Wärtsilä LNG Symposium Trinidad – 19 April 2012 Part 1: LNG ...

Wärtsilä LNG Symposium 

Trinidad – 19 April 2012 

Part 1: LNG Small Scale Liquefaction 

Part 2: LNG Regasification 

Stein Thorsager 

Executive Vice President 

Hamworthy Inc. 

April 2012 Page 1



Part 1: LNG Small Scale Liquefaction 


31 January 2012 Hamworthy plc becomes Wärtsilä Hamworthy 

Hamworthy’s portfolio of high technology products and systems represents a 

valuable complementary addition to Wärtsilä’s offering. The combining of the two 

companies’ strengths will speed up and ease the means for customers to reduce 

operating costs and achieve compliance with environmental legislation. 

Jaakko Eskola, Group Vice President, Wärtsilä Ship Power

Wärtsilä Hamworthy’s products and service

Hamworthy Oil & Gas Systems product portfolio 

LPG LNG Gas Recovery Separation Technology 

LPG cargo handling systems 

Cargo heaters & vaporizers 

Reliquefaction & cooling plants 

Ship- and cargo tank design 

BOG reliquefaction plants 

LNG regasification plants 

Small scale LNG plants 

VOC recovery systems 

Zero Flare solutions 

HC blanket gas and recovery 

Separator design 

VIEC /VIEC-LW internals 

Interface level and profilers 

LNG fuel gas systems Flare gas recovery and ignition Compact separation 

Aftermarket 

Commissioning 

Start–up support 

Project life time support 

Training

Liquefaction plants for onshore applications 

 

Mini-LNG 

LNG prod.: –> 20 k t/y 

–> 50 t/day 

–> 2.5 mmscfd 

 

 

Small Scale 

LNG prod.: 20 – 200 k t/yr, 

50 - 500 t/d, 

2,5 – 25 mmscfd 

Medium Scale 

LNG prod. 0,25 - 3 MMTPA

Hamworthy Gas Systems 

Small Scale Liquefaction - Reference project - Snurrevarden 

First free-standing small 

scale LNG plant in 

Northern Europe 

EPCIC contract with 

GASNOR 

LNG production capacity 

60 tons/day or 3 mmscfd 

Unmanned operation 

First LNG on 15th March 

2003 

Includes Pre-treatment, 

Liquefaction & Storage 

Snurrevarden

Small Scale Liquefaction process 

Feed gas 

Varmeveksler 

H2O & Hg removal 

CO2 removal 

Liquids separator 

-160°C 

LNG storage tank 

N2 compressor 

P-10-- 

LNG heat exchanger - section 1 

P-3-- P-3-- 

LNG heat exchanger – section 2 

LNG heat exchanger 

Section 3 

Expander 

Snurrevarden layout 

Cooling cycle 

compressor 

Gas engine 

Instrument air & 

Nitrogen 

Liquids separator & 

gas condensation (LNG) 

H2O removal 

CO2 removal 

Return gas 

compressor 

Storage tank

Snurrevarden LNG storage tanks 

Vacuum insulated tank 

Gross storage capacity of 2 x 250 m³ 

Dimensions: Diam:4.0 m, Height : 30 m 

Operating pressure : 125 kPa (1,25 bar) 

Design pressure : 800 kPa 

Boil of rate : 0.08 % / 24 hours 

Equipped with pump and hose station for LNG 

export to trailers

Reverse nitrogen Brayton – liquefaction process characteristics 

Cryogenic Heat Exchanger Compressors / Expanders 

Use of Nitrogen as non-combustible and non-toxic cooling medium 

Robustness due to single phase, single component, few or no splitting of streams 

Can be ramped quickly up and down in capacity, also fully automatic 

Can operate on optimum design point over a wide range of feed gas properties

Integrally geared compressor/expander (compander)

Liquefaction – cold box 

Brazed aluminium plate fin 

heat exchanger 

Designed with various 

number of process streams 

Installed inside an ”perlite 

insulated box”.

Pre-treatment challenge 

Gas sources

Gas pre-treatment 

Requirements to gas entering liquefier 

CO2 50 ppm 

H2O 1 ppm 

H 2S 4 ppm 

Pretreatment dependent on gas source: 

Batch processes, e.g. active carbon 

Amine systems (CO 2 and H 2S) 

Mol sieve (CO 2, H 2O, N 2, O 2,..) 

CO 2 Wash (CO 2, siloxanes, HFC’s …) 

Membrane technology (CO 2 and N 2) 

High H 2S content => potentially cost driving 

Energy consumption 

Dependent of level of contaminants 

To a large extent covered by heat


Small Scale Liquefaction - Reference project - Kollsnes 

LNG plant at the west 

coast of Norway 

EPCIC contract with 

GASNOR 

LNG production 

capacity 230 tons/day 

or 11 mmscfd 

First LNG in August 

2007 

Includes Pretreatment, 


Retrofit installation on 

existing LNG 

production site 

Kollsnes

Small Scale Liquefaction - Reference project - Sköldvik 

LNG plant in Finland 

EPCIC contract with Gasum 

LNG production capacity 55 

tons/day or 2.5 mmscfd 

First LNG in July 2010 

Includes Pre-treatment, 


Liquefaction based on use of 

liquid nitrogen from nearby air 

separation plant 

0% of feed gas lost to 

flaring/venting 

BOG handling, Tail gas handling 

(return to pipeline) 

Tank capacity 3 x 680 m3 

Continuous operation/peak 

shaving operation

Small Scale Liquefaction - Reference project - Sköldvik 

MCC and DCS 

Pre-treatment 

Metering Station 

BOG and residual gas handling 

Truck Filling 2 

Gas Feed and residual Gas return pipeline 

LNG Storage 

Cold Box 

Picture courtesy of 

GASUM OY 

Truck Filling 1


LNG Boil Off Gas Re- Liquefaction 

Most of US LNG 

import terminals are 

ideling. 

No solutions for the 

BOG 

Need to sent the 

gas at zero price 

into the gridline 

LNG BOG plant will 

re-liquefy the gas 

and put it back into 

the storage tank. 

Sköldvik 

Gulf LNG Terminal Similar as BOG Re-Liquefaction Plant

LNG export liquefaction plant design on barge for sheltered water 

For LNG export terminals 

in shelter waters a barge 

solution could be the right 

choice. 

Illustration reflect a Mid 

Scale LNG liquefaction 

plant of 0,6 MMTPA or 

75 mmscfd, with 

LNG Storage from 

existing LNG carries 

LNG export via LNG 

shuttle carriers.



Part 2: LNG Regasification 

. 


Hamworthy Oil & Gas Systems product portfolio 

LPG LNG Gas Recovery Separation Technology 

LPG cargo handling systems 

Cargo heaters & vaporizers 

Reliquefaction & cooling plants 

Ship- and cargo tank design 

BOG reliquefaction plants 

LNG regasification plants 

Small scale LNG plants 

VOC recovery systems 

Zero Flare solutions 

HC blanket gas and recovery 

Separator design 

VIEC /VIEC-LW internals 

Interface level and profilers 

LNG fuel gas systems Flare gas recovery and ignition Compact separation 

Aftermarket 

Commissioning 

Start–up support 

Project life time support 

Training

LNG Regasifications - Abbreviations and applications 

FSRU - Floating Storage and Regasification Unit 

SRV - Shuttle Regas Vessel 

JRU - Jetty Regas Unit 

Floating regasification terminal for gas supply to power plant or city 

pipeline network 

Applied for new build vessels, retrofit to existing LNG carriers, 

directly on the Jetty or to a barge 

Fast project execution, ~18 Months for conversion, typical lease 

arrangement of FSRUs imply low CAPEX

FSRU process overview 

Fiscal Metering 

Source: Golar LNG Energy 

FSRU 

Typical LNG Carrier 

LNG Regasification plant

Regasification system configuration

Regasification Unit based on Seawater as heating media 

LNG-flow per skid : 50-270 tons/hr 

LNG inlet temperature : -160 °C 

Gas outlet temperature : 0-10 °C 

LNG pressure (discharge pump) : 46-120 bar 

NG outlet pressure : 46-115 bar 

Inlet seawater temperature : 15-28 ºC 

Seawater outlet temperature : 5-18 ºC 

Typical skid size : 10*6*8 L(m)*W(m)*H(m) 

Propan Loop 

Seawater Loop 

LNG/NG loop

Regasification Unit based on Steam as heating media 

Water/Glycol Loop 

Steam Loop 

LNG/NG loop 

LNG-flow per skid : 50-270 tons/hr 

LNG inlet temperature : -160 °C 

Gas outlet temperature : 0-30 °C 

LNG pressure (discharge pump) : 46-120 bar 

NG outlet pressure : 46-115 bar 

Steam pressure : 10-25 bar 

Steam consumption : 15-83 tons/h/skid 

Typical skid size : 10*3*8 L(m)*W(m)*H(m)

LNG Re-gas Skid with seawater and propane loops 

Low OPEX 

(no LNG used in heat 

production) 

Quick response time 

(zero to max capacity 

typically within 30 minutes) 

Size and weight efficient 

(compared to other 

seawater based systems)

LNG Re-gas Skid with steam and water-glycol loops 

Compact 

(high temperature heating 

medium) 

Non-hazardous medium 

(steam heating) 

Sea temperature neutral 

(no cooling of seawater 

during regas)

Summary list for LNG Regasification plants 

Project Type Owners Delivery Capacity Trains Heating 

GdFSuez, Neptune, USA SRV Neptune SHI Hoegh LNG 2008 630 t/hr 3 x 33% Steam 

GdFSuez, Neptune, USA SRV Cape Ann SHI Hoegh LNG 2009 630 t/hr 3 x 33% Steam 

Petrobras, Rio FSRU “Golar Winter” Golar LNG 2009 460 t/hr 3 x 50% Water 

Shell/DUSUP, Dubai FSRU “Golar Freeze” Golar LNG 2010 460 t/hr 3 x 50% Water 

PT Nusantara, Djakarta FSRU “Golar Khannur” Golar LNG 2011 440 t/hr 3 x 50% Water 

Gas Berhad, Malaysia JRU Jetty Terminal Petronas 2012 442 t/hr 3 x 50% Water 

PGN, Medan FSRU Newb. HHI Hoegh LNG 2012 335 t/hr 3 x 33% Water 

KlaipedosNafta, Lithuania FSRU Newb. HHI Hoegh LNG 2013 345 t/hr 4 x 33% Water 

TBA FSRU Newb. HHI Hoegh LNG 2013 345 t/hr 3 x 33% Water 

April 2012

GdFSuez Neptune Shuttle Regasification Vessel (SRV) 

1st vessel gas trial March 2010 

2nd vessel gas trial August 2010 

3 x 210 t/hr (3 x33%) - 720 mmscfd export capacity

Golar Winter Floating Storage and Regasification Unit (FSRU) 

3 x 230 t/hr (3 x 50%) – 525 mmscfd export capacity

Golar Freeze FSRU 

3 x 230 t/hr (3 x 50%) – 525 mmscfd export capacity

P.T. Nusantara – Golar Khannur FSRU 

Source; Golar LNG 

3 x 220 t/hr (3 x 50%): 500 mmscfd export capacity 

Single Lift Module: 22 m x 20 m x 12 m (LxBxH) 

Dry weight: 738 Tonnes

PETRONAS Melaka Jetty Regasification Unit (JRG) 

Gas trial October 2010 




Höegh Medan Generic FSRU 




Höegh Klaipedos FSRU 




Contacts 

Stein Thorsager 

Executive Vice President 

Hamworthy Inc 

11111 Katy Freeway 

Suite 910 

Houston TX 77079 

Office : +1 (281) 759-3280 

Cell : +1 (305) 409-6702 

E-mail : sthorsager@hamworthy.com

Wärtsilä LNG Symposium Trinidad – 19 April 2012 Part 1: LNG ...

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