Lecture 11 LNG Import Terminals R2 - FIT Staffwebstaff.fit.ac.cy/eng.ap/FALL2016/MOE506/Lecture 11...
Transcript of Lecture 11 LNG Import Terminals R2 - FIT Staffwebstaff.fit.ac.cy/eng.ap/FALL2016/MOE506/Lecture 11...
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Lecture 11
LNG Import Terminals
Slide 1© Dr. Richard J Barnes 2013
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Types of Terminal
Slide 2© Dr. Richard J Barnes 2013
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Existing LNG Terminals
Operational in 2008
Japan 32 Brazil 2
USA 12 Chile 2
China 8 Italy 2
Spain 7 Taiwan 2
UK 5 Turkey 2
India 4 Belgium 1
South Korea 4 Greece 1
France 3 Canada 1
Mexico 3 Puerto Rica 1
Portugal 1
Total 93
Slide 3© Dr. Richard J Barnes 2013
Energoil
ConsultingTerminal Location
Terminal may be located:
• On the mainland (most common).
• On an island.
• On a platform.
• On a dedicated vessel.
Slide 4© Dr. Richard J Barnes 2013
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ConsultingMainland Terminal
• Requires deep water port.
• Easy access to export trunkline.
• Construction cost relatively low.
• Can be difficult to get planning approval -locals may object.
Source: www.ch-IV.com
Slide 5© Dr. Richard J Barnes 2013
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ConsultingIsland Terminal
• Requires deep water port.
• Access to export trunkline includes subsea link.
• Construction cost relatively low.
• Can be easier to get planning approval.
Source: tritonsa.gr
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ConsultingPlatform Terminal
• Deep water alongside.
• Could use old oil platform.
• Less planning problems.
• Requires subsea connector to land.Source: fiesta.bren.ucsb.edu
Slide 7© Dr. Richard J Barnes 2013
Energoil
ConsultingDedicated Vessel
• FSRU - Floating Storage and Regasification Unit.
• Same benefits as offshore platform terminal.
• Provides storage.
• LNG tanker is not delayed in turnaround.
Source: fiesta.bren.ucsb.edu
Source: http://www.excelerateenergy.com/downloads/Excelerate_teesside_08.pdf
Slide 8© Dr. Richard J Barnes 2013
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Marine Facilities
Slide 9© Dr. Richard J Barnes 2013
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ConsultingMarine Facilities
• Deep water channel required, typically about 17 m minimum.
• Adequate manoeuvring space, typically twice vessel length.
• Adequate tug support.
• Potential to close port whilst LNG tanker is in port.
Slide 10© Dr. Richard J Barnes 2013
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Energoil
ConsultingLNG Tanker Manoeuvring
Slide 11© Dr. Richard J Barnes 2013
Source: http://www.porttechnology.org/images/sized/images/uploads/news/LNG_Tanker-600x0.jpg
Source: http://www.asianews.it/files/img/russia-LNG-tanker.preview.jpg
Source: http://dmn.wpengine.netdna-cdn.com/wp-content/uploads/2011/11/CG-security-escort-for-tanker-Matthew.jpg
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Liquefaction Processes
Offloading Rate
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• LNG tankers are normally loaded and offloaded in 24 hours.
• Cargo size is between 75,000 m3 and 160,000 m3.
• Offloading rate must be 6,700 m3/hr.
© Dr. Richard J Barnes 2013 Slide 13
Offloading Rate
Energoil
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Liquefaction Processes
Loading/Offloading Arms
Slide 14© Dr. Richard J Barnes 2013
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• Typical installation is:
– 2 or 3 liquid loading arms;
– 1 vapour return;
– 1 liquid/vapour spare.
• Each arm has a 5,000 m3/hr rate.
© Dr. Richard J Barnes 2013 Slide 15
Loading Arms
Source: http://maritime-connector.com/ships_uploads/hilli-7382720-lng_tanker-port_-_dry_dock-566.jpg
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• Each arm consists of:
– A riser pipe;
– An inboard arm;
– An outboard arm.
• Each section is vacuum insulated.
• Inner pipe is 16 to 24” diameter.
• Outer pipe is 20 to 28”.© Dr. Richard J Barnes 2013 Slide 16
Loading Arm Detail
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• Each arm section is about 9 m long.
• Design allows for ship movement due to tide, wind and cargo discharge.
© Dr. Richard J Barnes 2013 Slide 17
Arm Flexibility
Source: Design and Construction SpecificationFor MARINE LOADING ARMS, (Third Edition –1999), OCIMF
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• Each arm is fitted with safety devices.
• Quick connect/disconnect couplers (QCDC)
• Emergency release systems (ESRs).
• Position monitoring.
© Dr. Richard J Barnes 2013 Slide 18
Arm Safety
Source: http://www.fmctechnologies.com/en/LoadingSystems/Technologies/ChiksanMarineLoadingSystems/~/media/LoadingSystems/Images/440_ChiksanMLA_LNGservice-280x240.ashx?bc=White&as=1&w=280
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• Provides easy positioning and quick connection to ship’s manifold.
• Hydraulic power supplied by marine arm.
• Operator can connect from a distance.
© Dr. Richard J Barnes 2013 Slide 19
Quick Connect/Disconnect Couplers
Source: http://www.niigata-ls.co.jp/jp/products/loading_arm/marine/options/images/qcdc/img01_001.jpg
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• Disconnects loading arm in case of fire, sudden tanker movement or other event.
• Two valves close and tanker is decoupled.
• Interlock prevents spillage.
© Dr. Richard J Barnes 2013 Slide 20
Emergency Release Systems
Source: http://www.niigata-ls.co.jp/jp/products/loading_arm/marine/options/images/ers/img01_001.jpg
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• Provides real-time data on loading arm position.
• Monitors position of tanker and arms.
• Movement of tanker.
• Displays operating envelope and gives alarm on excursions.
© Dr. Richard J Barnes 2013 Slide 21
Position Monitoring System
Source: http://www.niigata-ls.co.jp/jp/products/loading_arm/marine/options/images/pms/img01_001.jpg
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Liquefaction Processes
Terminal Process Scheme
Slide 22© Dr. Richard J Barnes 2013
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ConsultingTerminal Flow Scheme
Boil OffCompressor
VapourReturn Blower
VapourReturn Line
LNG Unloading Lines
LNG StorageTanks
First StageSendout Pumps
Second StageSendout Pumps
Recondenser
Vapouriser
Natural GasTrunk line
Slide 23© Dr. Richard J Barnes 2013
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Terminal Storage
Slide 24© Dr. Richard J Barnes 2013
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• Tank can be 80-90 m diameter and 50 m high.
• Typical volume is 160,000 m3 up to 250,000 m3.
• Normally a minimum of two tanks at a terminal.
© Dr. Richard J Barnes 2013 Slide 25
Terminal Tank Size
Source: http://s0.geograph.org.uk/geophotos/01/02/54/1025438_82c70921.jpg
Energoil
ConsultingLNG Storage Tanks
• Single containment.
• Double containment.
• Full containment.
• Membrane.
• In-ground storage.
• Standard tank size is now 160,000 m3.
Slide 26© Dr. Richard J Barnes 2013
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ConsultingTank Choice
• Full containment more expensive than single containment.
• Extra area of single containment tanks may be too expensive or not available.
• Single containment tanks require larger fire fighting and vapour compression.
• Concrete full containment tanks provide increased protection against external events.
• In-ground tanks claimed to be better in seismically active areas (Japan has 76 in-ground tanks). Slide 27© Dr. Richard J Barnes 2013
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• Receiving terminals built for winter period supply.
• Require sufficient tanks that one can be delivering to pipeline, whilst other is being filled.
• More tanks may be built to meet strategic demand and provide buffer storage.
© Dr. Richard J Barnes 2013 Slide 28
Terminal Storage Capacity
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Types of Vaporiser
Slide 29© Dr. Richard J Barnes 2013
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ConsultingVapouriser Types
• Open Rack.
• Submerged Combustion.
• Shell and tube.
• Cold utilisation.
Slide 30© Dr. Richard J Barnes 2013
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ConsultingOpen Rack Vaporiser
• Takes heat from seawater to vaporise LNG.
• Environmental restrictions on seawater return temperature.
• Biocide added to seawater to inhibit marine growth.
• Seawater can create corrosion problems.
Source: http://www.spp.co.jp/English/jigyou/ekika-e.html
Slide 31© Dr. Richard J Barnes 2013
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Submerged Combustion
Vaporiser
• Heat is supplied by burning natural gas.
• Flame is submerged for direct heat transfer to the water heating medium.
• Water becomes corrosive because CO2 dissolves in it.
• No flame impingement or hot spots.
Source: http://www.spp.co.jp/English/jigyou/ekika-e.html
Slide 32© Dr. Richard J Barnes 2013
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ConsultingShell and Tube
• Several different configurations;
• Seawater cooled indirectly by propane;
• Reduces risk of seawater freezing
• Also suitable for temperature recovery.Slide 33© Dr. Richard J Barnes 2013
Source: .kobelco.co.jp/english/machinery/products/ecmachinery/lng/ifv.html
Energoil
Consulting“Cold” Recovery
Low temperature used in other process:
• Cool air intake of CCGTG;
• Pre-cooling in air separation;
• Cold storage of frozen food;
• Refrigeration and industrial use;
• Production of CO2 and dry ice;
• Ethane and propane extraction and recovery.
Slide 34© Dr. Richard J Barnes 2013
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Liquefaction Processes
LNG Pumps
Slide 35© Dr. Richard J Barnes 2013
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• Pumps in each storage tank deliver the LNG at about 7 barg.
• The pumps are installed from the top of the tank, so that no aperture is cut into the tank below liquid level.
• Several pumps are installed to give adequate spares.
• LNG is pumped around the loading lines to keep them cold.
© Dr. Richard J Barnes 2013 Slide 36
In-tank Pumps
Source: http://www.nikkiso.com/products/pump/submerged/img/c04-1.jpg
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• Send-out pumps boost the LNG to pipeline pressure before the vaporiser.
• Due to the high head normally required, multi-stage, canned pumps are used.
© Dr. Richard J Barnes 2013 Slide 37
Send-out Pumps
Source: http://www.lngexpress.com/lngl/Pres/TommyStone.pdf
Energoil
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Liquefaction Processes
Boil Off Gas
Slide 38© Dr. Richard J Barnes 2013
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ConsultingVapour Disposal
• Vapour sent to tanker when unloading.
• Compressed, recondensed and fed to Second Stage Sendout Pumps.
• Compress and send direct to natural gas pipeline;
• Flare or vent.
Slide 39© Dr. Richard J Barnes 2013
Energoil
Consulting
© Dr. Richard J Barnes 2013 Slide 40
BOG Liquefaction Schematic
From BOGCompression
Liquid ReturnTo Tank
HP BOG toPipeline
Compressor-Expander
After-Cooler
CompressorAfter-Cooler
TC
PC
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Consulting
Liquefaction Processes
Meeting Gas Specification
Slide 41© Dr. Richard J Barnes 2013
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ConsultingGas Higher Heating Values
Slide 42© Dr. Richard J Barnes 2013
Gas BTU/SCF MJ/m3
Methane 1,010.0 37.708
Ethane 1,769.6 66.065
Propane 2,516.1 93.936
Nitrogen 0.0 0.0
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ConsultingEffect of Ethane and Propane
• 20% ethane or 10% propane could be added to gas and still meet the CV specification.
• Wobbe specification limits addition to 5% ethane and 4% propane.
Slide 43© Dr. Richard J Barnes 2013
Energoil
ConsultingAddition of 5% Nitrogen
• Addition of inert gas decreases both CV and Wobbe.
• Up to 15% ethane can be added or 10% propane and still meet both specifications.
Slide 44© Dr. Richard J Barnes 2013
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Import Terminal
Cost Breakdown
Slide 45© Dr. Richard J Barnes 2013
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ConsultingTypical Cost Breakdown
Jetty 11%
Tanks 45%
Process 24%
Utilities 16%
General Facilities 4%
Total 100%
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ConsultingCAPEX Estimate
• Dependent on soil conditions;
• Jetty length and need for dredging;
• Cost of land and area required;
• $70 - 150 / tpa capacity.
(Source: BG Group)
Slide 47© Dr. Richard J Barnes 2013
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Liquefaction Processes
End of Presentation
Slide 48© Dr. Richard J Barnes 2013