0 -- -- 1.0 --

Spill Condition U3 1.0 1.0 1.0 -- -- -- -- -- 1.0

Spill + OBE U4 1.0 1.0 1.0 -- -- -- 1.0 -- 1.0

2.2.3.4 Tank Modeling and Analysis

During detailed design, the concrete tank shall be analyzed for service and

emergency loads using a combination of 2D and 3D finite element modeling

and analysis techniques. The analysis model shall also include both heat

transfer and nonlinear thermal effects. The overall model shall include the

foundation stiffness effects (soil-structure interaction), the concrete base slab

(or pile cap), the concrete wall, the outer tank roof, the inner tank, the

suspended deck, the insulation system and allowance for piping and tank top

structures.

The following specific points shall as a minimum be considered during

detailed design:


20/103


Table 2.2.3-3Tank Modeling and Analysis

Analysis or Model Description

Heat Transfer Heat transfer analysis shall be performed to determine

the temperature distributions for both service and spillloading conditions. The results shall be used withcoincident mechanical loading for nonlinear stressanalysis.

Stress Analysis The stress analysis shall take into account the nonlinearbehavior of the concrete; i.e., reduced stiffness due tocracking.

Foundation Stiffness The stiffness effects of the foundation shall be includedusing spring elements.

Preload The preload effects due to post-tensioning (includingrelaxation), creep and shrinkage of the concrete shallalso be considered.

Differential Settlement Predicted edge to center differential settlements shallbe included as normal service loads.

2.2.3.5 Acceptance Criteria

The following acceptance criteria for calculations are required for load

conditions as applicable:

Table 2.2.3-4 Acceptance Criteria

Criteria Description

Strength Criteria Concrete strength criteria per ACI 318 shall besatisfied for all load conditions using the material andload factors in Tables 2.2.3.2 and 2.2.3.3, asapplicable. For shear strength evaluations of concretecross sections with significant tension, ACI 318provisions may be applied.

Crack Control For construction and normal operating conditions,concrete crack widths in the wall shall be limited to 0.2mm for prestressed zones. Crack widths in the slaband concrete roof shall be limited to 0.3 mm.

Wall Liquid Tightness

(Applies to Inner Tank

Spill Condition Only)

Above the TCP, a compression zone shall bemaintained in the wall of at least 10%, but not less than80 mm. In addition, an average compressive stress of

1 MPa [150 psi] shall be maintained in thecompression zone.


21/103


2.3 Component Design

2.3.1 General

The following components shall be designed, fabricated, supplied, erected,inspected and tested in accordance with the standards, guidelines,

specifications, documents specified herein and additional requirements as

given in this specification. Components include: the inner tank, secondary

bottom plus the thermal corner protection (TCP), suspended deck, bottom

liner, wall liner, and the roof liner.

2.3.2 Inner Tank

2.3.2.1 Allowable Stress

Maximum allowable stresses for the inner tank design shall be in accordance

with API 620, Appendix Q.

2.3.2.2 Welding

Welding of the inner tank bottom annular plates shall comply with API 620

Q 7.1.1. Shell to annular plate welds shall conform to API 620 sections

3.9.5 and Q 7.1.1 requirements.

2.3.2.3 Temporary Access

Temporary access through the inner tank shell, using door sheets or

manways shall be permitted.

2.3.2.4 Welded Attachments

All permanent structural attachments welded directly to the 9% nickel steel

inner tank shall be of the same material as that to which it shall be welded.

Contractor shall prepare an alloy verification procedure.

2.3.2.5 Plate Thickness

Minimum plate thickness shall be calculated per API 620.

2.3.2.6 Design Temperature

The minimum design temperature shall be -270F.


22/103


2.3.3 Liners (Vapor Barriers)

2.3.3.1 Bottom Liner

A vapor tight bottom liner connected to the wall liner shall be provided. Thedesign shall account for stresses, strains and thermal considerations. The

bottom liner plates shall be lap welded.

2.3.3.2 Wall Liner

A vapor tight wall liner connected to the bottom liner, the TCP embed plate,

and the roof liner shall be provided.

2.3.3.3 Roof Liner

A carbon steel roof liner shall be installed at the inside face of the concrete

roof. The liner shall function as an integral part of the concrete roof andmay be used as formwork for the concrete during construction.

2.3.4 Suspended Deck

2.3.4.1 Vents

The suspended deck shall be provided with open vents to ensure pressure

equilibrium on both sides of the suspended deck.

2.3.4.2 Plate Design

The suspended deck shall be aluminum (B2095083O AL) and the

suspended deck hangers shall be Type 304 Stainless Steel.

2.3.5 Secondary Bottom and Thermal Corner Protection (TCP)

2.3.5.1 General

The secondary bottom shall consist of ASTM A 553 Type 1 lap-welded

inner bottom plates and annular plates at the perimeter.

2.3.6 Piping and Roof Nozzles

2.3.6.1 General

The tank internal piping shall enter the tank through the concrete outer tank

roof. No penetrations through the outer wall or inner tank shell shall be

permitted. All roof nozzles shall have vertical axes, with the flange bolt

holes straddling the north-south centerline of the nozzle.


23/103


External flanges up to 24 inches NPS shall conform to ASME B16.5.

Flanges larger than NPS 24 shall conform to ASME B16.47. The design

shall satisfy the requirements of API 620, paragraph 5.20.2.

Contractor shall provide a listing of nozzle penetrations and also drawingsthat illustrate the location of the nozzle penetrations.

2.3.6.2 Pump Columns

Each LNG Storage Tank shall be equipped with three in-tank pump columns.

The size of the columns will be provided separately. The pump columns

shall be fully installed and include electrical supplies, supports,

instrumentation, piping, etc., for a complete system. The columns shall be

designed to ASME pressure vessel codes, as they operate at higher pressures

than the LNG storage tank.

2.3.6.3 Liquid Inlet-Top Fill

A liquid inlet with a roof nozzle for top filling the LNG Storage Tank shall

be provided.

2.3.6.4 Liquid Inlet-Bottom Fill

A liquid inlet with a roof nozzle for bottom filling the LNG Storage Tank

shall be provided.

2.3.6.5 Vapor Outlets

Liquid entrainment shall be avoided in the vapor outlets and relief valves by

positioning the vapor outlets away from the deflector plate and standpipe of

the liquid inlet line.

2.3.6.6 Purge/Venting System

The purge/venting system shall include means for both inerting all areas of

the tank using nitrogen and pistoning out nitrogen from the inner tank with

introduced natural gas prior to cooldown.

2.3.7 Structural Steel

Design of steel structural components shall be in accordance with the USA

AISC Steel Construction Manual.


24/103


3 CONSTRUCTION REQUIREMENTS

3.1 Materials Requirements

3.1.1 Concrete Outer Tank

3.1.1.1 Concrete

Concrete shall be per ACI 318 and shall have 28 day specified compressive

strengths of 27.6 MPa [4000 psi] for reinforced concrete components, and

41.4 MPa [6000 psi] for post-tensioned components, or higher. Blinding

concrete used as a mud mat shall be C20. Concrete mix design and

production and testing shall comply with ACI 318.

3.1.1.2 Steel

All reinforcement, excluding cryogenic reinforcing steel, shall be uncoated

deformed bars conforming to the requirements of ASTM A615 Grade 60 or

alternatively BS 4449 Grade 460. Cryogenic reinforcing steel shall also be

uncoated, but marked in a way as to be clearly distinguishable from non-

cryogenic reinforcing steel.

3.1.2 Inner Tank, Secondary Bottom, and TCP Materials

3.1.2.1 Plate

All inner tank primary component plate materials shall comply with ASTM

A553 Type 1. ASTM A553 Type 1 shall also have restricted sulfur (max

0.005%) and restricted phosphorus (max 0.010%).

The following additional requirements shall be prepared during preparation

for construction:

A reference list of proposed material suppliers giving details of their

experience in the supply of 9% nickel materials.

Before leaving the steel mill, the four corners of all 9% nickel steel

plates shall be checked using a gauss meter. Residual magnetism shall

not exceed 50 Gauss.

For the quenched and tempered grade of 9% nickel steel, a heat

treatment in accordance with the steel manufacturers recommendationis required if it has been cold deformed between 3% and 5%. Cold

deformation shall not exceed 5%.

3.1.2.2 Internal Piping Components

Material for piping, tubing, forging, and bolting shall conform with the

requirements of Appendix Q of API 620 (Table Q-1).


25/103


3.1.2.3 Secondary Bottom and TCP Components

The secondary bottom and thermal corner protection shall be made of ASTM

A553 Type 1. Material requirements for this A553 Type 1 shall comply with

the requirements of API 620 Appendix Q for primary component material.

3.1.3 Bottom Liner, Wall Liner, and Roof Liner (Vapor Barriers)

3.1.3.1 Plate

The outer bottom plate the steel plate vapor barriers on the concrete wall and

their embedment materials, and all roof plate material shall be carbon steel

conforming to API 620 Appendix R-4 requirements. Structural framework

under the roof plates used for roof plate erection and to provide support

during concrete pouring shall be ASTM A36, A572, or equivalent. This

framework shall be welded to the roof plates.

3.1.3.2 Welding

Welding procedures shall comply with API 620, Appendix R.6 requirements

for components that do not qualify as secondary components for all

conditions or applicable combinations of normal and emergency loads.

Contractor shall prepare an alloy verification procedure that includes details

for welding procedures on alloy materials.

3.1.4 Suspended Deck

3.1.4.1 Deck Materials

The suspended deck shall be ASTM B209 aluminum alloy 5083-O.

3.1.4.2 Hangers

Suspension rods/hangers shall be stainless steel Type 304.

3.1.4.3 Testing Procedure - Materials

All 9% nickel materials shall be tested in accordance with the requirements

of API 620, Q.2.2.2, Q.2.2.3 and Q.2.2.4 and in accordance with the alloy

verification procedure prepared by Contractor. Testing methods and controls

shall comply with ASTM A370.

3.1.4.4 Welded Joints

Impact testing procedure requirements shall be in accordance with API 620,

Q.6.2.


26/103


27/103


shall be prepared for installation of the bottom, the cellular glass insulation

and the concrete ringbeam.

A mouse-hole shall be made in the horizontal butt-welds of the inner tank

stiffeners in accordance with Figure Q-1 of API 620 to allow liquid tocompletely drain.

3.2.2 Welding Procedures

3.2.2.1 General

Welding shall be in accordance with API 620 and in accordance with an

alloy verification procedure that is to be prepared by Contractor. All vertical

and horizontal seams of the inner tank shell may be welded manually, semi-

automatically, or by machine.

3.2.2.2 Documentation

All welding procedure specifications (WPS) and procedure qualification

records (PQR) to be used for the construction of the tanks, including those

for prefabrication, repair, tack and attachment welds, shall be approved prior

to the work being performed.

3.2.2.3 Welding and NDE Maps

Welding procedures used for all welds and the radiographic or ultrasonic

inspection procedure shall be clearly indicated in construction documents.

3.2.2.4 Post Hydrotest

No welding shall be permitted on the inner tank after completion of the

hydrotest.

3.2.3 Welding Consumables

3.2.3.1 General

Filler metal for 9% nickel welding shall conform to AWS SFA-5.11 and/or

SFA-5.14.

3.2.3.2 Code Compliance

Each lot or heat of the austenitic stainless steel welding (filler) materials

shall meet the requirements of ASME Section VIII, Division 1, UHA-51 (e)

and (f). All welding procedures shall be qualified as required by API 620.

3.2.4 Welding Qualification and Identification


28/103


All welding shall be performed by qualified welders, tested and certified to

each process including fit up. Tank welding shall be performed in

accordance with the requirements of API 620.


29/103


3.2.5 Inspection

3.2.5.1 Radiographic Inspection

The radiographic techniques, acceptance criteria and extent (except whereNFPA 59A applies) for the inner tank shall be in accordance with API 620.

Radiographic inspection of butt welds in plates shall be in accordance with

the requirements of API 620, Q.7.6 and NFPA 59A.

3.2.5.2 Liquid Penetrant Examination

Liquid penetrant examination for the inner tank shall be carried out in

accordance with API 620. The secondary bottom annular plates shall have

the same liquid penetrant examination requirements as the inner bottom

annular plates. TCP welds shall have the root pass and the final weld

examined by liquid penetrant. The weld between the secondary bottom andthe TCP shall have the root pass and the final weld examined by liquid

penetrant.

3.2.5.3 Solution Film Testing

Vacuum box testing shall be carried out in accordance with API 620.

All welds of the roof liner plates shall be vacuum box tested before concrete

placement on the roof. Vacuum box testing of the bottom slab and side wall

vapor barrier welds shall be completed before covering up the plates. Welds

between liner components (e.g. wall liner to bottom liner) shall be vacuum

box tested.

All secondary bottom, TCP and outer bottom vapor barrier plate welds shall

be vacuum box tested.

Inner tank bottom plate welds shall be vacuum box tested before and after

hydrostatic testing.

The inner tank shell-to-bottom Tee joint annular space shall be pressure

tested for leakage using a solution film in accordance with API 620,

Paragraph Q.8.2.2.

3.3 Insulation Systems

3.3.1 Tank Bottom Insulation System

The tank bottom shall be insulated with cellular glass block insulation,

which is a load bearing insulation designed to support the tank and product

weight.


30/103


A concrete bearing ring shall be located under the inner tank shell to

distribute the shell loads into the underlying bottom insulation.

The cellular glass blocks shall be located between the outer bottom and inner

bottom and laid on a concrete leveling course on top of the outer tankbottom. Inter-leaving material shall be placed over the concrete leveling

course and between bottom insulation layers to fully develop the strength of

the load bearing bottom insulation.

A layer of dry sand shall be placed over the cellular glass block bottom

insulation prior to installation of the inner tank bottom.

3.3.2 Tank Wall Insulation

The annular space between the inner and outer tanks shall be filled with

loose fill expanded Perlite and resilient glass wool blanket insulation. The

following parameters are applicable to the Perlite that shall be used:

Perlite density is between 3 lb/ft3and 5 lb/ft

3

Thermal conductivity not greater than 0.305 Btu-in/hr-ft2at 32F

Moisture content limit 0.5% maximum

An important consideration for the installation of the Perlite in the annular

space is the Perlite vibration after filling. Vibration will be used to settle

the Perlite to eliminate potential voids or pockets in the Perlite volume and

maximize the insulating value of the system. The design of the LNG

Storage Tank shall include a reservoir of Perlite that shall be placed at the

top of the annular space to compensate for future, long-term settlement of

the Perlite.

3.3.3 Suspended Deck Insulation

The outer tank roof shall support a suspended deck above the top of the

inner tank.

Roof deck plates shall be fully seal welded before the beginning of any

glass fiber blanket installation. If a formed plate (trough system) is used,

then lapping and fixing details must completely seal against insulation

leakage.

Identification markers shall be provided to gauge the finished level of

blanket insulation by means of easily identifiable colored tape or an

acceptable alternative at all roof hangers and deck penetration collars.


31/103


At each penetration through the suspended deck there shall be a flexible

shroud fitted to prevent fiberglass material from falling into the inner

container.

3.3.4 Insulation of Nozzles and Internal Piping

Nozzle connections with internal piping located in the LNG Storage Tank

dome space shall be provided with thermal distance pieces to allow the

line temperature to warm to near ambient temperature at the point of

penetration into the roof. The thermal distance pieces shall be insulated

with fiberglass blanket to provide insulation between the cold line and

distance piece and also to provide a convection stop. The outside

insulation layer can be bonded foil or open weave glass fabric and shall be

specified during detailed design.

3.3.5 Protection of Insulation

3.3.5.1 Storage

All insulation materials shall be stored in an enclosed and ventilated dry

place and shall be protected against water from the time they are dispatched

to site until they are required for installation.

3.3.5.2 Installation

Adequate provisions shall be made to ensure the complete absence of

moisture in the insulation and in the zones where insulation is to be installed.

The methods proposed for ensuring dryness shall be specified duringdetailed design.


32/103


4 ANCILLARY EQUIPMENT REQUIREMENTS

4.1 Accessories

4.1.1 Roof Platform

The pump platform shall be sized to provide sufficient working space

around the pump wells and piping.

4.1.2 Access to Platform and Roof

4.1.2.1 Stairways, Ladders and Tank Access

A stairway with intermediate landings attached to the outer tank shall be

provided to access the roof platforms. This staircase shall provide access

from the platform to the tank roof.

An emergency escape ladder shall also be provided at a location that is

opposite the main roof platform and accessed via a roof walkway. This shall

be of the caged ladder type with side stepping platforms. It shall be attached

to and supported by the outer tank.

Platforms shall be provided on the tank roof for access to the pump columns,

nozzles and instrumentation. Stairways with handrails shall provide access

to the top of the roof.

4.1.2.2 Internal Tank Ladder

Internal tank access shall be provided through roof man-ways. A stairway

shall be provided to the inner tank bottom.

4.1.2.3 Walkways and Handrails

Handrails for exterior stairways and platforms shall be galvanized.

4.1.3 Cranes/Hoists

The pump handling system shall consist of a monorail type hoist.

Explosion proof electric motors and components shall be provided to meet

hazardous rating requirements.

4.1.4 Supports

During detailed design, specifications for the design and supply of

reinforced pads, embedments and sleepers for attachment of pipe supports,

electrical/ instrument cable, platform, and handrail supports shall be

prepared.


33/103


4.1.5 Lighting

General tank lighting systems shall be provided. Lighting levels shall be

as defined in Illuminating Engineering Society of North America (IESNA)

recommendation.

Emergency escape lighting shall be provided using self contained battery

fittings.

A dual aircraft warning light shall be provided at the highest point on the

tank in accordance with FAA directives. Outdoor convenience receptacles

shall be provided at the tank with a minimum of two at the top platform.

The electrical system shall be designed in accordance with the National

Electrical Code (NEC). To the greatest extent possible, all lighting shall

be directed inward to the Terminal and shall consist of low yellow lighting.

4.2 External Piping

In case of earthquake, large displacement of LNG storage tank in the horizontal and

vertical directions may be generated due to the lateral motion of the isolators. For the

layout design and the strength study of the LNG storage tank external piping, the

displacement of LNG storage tank shall be considered.

Differential settlement due to ground deformation shall be considered also.

4.3 Pressure and Vacuum Relief Systems

The tank shall be ultimately protected against over-pressure and under-pressure by the

provision of pressure and vacuum relief valves.

4.3.1.1 Over-Pressure Protection

Over-pressure protection shall be provided by spring-loaded remote sensing

pilot operated relief valves. These valves relieve from the inner tank to

atmosphere, ensuring that cold gas is not drawn into the dome space in a

relief event. When the relief valves lift, cold LNG vapor is discharged to

atmosphere.

The required relieving rate is dependent on a number of factors, but sizing

shall be based on the NFPA 59A Section 4.7.3.2 (2001 ed.) requirement that:

The minimumpressure relieving capacity in kg/hr (lb/hr) shall not be less

than 3 percent of full tank contents in 24 hours. Also, NFPA 59A 4.7.2.1

(2001 ed.) requires: Sufficient pressure and vacuum relief valves shall be

installed on the LNG container to allow each valve to be isolated

individually for testing or maintenance while maintaining the full relieving


34/103


capacities required. The number of relief valves shall be determined

accordingly. Each valve shall be provided with an inlet isolation valve.

Valve discharges shall be independently routed to atmosphere.

Each relief valve shall discharge to atmosphere locally at a safe location viaa vertical tailpipe. NFPA 59A Section 4.7.2 (2001 ed.) requires: Relief

devices shall communicate directly with the atmosphere. A safe location is

considered to be a minimum of 3m from platforms and walkways and 5m

above local grade (tank roof).

To protect against the ingress of foreign matter, the tailpipe shall be

provided with a coarse screen; and to protect against rain ingress a small-

bore piped low point drain shall be provided. To protect against snow and

ice, the tailpipe shall be provided with appropriate winterization.

4.3.1.2 Under-Pressure Protection

Under-pressure protection shall be provided by weight-loaded, pallet-type

vacuum relief valves. These valves relieve from atmosphere to the dome

space, ensuring, insofar as possible, that moist air is not drawn into the inner

tank in a relief event. When the relief valves lift, air is drawn into the tank

from the atmosphere.

Vacuum relief valves shall be designed in accordance with the requirements

of NFPA 59A Section 4.7.2.1 (2001 ed.), which requires that: Sufficient

pressure and vacuum relief valves shall be installed on the LNG container to

allow each valve to be isolated individually for testing or maintenance while

maintaining the full relieving capacities required. Therefore, sufficient

redundancy shall be installed to provide the total required relief capacity.Each valve shall be provided with a dedicated tank-side isolation valve.

Valve inlets will draw independently from the atmosphere.

To protect against the ingress of foreign matter, the inlet of each vacuum

relief valve shall be provided with a coarse screen; and to protect against

rain and snow ingress a protective cowl shall be provided. To protect

against ice, each valve shall be provided with winterization.

A monorail crane shall be positioned for relief valve service.

4.4 Electrical

4.4.1 LNG Tank Grounding (Earthing)

The tank shall be provided with a grounding system. The grounding grid

shall consist of stranded copper wire. Grounding electrodes are spaced

such that the overall grounding resistance shall not exceed 10 Ohms.


35/103


4.4.2 Lightning Protection

During detailed design, a complete lightning protection system shall be

specified. The system shall be comprised of air terminals, bonding

conductors and down conductors on each tank. The down connectors shallterminate at ground busses, which shall be connected directly to the

grounding grid ring with insulated grounding cable. The lightning

protection system shall be designed in accordance with API 2003 and

NFPA 780.

4.4.3 Foundation Heating System

Contractor shall determine the need for a foundation heating system to

prevent frost heave of the subsoil. If required, the foundation heating

system shall consist of a constant wattage cable system installed in parallel

galvanized steel conduits. The conduits shall be spaced at appropriateintervals to provide an even heating layer for a designed 100% surplus

heating system (available heat versus required heat). The system shall be

fully redundant and include: Power Controller, Temperature

Controller/Monitor, Temperature Sensors, Heating Cable, Junction Boxes,

Marshalling Cabinets and all cables necessary to provide a complete

system from the marshalling panels to the under tank components.

Foundation heating system monitoring, alarm and status data shall be

available through the Terminal DCS system.

4.5 Instrumentation

Contractor shall provide drawings and specifications for the LNG storage tank

instrumentation requirements. The following is a summary of the instrumentation

systems that shall be installed.

4.5.1.1 Cool-Down Sensors

To assist in cool-down and subsequent temperature measurement during

commissioning and decommissioning of the tank, resistance temperature

detector (RTD) elements shall be installed. All cabling from these RTDs

shall be terminated at a junction box external to the tank roof.

4.5.1.2 Temperature Sensors

RTD elements shall be placed on the inner shell, the inner container bottom

and on the suspended deck. These temperature elements shall be used to

monitor the tank temperature during cool-down.

RTDs shall be located in the tank bottom annular space for leak detection

and they shall be spaced equally around the circumference of the tank.


36/103


37/103


4.5.1.8 Translation and Rotation Movement Indicators

Contractor shall provide drawings that illustrate details of translation and

movement indicators that shall be designed for the inner tank.

4.6 Painting

4.6.1 Sealing Concrete Outer Surfaces

A specification for sealing concrete outer surfaces shall be prepared during

detailed design. One option to make the outside surface of the concrete

roof and concrete walls water-tight will be by means of a coating or sealer.

In this option, the surface will be sweep-blasted and then coated with a

light-colored epoxy-based paint. A second option may be to use concrete

additives such as Blast Furnace Slag Cement (BFSC), Silica Fume, or Fly

Ash cement that may eliminate the need for external coatings on theconcrete roof and walls.

4.6.2 Internal Metal Surfaces

The internal surfaces of carbon steel liners (bottom, wall, and roof) shall

be grit blasted and shop primed, except that a weld strip of approximately

50 mm may be left unprimed. The 9% nickel steel shall be grit blasted

only, or grit blasted and shop primed (except for a 50 mm, strip which may

be left unprimed) only if the primer is suitable for service at cryogenic

temperature.

4.6.3 General Requirements

Carbon steel stairs, platforms and pipe supports shall be hot dip galvanized.

Stainless steel, aluminum and galvanized surfaces shall not be painted.

4.6.4 Insulated or Fireproofed Surfaces

All external metal surfaces including insulated or fire proofed surfaces,

equipment, and piping (excluding stainless steel) shall be coated or painted.

Specifications for coating and painting shall be prepared during detailed

design.


38/103


5 COMMISSIONING REQUIREMENTS

5.1 Hydrostatic/Pneumatic Testing

5.1.1 Hydrotesting of Inner Tank

Hydrostatic testing of the inner container shall be in accordance with API

620 Appendix Q.8.

Contractor shall prepare hydrostatic test procedures that, in addition to the

actual hydrostatic test procedure shall also include the following:

Requirements for water quality, including sampling, testing and

treatment required to determine suitability prior to use.

Rates at which water is to be pumped into the LNG storage tank.

Note: water shall be pumped into the tank at rates not exceeding thelimitation set by API 620.

Limits for the period of time that water used for hydrostatic testing

shall remain within the tank to prevent corrosion and biological

fouling and shall include any requirements for treatment.

Requirements for re-using water for hydrostatic testing of additional

LNG Storage Tanks.

Requirements for the disposal of water upon completion of the

hydrostatic testing and any treatment prior to discharge.

5.1.1.1 Pressure and Vacuum Testing

A pneumatic test of the outer container shall be performed in accordance

with API 620 Appendix Q.8.

Pump columns shall be tested in accordance with ASME B31.3, Chapter VI,

345.6 - Hydrostatic-Pneumatic Leak Test. The design pressure shall be the

pump discharge pressure at shutoff. Prior to the tank hydrotest, the pump

wells shall be emptied and sealed.

5.1.1.2 Settlement Monitoring

A settlement monitoring system shall be provided to measure and record

inner and outer container movements during construction and hydro test.

Contractor shall provide details of the survey/reference points and their

location around the outer edge of the tank foundation. In addition,

settlement of the inner container shall be monitored at the same reference

points used for the tank foundation/outer container. Measurements shall be

made from the inner container annular plate. Also, a reference point shall be


39/103


established on the outer container wall to measure differential settlement

between inner and outer containers. Differential settlement and tilting of the

foundation shall be monitored and recorded.

During the hydro test, settlements, rotation and foundation tilting shall bemonitored at approximately each 16-foot increment of water fill height.

Measurements shall also be recorded when the tank is emptied. During

construction, the settlement of the foundation and inner container shall be

monitored on a weekly basis.

Contractor shall prepare a detailed civil monitoring specification.

5.2 Calibration

Prior to mechanical completion of the LNG storage tank, the construction contractor

shall arrange for calibration of the inner tank by a specialist organization in accordance

with the API Manual of Petroleum Management Standard, Chapter 2, Tank

Calibration, or other internationally accepted code. The construction contractor shall

supply gauge tables or equivalent calibration curves and equations, which relate the

actual tank volume under operating conditions and at various product levels to the

warm, measured, tank volume.

5.3 Purging

A detailed drying, purging and cooldown procedure shall be provided by the

construction contractor.


40/103

Oregon LNG Job No. 07902

Warrenton, Oregon

Public Appendices

Resource Report 13

18 CFR 380.12(o)

Appendix L.3


41/103

M L (A)

D 20JAN09 Revised based on client comment (Sec.2.2) TH - MH

C 28APR08 Revised based on client comment TH - MH

B 17JAN08 Revised based on client comment TH - MHA 11JAN08 Issued for Approval TH - MH

NO. DATE DESCRIPTION PREPD CHECKED APPROVE

CAUTIONTHIS DOCUMENT CONTAINSCONFIDENTIAL ANDPROPRIETARYINFORMATION OF IHICORPORATION.THE DOCUMENT ALWAYSREQUIRES PRIOR WRITTENCONSENT OF IHI FOR(1) ITS REPRODUCTION BY ANY

MEANS,(2) ITS DISCLOSURE TO A

THIRD PARTY,OR(3) ITS USE FOR ANY PURPOSE

OTHER THAN THOSE FORWHICH IT IS SUPPLIED.

JOB NO.

Electrical & Control Dept.

OREGON LNG FERC FILING PROJECT

TANK INSTRUMENTATION SPECIFICATION

CH-IV INTERNATIONAL


42/103

JOB NO

TABLE OF CONTENTS

1.0 INTRODUCTION ............................................................................................................3

2.0 TANK GAUGING SYSTEM AND OVERFILL PROTECTION .........................................3

3.0 TEMPERATURE MONITORING FOR LEAK DETECTION.............................................4

4.0 TEMPERATURE MONITORING FOR COOLDOWN......................................................4

5.0 TEMPERATURE MONITORING FOR BASE SLAB....................................................... 5

6.0 PRESSURE MONITORING............................................................................................5

7.0 TEMPERATURE MONITORING.....................................................................................5

8.0 INNER TANK HORIZONTAL MOVEMENT SYSTEM.....................................................6


43/103

JOB NO

1.0 INTRODUCTION

This document is to specify the purpose and the general requirement for tankinstrumentation. The tank instrumentation comprises the followings.

1) Tank gauging system and overfill protection

2) Temperature monitoring for leak detection

3) Temperature monitoring for cooldown

4) Temperature monitoring for base slab

5) Pressure monitoring

6) Temperature monitoring

7) Inner tank movement system

2.0 TANK GAUGING SYSTEM AND OVERFILL PROTECTION

2.1 Purpose

The tank gauging system provides the necessary measurement of product level,temperature and density for tank inventory management and product stratification duringnormal operation.

2.2 Description

The measurement of product level and temperature in the tank will be provided by two levelgauges, both equipped to provide remote level reading and level alarm signals in the control

room. Each gauge shall be equipped with transmitter and threshold contacts to providelow-low level and high-high level alarms. Both the gauges shall read both level andtemperature of the product with multiple temperature sensors.

An independent third level gauge for high-high level alarm only shall also be provided. Thesignal together with the other two tank gauges shall be cabled to the SIS system.

A separate level / temperature / density gauge (LTD) shall be provided to monitor theproduct density at any given level. The LTD shall also monitor the level and temperature atany given density measurement point. The LTD is used to monitor for the onset of productstratification, which can lead to rollover. The use of top and bottom fill lines and productre-circulation ensures that stratification is avoided.

A PC based system shall be provided as data acquisition system to collect and manage thedata such as level, temperature and density etc. measured by the above tank gauges andshall be provided with hardware and software to permit data transfer to the plant controlsystem by means of serial communications (RS-485 interface).


44/103

JOB NO

3.0 TEMPERATURE MONITORING FOR LEAK DETECTION

3.1 Purpose

The purpose of the temperature sensor is to monitor the temperature in the annular spacebetween inner tank and outer wall and to generate an alarm when low temperature isdetected because of inner tank leakage.

3.2 Description

The sensor shall contain a minimum of 4 sensor elements spaced equal around the bottomof the tank annular. At all location, one additional sensor shall be installed on a vertical linealong the thermal corner protection to provide an indication of build-up of any liquid insidethe annular space.

The sensor temperature remains relatively constant and due to the insulation and heatin-leak from outside the tank, it is warmer than the bottom of the inner tank, which will be atthe LNG product temperature.

In the case of a leakage from the inner tank, the product will enter the annular space and thetemperature in the area around the leak will fall. This will be detected by the temperaturesensor and an alarm will be raised to control room by plant control system.

All the sensors shall be 3-wire RTD (platinum resistance temperature detectors) with aresistance of 100ohms at 32deg.F (0deg.C) and in compliance with IEC 751 Class A.

4.0 TEMPERATURE MONITORING FOR COOLDOWN

4.1 Purpose

During tank cooldown, it is necessary to monitor the temperature of the tank shell, bottomand suspended deck so that an adequate temperature profile of the tank can be obtainedduring the cooldown process to ensure that the tank is being cooled down uniformly and thattemperature differences do not occur which would cause unacceptable stresses in the innertank shell and bottom plates.

4.2 Description

A series of sensors shall be located on the inner tank shell, bottom and suspended deck toprovide coverage of the complete tank. The temperature elements are routed throughnozzles on the tank roof.

The number and location of the temperature sensors shall be as follows;a. 13 (thirteen) equally spaced along a vertical line on the outside of the tank shell

b. 11 (eleven) distributed strategically along diagonal line on the inside of the tank bottom

c. 5 (five) equally spaced along a horizontal line on the suspended deck

All cooldown sensors shall be 3-wire RTD (platinum resistance temperature detectors) with aresistance of 100ohms at 32deg.F (0deg.C) and in compliance with IEC 751 Class A.


45/103

JOB NO

5.0 TEMPERATURE MONITORING FOR BASE SLAB

5.1 Purpose

The temperature sensors are used to know the temperature of the concrete bottom slab.

5.2 Description

A continuous temperature monitoring shall be provided for the base slab. The temperaturemonitoring shall consist of 24 temperature sensors distributed over the base slab. Thedesign could be based on demonstrable previous installation experience.

All the sensors shall be 3-wire RTD (platinum resistance temperature detectors) with aresistance of 100ohms at 32deg.F (0deg.C) and in compliance with IEC 751 Class A.

6.0 PRESSURE MONITORING

6.1 Purpose

The instrument is used for the BOG compressor control to keep pressure in storage tankwithin allowable pressure and for over and vacuum pressure protection.

6.2 Description

Pressure transmitter for the bellow pressure measurement requirements is provided forstorage tank.

Absolute tank pressure for BOG compressor control

Gauge tank pressure for over and vacuum pressure protection and emergency shutdown

(ESD)

7.0 TEMPERATURE MONITORING

7.1 Purpose

The purpose of the temperature sensor is to monitor the temperature in the vapor spaceunder the suspended deck and to generate an alarm when the temperature in the vaporspace is increased due to some reasons.

7.2 Description

The sensor shall be installed under suspended deck to monitor the temperature of the vaporspace in storage tank.

The sensor shall be 3-wire RTD (platinum resistance temperature detectors) with aresistance of 100ohms at 32deg.F (0deg.C) and in compliance with IEC 751 Class A.


46/103

JOB NO

8.0 INNER TANK MOVEMENT SYSTEM

8.1 Purpose

Inner tank movement indicators are provided to monitor radial and rotational measurementof inner tank during cooldown and normal operation.

8.2 Description

Radial and rotational movement indicators shall be provided in the annular space betweeninner tank and outer wall.

Radial and rotational movement of the inner tank shall be determined assuming the twomeasured points lie on a circle, and that the radial thermal shrinkage at each positionrelative to the tanks center is equal and repeatable.

Radial and rotational movement of the inner tank shall be measured relative to the TCPinner wall using the sensors located at two orthogonal tank positions. Two sensors shall beprovided for radial and rotational movement respectively at each location.


47/103

M L (A)

C 18JAN08 Revised based on client comment TH - MH

B 17JAN08 Revised based on client comment TH - MH

A 11JAN08 Issued for Approval TH - MH

NO. DATE DESCRIPTION PREPD CHECKED APPROVED

CAUTION

THIS DOCUMENT CONTAINSCONFIDENTIAL ANDPROPRIETARYINFORMATION OF IHICORPORATION.THE DOCUMENT ALWAYSREQUIRES PRIOR WRITTENCONSENT OF IHI FOR(1) ITS REPRODUCTION BY ANY

MEANS,(2) ITS DISCLOSURE TO A

THIRD PARTY,OR(3) ITS USE FOR ANY PURPOSE

OTHER THAN THOSE FORWHICH IT IS SUPPLIED.

JOB NO.

TEL 03-

6204-7615


Environmental & Plant Div. DRAWING NO.

07902-TS-200-204/S7721-9001

REV.

C 1 21

TE2573 0 A4

8.5

IHI CorporationFORM E399 6A

OREGON LNG FERC FILING PROJECTTYPICAL SPECIFICATION FOR LEVEL/TEMPERATURE/DENSITY MONITORING,

LIQUID LEVEL GAUGING AND OVERFILL PROTECTION SYSTEM

CH-IV INTERNATIONAL


48/103

JOB NO


Environmental & Plant Div.DRAWING NO.

07902-TS-200-204/S7721-9001

REV.

C 2 / 21

IHI Corporation FORM E399-008

TABLE OF CONTENTS

1.0 SCOPE ............................................................................................................................... 3

2.0 CODE AND STANDARD ...................................................................................................3

3.0 ENVIRONMENTAL CONDITIONS..................................................................................... 4

4.0 GENERAL REQUIREMENTS ............................................................................................ 4

5.0 IDENTIFICATIONS PLATES ............................................................................................. 4

6.0 FACTORY ACCEPTANCE TEST ...................................................................................... 5

7.0 SITE ACCEPTACE TEST .................................................................................................. 5

8.0 TECHNICAL INFORMATION (DOCUMENTATION) .........................................................6

9.0 INDIVIDUAL SPECIFICATION ..........................................................................................6

9.1 Level gauging.................................................................................................................. 6

9.2 Temperature monitoring.................................................................................................. 7

9.3 Density monitoring .......................................................................................................... 7

9.4 Level gauging for high-high level protection ................................................................... 8

9.5 Data acquisition system .................................................................................................. 8

ATTACHMENT-1 VENDOR BROCHURE FOR LEVEL GAUGE

ATTACHMENT-2 VENDOR BROCHURE FOR LTD

ATTACHMENT-3 TYPICAL SYSTEM CONFIGURATION FULLY REDUNDANT ARCHITECTURE


49/103

JOB NO



07902-TS-200-204/S7721-9001

REV.

C 3 / 21


1.0 SCOPE

This specification defines general requirements for the design and supply of TANKGAUGING SYSTEM (including separate high-high level gauge) for tank inventorymanagement. TANK GAUGING SYSTEM shall be composed of the following equipment.

Level Gauging with multi-type temperature sensor ; 2 sets

Level, Temperature and Density Monitoring ; 1 setLevel Gauging for high-high level protection ; 1 set

Data Acquisition System ; 1 set

2.0 CODE AND STANDARD

TANK GAUGING SYSTEM design and materials shall comply with latest editions of codesand standards listed below:

NEMA Publications

NEMA 250 Enclosures for Electrical Equipment

API Publ ications

API RP 2350 Overfill Protection for Storage Tanks in Petroleum FacilitiesSecond Edition

API MPMS Chapter 2 Tank Calibration (Section 2A, 2B)

API MPMS Chapter 3 Tank Gauging,

Section 3 Standard Practice for Level Measurement of LiquidHydrocarbons in Stationary Pressurized Storage Tanks byAutomatic Tank Gauging

API MPMS Chapter 7 Temperature Determination

Section 4 Temperature Determination Using Fixed Automatic TankThermometer

API MPMS Chapter 11.1 Volume Correction Factors Table

API MPMS Chapter 12 Calculation of Petroleum Quantities

ASME Publ ications

ASME B16.5 Pipe Flanges and Flanged Fittings.

ASME B31.3 Process Piping

ASME B46.1 Surface Texture (Surface Roughness, Waviness and Lay)

NFPA Publications

NFPA 59A Production, Storage and Handling of Liquefied Natural Gas (LNG)


50/103

JOB NO



07902-TS-200-204/S7721-9001

REV.

C 4 / 21


3.0 ENVIRONMENTAL CONDITIONS

The system described herein for LNG Terminal Plant; the site is located in NE King Ave,Warrenton, OR. The site conditions are stated in the Design Basis, 07902-TS-000-002.

4.0 GENERAL REQUIREMENTS

The field equipment composing TANK GAUGING SYSTEM installed in process areas shallcomply with the following area classification and protetction class for the enclosure.

Area classification : Class 1, Division 2, Group C&D

Protection class : NEMA 4X or equal

Power supply (from UPS) : VAC, single phase, Hz (TBA)

TANK GAUGING SYSTEM shall be designed in accordance with this specification. Processconnection shall be in accordance with piping class and shall be as indicated in this

specification. The manufacturer will be responsible for the right performance of TANKGAUGING SYSTEM under the following conditions.

Tank details

Stored liquid : LNG

Stored liquid density : (HOLD) lb/ft3 (TBA)

Design min./max. temperature : -270deg.F/Ambinet

Design min./max. pressure : -0.073/4.3psig

Design max. liquid level : 118.630ft

The manufacturer will give all equipments for TANK GAUGING SYSTEM with ending andnecessary coating to resist the environmental conditions mentioned in clause 3.0. It isaccepted the epoxy resin like a protective coating against the corrosion. Instrument colorshall be the manufacturer's standard unless otherwise specified.

5.0 IDENTIFICATIONS PLATES

All instruments shall be provided with an identification plate, with all data clearly and deeplystamped on a corrosion-resistant plate permanently attached to the transmitter by means ofrivets or pins. The following information, but not limited to, shall be provided;

- Instrument tag number- Manufacturers name or trade mark- Manufacturers model number- Manufacturers serial number- Body rating including units- Electrical safety type of protection and enclosure- Range including units of measure- Output signal including units


51/103

JOB NO



07902-TS-200-204/S7721-9001

REV.

C 5 / 21


Notes:

1. Manufacturers model number should include type of measuring element material andtype of fill fluid and if applicable the range elevation.

2. Electrical safety type of protection identification shall be identical to the one specified inthis specification.

3. Each transmitter shall be provided with a stainless steel tag plate that shall be fixed with astainless steel wire to the transmitter. This plate shall show the purchasers tag number as

stated in the requisition/indent.

6.0 FACTORY ACCEPTANCE TEST

Manufacturer will be responsible for procedures and/or tests programs to be followed toguarantee the right performance of the TANK GAUGING SYSTEM. The responsibility forproduction test rests with the manufacturer.

Before TANK GAUGING SYSTEM is delivered to site, satisfactory performance of TANKGAUGING SYSTEM shall be demonstrated to CONTRACTOR and client or theirrepresentative.

Client or their representative shall witness the test prior to releasing the equipment for

shipment. The manufacturer shall be responsible for conducting the tests and providing allnecessary facilities, equipment and personnel.

Unless otherwise specified, inspection by CONTRACTOR shall be restricted to the followingas a minimum:

- Visual examination and dimensional check

- Verification of hydraulic, functional and electrical test, and characteristic and accuracy

checks for each equipment

- Verification of functional test for the whole system

- Verification of electrical safety type of protection certificate or declaration

- Verification of material certificate (if applicable)

- Verification of calibration certificate

The final acceptance, on the part of CONTRACTOR, will be made TANK GAUGINGSYSTEM installation place.

7.0 SITE ACCEPTACE TEST

The manufacturer shall demonstrate, to CONTRACTOR and company that the scope of workhas been accomplished in accordance with the Site Acceptance Test Procedure that therequirements of the test shall be defined. The test shall prove that the various systems havenot been damaged during transportation and are installed correctly. Communication testbetween TANK GAUGING SYSTEM and Terminal DCS shall be done as Site AcceptanceTest.


52/103

JOB NO



07902-TS-200-204/S7721-9001

REV.

C 6 / 21


8.0 TECHNICAL INFORMATION (DOCUMENTATION)

The manufacturer shall provide the following documentation, as a minimum, includingdrawings and technical specification where TANK GAUGING SYSTEM design characteristicsand manufacturing details are shown;

- General arrangement / Dimensioned drawings

- Fully detailed termination and wiring diagrams

- Software

- Installation, operation and maintenance manual

- Commissioning spare list, if any

- Spare quotation for 2 years operation

- Packing list complete with shipping weights and dimensions

- Factory and site test procedures

- Communication list with terminal DCS

In addition to the required test and inspection documents the manufacturer shall supply acertificate stating that the TANK GAUGING SYSTEM comply in all respects with thisdescription, the specification and the purchase order including the test requirements, for thecomplete TANK GAUGING SYSTEM.

9.0 INDIVIDUAL SPECIFICATION

9.1 Level gauging

The specification for the level gauge is as follows. Transmitter shall be equipped with

threshold contact in addition to serial link. The transmitter shall communicate with dataacquisition system with serial link as well as send contact signal to SIS system directly.Vendor brochure is attached as Attachment-1 for reference.

Type : Servo driven displacer gauge

Nozzle Connection : 6 ANSI 150# RF

Measuring Range : 0 to 120ft

Accuracy : Within 2mm

Material : Housing : Cast aluminum

Measuring tape : Stainless steelDisplacer : Stainless steel

Others : Manufacturers standard

Power Cable Entry Thread : Min. 1/2 NPT

Signal Cable Entry Thread : Min. 1/2 NPT


53/103

JOB NO



07902-TS-200-204/S7721-9001

REV.

C 7 / 21


9.2 Temperature monitoring

9.2.1 Temperature sensor

The specification is as follows.The temperature sensors shall measure the temperature ofliquid and vapor contained in LNG tank, consisting of sixteen (16) spot resistancetemperature detectors (RTD) spaced for the length of the probe and covering the tankavailable level. The output shall be transmitted to the multiple temperature interface.

Nozzle Connection : 2ANSI 150# RF

Overall Length : (HOLD) ft (TBD at detail engineering stage)

Sensitive Length : (HOLD) ft (TBD at detail engineerin

appendix 13l-storage tanks

Documents