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EUROPEAN COMMISSION
DG MOVE
SEVENTH FRAMEWORK PROGRAMME
GC.SST.2012.2-3 GA No. 321592
LNG network identification
LNG Blue Corridors Project is supported by the European Commission under the Seventh Framework
Programme (FP7). The sole responsibility for the content of this document lies with the authors. It does
not necessarily reflect the opinion of the European Union. Neither the FP7 nor the European
Commission is responsible for any use that may be made of the information contained therein.
Deliverable No. LNG BC D3.7
Deliverable Title LNG Network identification
Dissemination level Public
Written By Javier Lebrato (NGVA) 14/03/2014
Checked by Milagros Rey (GNF) 16/07/2014
Approved by Xavier Ribas (IDIADA) 21/07/2014
Issue date 21/07/2014
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Revision History Rev Date Author Organization Description
0.1 14-03-2014 Javier Lebrato NGVA Initial Draft
0.2 07-04-2014 Gerard Balleste GNF Review and comments
0.3 07-04-2014 Milagros Rey GNF Review, comments and suggest additional
information.
0.4 28-04-2014 Eric Van Gysel Fluxys General revision
0.5 29-04-2014 Janez Pikon ENOS LNG Data actualization
0.6 9-05-2014 Milagros Rey GNF Review, comments and propose new
information.
0.7 20-05-2014 Javier Lebrato NGVA Additional information
0.8 21-05-2014 Milagros Rey GNF Review, comments.
0.9 11-06-2014 Javier Lebrato NGVA Final conclusions and amendments
1.0 16-07-2014 Milagros Rey GNF Final review (1rst version)
1.1 18-07-2014 Javier Lebrato NGVA Updated
1.2 18-07-2014 Milagros Rey GNF Review
1.3 18-07-2014 Judith Dominguez IDIADA Format review
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Contents Revision History ..................................................................................................................................2
1 Introduction ................................................................................................................................5
1.1 LNG Blue Corridors project ..................................................................................................5
2 Current situation .........................................................................................................................7
2.1 Overview .............................................................................................................................7
2.2 Natural Gas consumption in EU markets ..............................................................................8
2.3 LNG imports ...................................................................................................................... 10
3 The LNG supply chain ................................................................................................................ 12
4 The liquefaction plants .............................................................................................................. 15
4.1 Global liquefaction capacity............................................................................................... 16
5 LNG terminals ........................................................................................................................... 19
5.1 Large scale......................................................................................................................... 19
5.2 Small scale......................................................................................................................... 20
5.3 Terminals in operation ...................................................................................................... 21
5.3.1 Belgium ..................................................................................................................... 21
5.3.2 France ....................................................................................................................... 22
5.3.3 Greece ....................................................................................................................... 24
5.3.4 Italy ........................................................................................................................... 25
5.3.5 The Netherlands ........................................................................................................ 26
5.3.6 Portugal ..................................................................................................................... 26
5.3.7 Spain ......................................................................................................................... 27
5.3.8 Sweden...................................................................................................................... 29
5.3.9 Turkey ....................................................................................................................... 29
5.3.10 Turkey ....................................................................................................................... 30
5.3.11 UK ............................................................................................................................. 30
5.4 Small scale LNG ................................................................................................................. 32
6 The European natural gas.......................................................................................................... 33
7 Conclusions ............................................................................................................................... 34
List of Tables ................................................................................................................................. 43
List of figures ................................................................................................................................ 43
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1 Introduction 1.1 LNG Blue Corridors project
The LNG Blue Corridors project’s aim is to establish LNG as a real alternative for medium- and long-
distance transport—first as a complementary fuel and later as an adequate substitute for diesel. Up to
now the common use of gas as fuel has been for heavy vehicles running on natural gas (NG) only for
municipal use, such as urban buses and garbage collection trucks. In both types of application, engine
performance and autonomy are good with present technologies, as they are well adapted to this
alternative cleaner fuel.
However, analyzing the consumption data, the equivalence in autonomy of 1 liter of diesel oil is 5 liters
of CNG (Compressed Natural Gas), compressed to 200 bar. Five times more volume of fuel prevents
the use of CNG in heavy road transport, because its volume and weight would be too great for a long-
distance truck. This opens the way for LNG (Liquefied Natural Gas), which is the way natural gas is
transported by ship to any point of the globe. NG liquefies at 162º C below zero, and the cost in
energy is only 5% of the original gas. This state of NG gives LNG the advantage of very high energy
content. Only 1,8 liters of LNG are needed to meet the equivalent autonomy of using 1 liter of diesel
oil. A 40-ton road tractor in Europe needs a tank of 400 to 500 liters for a 1.000 km trip; its equivalent
volume with liquid gas would be 700 to 900 liters of LNG, a tank dimension that could easily be fitted
to the side of the truck chassis. LNG therefore opens the way to the use of NG for medium- and long-
distance road transport.
LNG has huge potential for contributing to achieving Europe’s policy objectives, such as the
Commission’s targets for greenhouse gas reduction, air quality targets, while at the same time
reducing dependency on crude oil and guaranteeing supply security. Natural gas heavy-duty vehicles
already comply with Euro V emission standards and have enormous potential to reach future Euro VI
emission standards, some without complex exhaust gas after-treatment technologies, which have
increased procurement and maintenance costs.
To meet the objectives, a series of LNG refueling points have been defined
along the four corridors covering the Atlantic area (green line), the
Mediterranean region (red line) and connecting Europe’s South with the
North (blue line) and its West and East (yellow line) accordingly. In order to
implement a sustainable transport network for Europe, the project has set
the goal to build approximately 14 new LNG stations, both permanent and
mobile, on critical locations along the Blue Corridors whilst building up a
fleet of approximately 100 Heavy-Duty Vehicles powered by LNG.
This European project is financed by the Seventh Framework Programme
(FP7), with the amount of 7.96 M€ (total investments amounting to 14.33
M€), involving 27 partners from 11 countries.
This document corresponds to the 7th deliverable within work package 3. It is a document describing
and overview about the supplying logistics of LNG in Europe. This document will be available at the
project website: http://www.lngbluecorridors.eu/.
Figure 1-1. Impression of the
LNG Blue Corridors
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Some graphics and data shown in this document are based on studies and publication updated of
2013. In each diagram, for better understanding reading, the actualization date is written close to the
image.
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2 Current situation 2.1 Overview
Europe's natural gas industry has a good situation despite the challenges from factors like low
demand, subsidized renewables, competition from coal and underused gas-fired generation.
Over the last years, global LNG trade has stabilized at around 240 MT. On the positive side, during the
last five years some new markets started to import LNG expanding the geographic reach and modify
the final markets. On the negative side, the low demand from Europe has made to increase other top
markets such as the Middle East, Asia, Asia Pacific and Latin America.
Total gas consumption in Europe’s 28 Member States has decreased for the third year running.
According to latest estimates, total demand was down 1.4% in 2013, following the 10% and 2% decline
in 2011 and 2012 respectively. Overall in 2013, gas demand remained under pressure predominantly
due to reduced usage in the power sector.
On average, comparing with other markets out of Europe, energy use per capita in the EU Member
States continues to be slightly lower than that of Japan and substantially lower than that of the United
States of America. On the demand side, the Asia Pacific region continued being the most growing
market with 7.7 MT, with the most consumption level in South Korea and China.
Contrariwise, inside the decreased European consumption mentioned previously, the most important
drop markets are Spain, Sweden and Italy.
Initial estimates for 2013 put gas consumption in the EU28 at 4 989 terawatt-hours gross calorific value
(TWh GCV), equivalent to 462 billion cubic meters (BCM), or 386 million tons of oil equivalent net
calorific value (MTOE NCV).
Despite a slight increase in EU gas demand recorded in the first six months of 2013, a range of factors
continued to have a negative effect on demand for the third year in a row.
Throughout 2013 and since the beginning of 2011, increased competition from renewables and the
continuing low price trend of coal in combination with low carbon prices have resulted in a further
decline of gas use in power generation. However, other factors such as the decrease in electricity
demand due to sluggish European economic growth have completed the picture, driving gas
consumption down.
In the residential and services sector, the colder weather experienced across the EU in 2013 resulted in
a higher demand for gas in heating, compared with 2012. The longer-lasting cold spell in spring was,
nevertheless, counterbalanced by less severe winter temperatures during the fourth quarter of 2013.
The continuing economic recession illustrated by a 0.5% decrease in EU28 average industrial
production in 2013 compared with 20124 again affected gas demand from industry.
On the gas supply side, indigenous production registered a slight decrease of 1% to 1 690 TWh (156
bcm), in comparison with 2012. EU production nevertheless still remained the largest source of gas for
EU28 customers, making up 33% of the total net supplies. The main external sources of supply were
Russia at 27%, Norway at 23% and Algeria with 8%. Liquefied natural gas (LNG) flows to the EU were
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again challenged in 2013 by strong competition on the global market. The share of gas from Qatar in
EU supplies, the EU’s main LNG supplier, decreased from 6% in 2012 to 4% in 2013.
Figure 2-1. Graphic of globally supply and demand of gas
2.2 Natural Gas consumption in EU markets
In this section the consumption of the European countries is shown. The amounts of gas traded are
written in TWh – Terawatts per hour – BCM – billion cubic meter – MTOE - Million tons of oil
equivalent – and PJ – Petajoules. These tables are based on data from 2013.
Table 2-1 Natural gas consumption in EU markets (A-D)
AusAusAusAustriatriatriatria BelgiumBelgiumBelgiumBelgium BulgariaBulgariaBulgariaBulgaria CroatiaCroatiaCroatiaCroatia CyprusCyprusCyprusCyprus Czech Rep.Czech Rep.Czech Rep.Czech Rep. DenmarkDenmarkDenmarkDenmark
TWhTWhTWhTWh 90,1 183,2 26,7 30,3 0 88 35,9
BCM BCM BCM BCM 8,3 17 2,5 2,8 0 8,1 3,3
MTOEMTOEMTOEMTOE 7 14,2 2,1 2,3 0 6,8 2,8
PJPJPJPJ 324,4 659,6 96,2 19,2 0 316,7 129,4
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Table 2-2 Natural gas consumption in EU markets (E-I)
EstoniaEstoniaEstoniaEstonia FinlandFinlandFinlandFinland FranceFranceFranceFrance GermanyGermanyGermanyGermany GreeceGreeceGreeceGreece HungaryHungaryHungaryHungary IrelandIrelandIrelandIreland
TWhTWhTWhTWh 7,1 36,9 498,1 956 41,5 100 49,7
BCM BCM BCM BCM 0,7 3,4 46,1 88 3,8 9,3 4,6
MTOEMTOEMTOEMTOE 0,5 2,9 38,5 74 3,2 7,7 3,8
PJPJPJPJ 5,6 132,8 1793,2 3441,6 149,5 360,2 178,9
Table 2-3 Natural gas consumption in EU markets (I-N)
ItalyItalyItalyItaly LatviaLatviaLatviaLatvia LithuaniaLithuaniaLithuaniaLithuania LuxembourgLuxembourgLuxembourgLuxembourg MaltaMaltaMaltaMalta NetherlandsNetherlandsNetherlandsNetherlands
TWhTWhTWhTWh 741,6 15,5 27,9 14,1 0 435
BCM BCM BCM BCM 68,7 1,4 2,6 1,3 0 40,3
MTOEMTOEMTOEMTOE 57,4 1,2 2,2 1,1 0 33,7
PJPJPJPJ 2669,8 55,8 100,4 50,6 0 1566
Table 2-4 Natural gas consumption in EU markets (O-S)
PolandPolandPolandPoland PortugalPortugalPortugalPortugal RomaniaRomaniaRomaniaRomania SlovakiaSlovakiaSlovakiaSlovakia SloveniaSloveniaSloveniaSlovenia SpainSpainSpainSpain SwedenSwedenSwedenSweden
TWhTWhTWhTWh 177,4 46,7 125 54,7 7,1 333,4 12,4
BCM BCM BCM BCM 16,3 4,3 11,6 5,1 0,7 30,9 1,1
MTOEMTOEMTOEMTOE 13,7 3,6 9,7 4,2 0,6 25,8 1
PJPJPJPJ 635 168,3 450 196,9 27,5 1200,2 44,6
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Table 2-5 Natural gas consumption in EU markets (others)
UKUKUKUK EUEUEUEU----28282828 SwitzerlandSwitzerlandSwitzerlandSwitzerland TurkeyTurkeyTurkeyTurkey
TWhTWhTWhTWh 855,1855,1855,1855,1 4989,1 39,9 480,9
BCM BCM BCM BCM 79,279,279,279,2 462 3,7 44,5
MTOEMTOEMTOEMTOE 66,266,266,266,2 486,1 3,1 37,2
PJPJPJPJ 3078,43078,43078,43078,4 17960,7 147,6 1731,2
In the consumption figures shown above, one of the key factors was the weather. It was an important
determinant of gas consumption over the first quarter of 2013 with unseasonably cold weather over
large parts of Europe.
In addition to this, other important aspects will have an important role and will be closely related with
the future gas demand as:
• Aggressive gas usage plans in China and India;
• The emergence of domestic shale gas as a preferred fuel source in the US;
• The discovery and use of gas resources in Latin America;
• The move away from nuclear power in Japan and some European countries in response to the
Fukushima Dai-ichi nuclear accident;
• Europe’s continued process of greenhouse gas emissions reduction;
• Russian plans to gasify its Far Eastern region;
• The search of shale and other unconventional gas resources in currently gas-poor countries.
2.3 LNG imports
Factors such as the drop in gas demand and the strong competition for LNG in the global market,
especially from Japan, led to a decrease in LNG imports.
LNG imports began falling in 2011 and this trend continued in 2012. In 2013, global LNG imports
remained stable compared to 2012. Total imports reached 236.9 Mt, a mere 0.3% increase over 2012.
At the end of 2013, LNG represented about 10% of global gas demand.
Three countries (Israel, Malaysia and Singapore) joined the ranks of LNG importers and Angola started
exporting its first cargoes. Little new supply was added during 2013, as exports were curtailed by
unplanned outages in several exporting countries.
While European imports sharply declined, the market tightness was sustained by strong demand
growth in China, South Korea and Latin America.
Due to the sluggish economic conditions, European LNG imports decreased by 13.5 Mt (-28.5%) and
reached 33.9 Mt, below 2005 levels.
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At the end of 2013, Asia made up 75.1% of global gas demand, followed by Europe (14.3%), and the
Americas (9.3%) and the Middle East (1.3%).
As a result of low demand in Europe and of higher prices in Asia and Latin America, LNG volumes re-
exported from European countries continued to grow, reaching 4 Mt (approximately 80 cargoes) at the
end of 2013.
Figure 2-2. LNG trade worldwide
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3 The LNG supply chain In order to understand completely the information explained in this document, the LNG supply chain is
explicated as following.
Natural gas comes from deep geological deposits, held hundreds of meter underground. Once
extracted, natural gas is preliminary treated and then sent to the pipelines network.
Actually, the exploration and production of hydrocarbons has moved to remote sites, such as deep-
water and ultra-deep water fields, even located 350 km far from the coast.
For these reasons, the oil&gas industry has developed the technology of liquefaction of natural gas:
natural gas is liquefied in a specific plant (more details are shown….) by cooling it to minus 160ºC at
atmospheric pressure.
Figure 3-1. Extraction and liquefaction scheme of LNG
Liquefied Natural Gas is then stored in tanks, named cryogenic tanks, that is to say, tanks with stands
cryogenic temperatures. Liquefaction plants are built in on-shore or offshore installations in order to
load LNG on specific vessels called LNG tankers (an overview of the large scale liquefaction plants
available in Europe are shown on the point 4.1.) It is useful to clarify that the difference between large
and small liquefaction plant is due to the size of the plant (It can be considered small scale liquefaction
plant around 50-450 K gallons per day, but there is not a clear definition about it). In a LNG small-scale
liquefaction plant the LNG is produced, for instance, to respond to peak shaving demand or make
available natural gas to regions where it is not economically or technically feasible to build new
pipelines.
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Figure 3-2. LNG stored on tankers (photo Gaz de France)
Once reach the regasification terminal, the LNG tanker is moved to specific place where articulated
arms connect to isothermal tanks to unload cargo. Then LNG is stored again in tanks whose capacity is
sized to ensure continuity of supply of the transport network between to deliveries.
The liquefied gas is drown for the tank, pressurized and then regasified by the heat exchangers which
mostly use sea water to heat the gas.
Back to gaseous state, the gas can be injected in the pipeline network and ready to be consumed.
About this last step, the European network of pipelines, a map will be shown on the point 4.3 of this
document.
Figure below shows how the LNG import terminals could offering new LNG services (concept of small
scale LNG value chain).
Figure 3-3. Small scale LNG value chain
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A small scale LNG terminals could enable the following operations (it is useful to clarify that the main
difference between a large scale LNG terminal and a small scale LNG terminal is the number of services
offered by the installation):
• Reloading: Transfer of LNG from the LNG reservoirs of the terminal into a vessel
• Transshipment: Direct transfer of LNG from one vessel into another
• Loading of bunker ships: LNG is loaded on bunkering ships which supply to LNG-fuelled ships
or LNG bunkering facilities for vessels
• Truck loading: LNG is loaded on tank trucks which transport LNG in smaller quantities
• Rail loading: LNG is loaded on rail tanks which transport LNG in smaller quantities.
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4 The liquefaction plants LNG liquefaction plants (large scale) are generally classified as baseload or peak shaving, depending on
their purpose and size. The process for the liquefaction of natural gas is essentially the same as that
used in modern domestic refrigerators, but on a massive scale. A refrigerant gas is compressed,
cooled, condensed, and let down in pressure through a valve that reduces its temperature. The
refrigerant gas is then used to cool the feed gas. The temperature of the feed gas is eventually
reduced to −161°C, the temperature at which methane, the main constituent of natural gas, liquefies.
At this temperature, all the other hydrocarbons in the natural gas will also be in liquid form. In the LNG
process, constituents of the natural gas (propane, ethane, and methane) are typically used as
refrigerants either individually or as a mixture. Feed pretreatment and refrigerant component recovery
are normally included in the LNG liquefaction facility.
Figure 4-1. LNG pipeline
The European liquefaction plants are shown below:
Table 4-1 List of liquefaction plants
Liquefaction plants
Finland in operation 2010 Porvoo LNG
satelite
Germany in operation Gablingen
Germany in operation
Stuttgart
Peakshaver
Germany in operation
Nievenheim
Peakshaver
Italy in operation
Firenze FPSO, large
scale
Netherlands in operation 1977
Maasvlakte
Peakshaver
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Norway in operation 2003 Kollsnes LNG I
Norway in operation 2007 Kollsnes LNG II
Norway in operation 2004
Snurrevarden
(Karmøy) LNG
liquefaction
Norway in operation 2011
Risavika
(Stavanger) LNG
plant
Norway in operation
Hammerfest LNG,
Snohvit (large
scale)
Poland in operation 2012 Kurpinski LNG Plant
(coal mine)
Slovenia in operation Jesenice LNG
United Kingdom in operation 2005 Avonmouth LNG
Facility
4.1 Global liquefaction capacity
In the last year, the average global capacity remained at 290.7 MTPA.
With 117 MTPA of liquefaction capacity under construction, global capacity is expected to grow by
36% over the next five years to reach 397 MTPA in 2018.
In 2014, liquefaction capacity growth is anticipated from the commissioning of plants in Algeria (Arzew
- GL3Z), Papua New Guinea (PNG LNG) and Australia (Queensland Curtis LNG). Growth will accelerate
starting in 2015 as a series of under construction projects in Australia.
Global liquefaction capacity utilization has trended downward over the past two years, from 87% in
2011 to 82% in 2013. In spite of higher Qatari and Malaysian production, as well as the recovery of
Yemen LNG following a series of attacks on feedstock pipelines in 2012, Atlantic Basin plants
continued to experience supply disruptions. Rising domestic demand in Egypt and Algeria, repeated
force majeure in Nigeria and technical difficulties in Norway saw plant utilization drop in all three
countries.
Utilization was particularly low in Egypt, where insufficient feedstock led to the closure of SEGAS LNG,
with country utilization dipping to just 23%. Continued feedstock issues in early 2014 led to the
temporary closure of Egypt’s second LNG plant, Egyptian LNG. No timeline has been established for
the resumption of Egyptian exports.
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Figure 4-2. Liquefaction activities by country in 10/2013. Source ENI
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Figure 4-3. Liquefaction capacity by cluster per companies in 10/2013. Source ENI
Figure 4-4. Liquefaction capacity by cluster per companies in 10/2013. Source ENI
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5 LNG terminals LNG terminals in Europe are shown in the following table:
5.1 Large scale Table 5-1 Large scale – LNG terminals
Country City Status Start-up
Year
NAME
of installation
Belgium Zeebrugge in operation 1987 Zeebrugge LNG
Terminal
France Fos Toskin in operation 1972 Fos-Tonkin LNG
Terminal
France Montoir-de-
Bretagne in operation 1980
Montoir-de-
Bretagne LNG
Terminal
France Fos Cavaou in operation 2010 Fos Cavaou LNG
Terminal
Greece Revithoussa in operation 2000 Revithoussa LNG
Terminal
Italy Fezzano di
Portovenere in operation 1971
Panigaglia LNG
terminal
Italy Livorno
in operation 2013 OLT Offshore LNG
Toscana
Italy Porto Levante In operation 2009 Adriatic LNG
Netherlands Rotterdam in operation 2011 Rotterdam (Gate)
LNG Terminal
Portugal Sines in operation 2004 Sines LNG
Terminal
Spain Barcelona in operation 1969 Barcelona LNG
Terminal
Spain Sagunto in operation 2006 Sagunto LNG
Terminal
Spain Bilbao in operation 2003 Bilbao LNG
Terminal
Spain Huelva in operation 1988 Huelva LNG
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Terminal
Spain Cartagena in operation 1989 Cartagena Plant
Spain Mugardos in operation 2007
El Ferrol,
Mugardos LNG
Terminal
Turkey Marmara Ereglisi
in operation 1994 Marmara Ereglisi
LNG Terminal
Turkey Aliaga
in operation 2006 Aliaga Izmir LNG
Terminal
United Kingdom
Teesside
in operation 2007
United Kingdom
Milford Haven
in operation 2009 Dragon LNG
United Kingdom Isle of Grain in operation 2005 Grain LNG
terminal
United Kingdom Milford Haven in operation 2009 South Hook LNG
5.2 Small scale Table 5-2 Small scale – LNG terminals
Country City Status Start-up
Year
NAME
of installation
Norway Mosjoen in operation 2007 Mosjoen LNG
terminal
Norway Fredrikstad in operation 2011 Øra LNG,
Fredrikstad
Sweden Nynashamn in operation 2011 Nynasham
(Brunsviksholmen)
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Figure 5-1. LNG map of large scale terminals
5.3 Terminals in operation
All terminals in operation are described as follow:
5.3.1 Belgium
5.3.1.1 Zeebrugge Fluxys LNG
Start up: 1987
Max. Hourly Capacity currently: 1700000 m3 (N) / hour
LNG Storage Capacity currently: 380000 m3 (N) / hour
By 2014/2016: 540000 m3 (N) / hour
Max. Ship Class Size Receivable: 217000 m3 (N) / hour
Max. Send out Pressure: 80 bar
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Figure 5-2. LNG terminal in Zeebrugge
5.3.2 France
5.3.2.1 Fos Tonkin Elengy
Start up: 1972
Max. Hourly Capacity currently: 1150000 m3 (N) / hour
LNG Storage Capacity currently: 150000 m3 (N) / hour
Max. Ship Class Size Receivable: 75000 m3 (N) / hour
Max. Send out Pressure: 67,7 bar
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Figure 5-3. EOS Tonkin LNG terminal
5.3.2.2 Montoir de Bretagne Elengy
Start up: 1980
Max. Hourly Capacity currently: 1600000 m3 (N) / hour
LNG Storage Capacity currently: 360000 m3 (N) / hour
Max. Ship Class Size Receivable: 265000 m3 (N) / hour
Max. Send out Pressure: 80 bar
Figure 5-4. Montoir de Bretange LNG terminal
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5.3.2.3 Fos Cavaou STFMC
Start up: 2010
Max. Hourly Capacity currently: 1160000 m3 (N) / hour
LNG Storage Capacity currently: 330000 m3 (N) / hour
Max. Ship Class Size Receivable: 270000 m3 (N) / hour
Max. Send out Pressure: 90 bar
5.3.3 Greece
5.3.3.1 Greece, Revithoussa DESFA
Start up: 2000
Max. Hourly Capacity currently: 750000 m3 (N) / hour
By 2015: 930000 m3 (N) / hour
LNG Storage Capacity currently: 130000 m3 (N) / hour
By 2015: 225000 m3 (N) / hour
Max. Ship Class Size Receivable: 135000 m3 (N) / hour
Max. Send out Pressure: 64 bar
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Figure 5-5. Revithoussa LNG terminal
5.3.4 Italy
5.3.4.1 Panigaglia GNL Italia
Start up: 1971
Max. Hourly Capacity currently: 439000 m3 (N) / hour
By 2015: 915000 m3 (N) / hour
LNG Storage Capacity currently: 100000 m3 (N) / hour
By 2015: 240000 m3 (N) / hour
Max. Ship Class Size Receivable: 70000 m3 (N) / hour
Max. Send out Pressure: 70 bar
5.3.4.2 Porto Levante Adriatic LNG
Start up: 2009
Max. Hourly Capacity currently: 1100000 m3 (N) / hour
LNG Storage Capacity currently: 250000 m3 (N) / hour
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Max. Ship Class Size Receivable: 152000 m3 (N) / hour
Max. Send out Pressure: 70 bar
5.3.4.3 Livorno OLT Offshore LNG Toscana
Start up: 2013
Max. Hourly Capacity currently: 592465 m3 (N) / hour
LNG Storage Capacity currently: 135000 m3 (N) / hour
Max. Ship Class Size Receivable: 155000 m3 (N) / hour
Max. Send out Pressure: 80 bar
5.3.5 The Netherlands
5.3.5.1 Rotterdam Gasunie / Vopak
Start up: 2011
Max. Hourly Capacity currently: 1650000 m3 (N) / hour
By 2015: 2200000 m3 (N) / hour
LNG Storage Capacity currently: 540000 m3 (N) / hour
By 2015: 720000 m3 (N) / hour
Max. Ship Class Size Receivable: 267000 m3 (N) / hour
Max. Send out Pressure: 80 bar
5.3.6 Portugal
5.3.6.1 Sines REN Atlantico
Start up: 2004
Max. Hourly Capacity currently: 1350000 m3 (N) / hour
LNG Storage Capacity currently: 390000 m3 (N) / hour
Max. Ship Class Size Receivable: 215000 m3 (N) / hour
Max. Send out Pressure: 84 bar
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5.3.7 Spain
5.3.7.1 Barcelona Enagas
Start up: 1968
Max. Hourly Capacity currently: 1950000 m3 (N) / hour
LNG Storage Capacity currently: 840000 m3 (N) / hour
Max. Ship Class Size Receivable: 250000 m3 (N) / hour
Max. Send out Pressure: 72 bar
5.3.7.2 Huelva Enagas
Start up: 1988
Max. Hourly Capacity currently: 1350000 m3 (N) / hour
By 2015: 1650000
LNG Storage Capacity currently: 610000m3 (N) / hour
By 2015: 250000
Max. Ship Class Size Receivable: 137500 m3 (N) / hour
By 2015: 250000
Max. Send out Pressure: 72 bar
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Figure 5-6. Huelva LNG terminal
5.3.7.3 Cartagena Enagas
Start up: 1989
Max. Hourly Capacity currently: 1650000 m3 (N) / hour
LNG Storage Capacity currently: 587000 m3 (N) / hour
Max. Ship Class Size Receivable: 2630000 m3 (N) / hour
Max. Send out Pressure: 72 bar
5.3.7.4 Bilbao Bahia de Bizkaia (BBG)
Start up: 2003
Max. Hourly Capacity currently: 1200000 m3 (N) / hour
LNG Storage Capacity currently: 450000 m3 (N) / hour
Max. Ship Class Size Receivable: 270000 m3 (N) / hour
Max. Send out Pressure: 72 bar
5.3.7.5 Sagunto Saggas
Start up: 2006
Max. Hourly Capacity currently: 1600000 m3 (N) / hour
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LNG Storage Capacity currently: 750000 m3 (N) / hour
Max. Ship Class Size Receivable: 265000 m3 (N) / hour
Max. Send out Pressure: 72 bar
5.3.7.5.15.3.7.5.15.3.7.5.15.3.7.5.1 El FerrolEl FerrolEl FerrolEl Ferrol
Start up: 2007
Max. Hourly Capacity currently: 825600 m3 (N) / hour
LNG Storage Capacity currently: 300000 m3 (N) / hour
Max. Ship Class Size Receivable: 145000 m3 (N) / hour
Max. Send out Pressure: 72 bar
5.3.8 Sweden
5.3.8.1 Brunnsviksholmen AGA
Start up: 2011
5.3.9 Turkey
5.3.9.1 Turkey, Aliaga EGEGAZ
Start up: 2006
Max. Hourly Capacity currently: 680000 m3 (N) / hour
LNG Storage Capacity currently: 280000 m3 (N) / hour
Max. Ship Class Size Receivable: 265000 m3 (N) / hour
Max. Send out Pressure: 72 bar
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Figure 5-7. Aliaga LNG termminal
5.3.10 Turkey
5.3.10.1 Turkey, Marmara Ereglisi Botas
Start up: 1994
Max. Hourly Capacity currently: 685000 m3 (N) / hour
LNG Storage Capacity currently: 255000 m3 (N) / hour
Max. Ship Class Size Receivable: - m3 (N) / hour
Max. Send out Pressure: - bar
5.3.11 UK
5.3.11.1 Isle of Grain (Grain LNG) GrainLNG
Start up: 2005
Max. Hourly Capacity currently: 2650000 m3 (N) / hour
LNG Storage Capacity currently: 1000000 m3 (N) / hour
Max. Ship Class Size Receivable: 265000 m3 (N) / hour
Max. Send out Pressure: 70 bar
5.3.11.2 Milford Haven South Hook
Start up: 2009
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Max. Hourly Capacity currently: 2440000 m3 (N) / hour
LNG Storage Capacity currently: 775000 m3 (N) / hour
Max. Ship Class Size Receivable: 265000 m3 (N) / hour
Max. Send out Pressure: n.a
5.3.11.3 Teesside Exelerate Energy
Start up: 2007
Max. Hourly Capacity currently: 670000 m3 (N) / hour
LNG Storage Capacity currently: 138000 m3 (N) / hour
Max. Ship Class Size Receivable: 150900 m3 (N) / hour
5.3.11.4 Milford Haven BG / Petronas / 4Gas
Start up: 2009
Max. Hourly Capacity currently: 1140000 m3 (N) / hour
LNG Storage Capacity currently: 320000 m3 (N) / hour
Max. Ship Class Size Receivable: 165000 m3 (N) / hour
Max. Send out Pressure: n.a
Figure 5-8. Milford Haven LNG terminal
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5.4 Small scale LNG Table 5-3 Small scale – Terminals in operation
Norway, Mosjoen Gasnor
Start-up: 2007
LNG storage
capacity 6,500 m3 LNG
Norway, Øra LNG,
Fredrikstad Skangass
Start-up: 2011
LNG storage
capacity 6,500 m3 LNG
Sweden,
Brunnsviksholmen
(Nynäshamn) AGA
Start-up: 2011
LNG storage
capacity 20,000 m3 LNG
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6 The European natural gas
Figure 6-1. European Natural gas grid
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7 Conclusions In the following paragraphs the current situation of LNG in Europe is evaluated in terms of stations and
terminal.
- On the one hand, the present infrastructure of stations is analyzed. The following map shows
Figure 7-1. European situation in terms of LNG facilities with all planned stations included in this project.
the volume of Heavy Duty Vehicles in the European roads - countries from East Europe were not
analyzed – as well as the future – at the end of this project- location of all LNG stations.
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It seems easy to think that more LNG stations should be built in order to cover all European territory.
Bearing in mind the recommended distance between LNG stations is around 400 Km (could be longer,
but depends on each truck and brand, they normally have a minimum autonomy of 800 Km). The
following description will be based on the main transited roads – marked in red –with high percentage
of traffic (more than 20%). Once the red “lines” are covered, it could be considered that infrastructure
is sufficient to provide a minimum service.
The current LNG infrastructure in United Kingdom, Belgium and The Netherlands could be enough.
Short distance and several stations nearby.
In Portugal, taking into account the all stations planned to build – three - corresponding the LNG Blue
Corridors – FP7 project, could be considered enough, influenced by the Spanish stations close to
Portugal.
In Spanish territory, some facilities should be built in the North-East part, borders with Portugal and
south region (between Madrid and Malaga) in order to create a homogenous LNG network.
Figure 7-2. In Spain, around 1200 km of roads highly populated are not covered
In France, the medium-East part is not covered despite of the planned stations in Paris, Limoges (is not
defined yet but one station covering the medium west part or south) and Lyon.
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Figure 7-3. France around 1500 km of roads highly populated are not covered
In the italic peninsula several stations are required to move easily along Italy powered in LNG. Just one
station in the north for the time being.
Figure 7-4. Italy situation. Just one station in the north for the time being
The most requiring country in term of LNG structure is undoubtedly Germany, with none station now.
Due to its big extension, its position in the center of Europe, storing several main roads in Europe,
several stations will have to be constructed to supply German roads.
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Figure 7-5. Increasing range about volume of HDVs
Finally in the Nordic countries, also a high number of facilities are required in Finland (since there is
none) and some of them in the north-east of Sweden: the E10 national roads is transited by around
4,000 vehicles (majority Heavy Duty Vehicles).
Figure 7-6. Finland – none stations – and Sweden – 6 stations, none working in the north region
- On the other hand, other aspect has to be covered taking about LNG infrastructure: LNG
terminals and distances to the stations.
Significant growth has been noticed in Europe during the last years. Major markets as Spain, UK,
Netherlands and Sweden have incremented their LNG activities.
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In the following table – Table 7-1 – the national situation is exposed, both terminals and stations.
Table 7-1 LNG terminals and stations per countries (currently)
Country LNG stations LNG terminals
Portugal 3 1
Spain 11 6
France 0 3
United Kingdom 9 3
Belgium 2 1
Italy 1 3
The Netherlands 5 1
Germany 0 0
Sweden 6 1
The Netherlands represents one of the best growth in Europe with roughly 10 LNG facilities with an
excellent locations – center of Europe, as well as the publication of the first national LNG regulation.
These stations are well supplied by the Rotterdam LNG terminal, working since 2011 with more than
1500000 m3 of hourly capacity per hour and 540000 m3 per hour of LNG Storage capacity.
Additionally it is foreseen its enlargement in the next year. In terms of distance between LNG terminals
and stations, affecting consequently the price to transport LNG, the average distance in The
Netherlands is 151 Km, less than the 500 Km stated as average by JEC.
Obviously the shorter distance between stations and terminals, lower price has to be paid. Therefore,
this is a very important factor to take into account when it’s time to build a station. Consequently,
more amount of terminals per countries, more affordable and feasible to create a LNG net from an
economical point of view.
Spain continues having the most and extensive amount of LNG terminals in Europe. 6 LNG terminals
are able to supply all stations in the Iberian peninsula (around 20 bearing in mind private and public
stations). Alongside this important investment, more than 300 LNG trucks are often refueled in Spain.
Similar case in United Kingdom with 4 terminals and almost 10 stations. Short distance, several stations
and three LNG terminals: always less than 500 Km. Therefore it can be considered Spain and UK as
benchmark in Europe, being able to build a solid LNG network in a really short term. Consequently the
number of trucks and possible develop in these countries is higher in comparison with other adjoining
countries.
It has been noticed a slight growth in other LNG markets such as Italy, Belgium and Portugal.
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The first LNG stations have been built recently in Piacenza – Italy -, Kallo – Belgium - and coming soon
Lisbon. Due to the restrictive regulations and the unclear situations of the business market perspective,
all this makes difficult to invest in LNG stations for the time being.
In any case, they could be considered as good potential markets in the years to come since there are
well supplied and connected.
In Belgium, the average distance between terminal and station is around 90 Km – Zeebrugge terminal
and Kallo station-, so really well supplied. The second station will be allocated in the airport of Brussels,
less than 100 Km far away from the terminal. No possible suggestions nor needs about a better
locations to allocate a new LNG terminal.
Figure 7-7. Distances between LNG interesting points in Belgium. The planned stations have been displayed
On the contrary, there are much longer distance in Portugal, around 400 Km between LNG terminal in
Sines and Porto. The north area in Portugal can be deemed as not well covered for a future LNG facility
nearby. Other important aspect to take into account is the allocation of a Spanish plant in Ferrol, which
could supply the future facility in Porto since it is 261 Km far away. However, the low LNG storage
capacity currently, it is not foreseen its enlargement, being the smallest in Spain, make difficult to
provide LNG from this terminal, specially once developed LNG stations in the North-West part of
Spain.
This uncovered area might produce high price to transport LNG by road. A possible station there
would reduce significantly these transport expenses cutting in half.
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Figure 7-8. Distances between LNG interesting points in Portugal
Regarding Italy, since there is just one LNG station situated in the north region, the average distances
are shorter, never more than 260 Km between terminals and station.
Figure 7-9. Distances between LNG interesting points in Italy. Current situation
The south region is completely unsupplied, though. In case of building a LNG station, this should be
supplied and covered by a new hypothetical terminal in the south at least.
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Figure 7-10. Other LNG stations in Italy – not working in LNG. Current situation
On the other hand, there are seven facilities which are already ready to provide LNG. Their locations
are, most of them, in the north of Italy. For different they are not providing LNG.
Go beyond Rome, south direction, the distances become significant to the terminals, that means more
than 450 Km. consequently the prices would really high.
Special mention is required for Germany and France since they are really key countries within the
European development of LNG as well as for the Blue Corridors project.
Regarding France and Germany, since there is none LNG station, the LNG refueling services are quite
devoid. Nonetheless there are three LNG terminals working in France. The lack of unique regulation to
register LNG trucks have delayed the investment in stations in both countries. Based on the high
interest of LNG in both countries alongside the availability of trucks during 2014, France and Germany
are deemed one of the most important markets for the project success.
The French and German stations will be crucial for several fleet operations from Spain, Belgium, The
Netherlands and Italy.
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Figure 7-11. Distances between LNG interesting points in France. The planned stations have been displayed.
From an economical point of view, bearing in mind the cost of transporting LNG trucks by road, the
future station in Paris will be better supplied by another terminal theoretically situated in the north
east.
The application of the regulation R110 in each country, based on this, any LNG truck can be approved
and registered in any European country, make the future investments feasible in the years to come.
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References List of Tables
Table 2-1 Natural gas consumption in EU markets (A-D) .................................................................................... 8
Table 2-2 Natural gas consumption in EU markets (E-I) ...................................................................................... 9
Table 2-3 Natural gas consumption in EU markets (I-N) ..................................................................................... 9
Table 2-4 Natural gas consumption in EU markets (O-S) .................................................................................... 9
Table 2-5 Natural gas consumption in EU markets (others)..............................................................................10
Table 4-1 List of liquefaction plants........................................................................................................................15
Table 5-1 Large scale – LNG terminals ...................................................................................................................19
Table 5-2 Small scale – LNG terminals ...................................................................................................................20
Table 5-3 Small scale – Terminals in operation ....................................................................................................32
Table 7-1 LNG terminals and stations per countries (currently) .......................................................................38
List of figures
Figure 1-1. Impression of the LNG Blue Corridors ................................................................................................. 5
Figure 2-1. Graphic of globally supply and demand of gas................................................................................. 8
Figure 2-2. LNG trade worldwide ............................................................................................................................11
Figure 3-1. Extraction and liquefaction scheme of LNG .....................................................................................12
Figure 3-2. LNG stored on tankers (photo Gaz de France) ................................................................................13
Figure 3-3. Small scale LNG value chain ................................................................................................................13
Figure 4-1. LNG pipeline ...........................................................................................................................................15
Figure 4-2. Liquefaction activities by country in 10/2013. Source ENI ............................................................17
Figure 4-3. Liquefaction capacity by cluster per companies in 10/2013. Source ENI...................................18
Figure 4-4. Liquefaction capacity by cluster per companies in 10/2013. Source ENI...................................18
Figure 5-1. LNG map of large scale terminals ......................................................................................................21
Figure 5-2. LNG terminal in Zeebrugge .................................................................................................................22
Figure 5-3. EOS Tonkin LNG terminal .....................................................................................................................23
Figure 5-4. Montoir de Bretange LNG terminal ...................................................................................................23
Figure 5-5. Revithoussa LNG terminal ....................................................................................................................25
Figure 5-6. Huelva LNG terminal .............................................................................................................................28
Figure 5-7. Aliaga LNG termminal ...........................................................................................................................30
Figure 5-8. Milford Haven LNG terminal................................................................................................................31
Figure 6-1. European Natural gas grid ...................................................................................................................33
Figure 7-1. European situation in terms of LNG facilities with all planned stations included in this
project. ..........................................................................................................................................................................34
Figure 7-2. In Spain, around 1200 km of roads highly populated are not covered......................................35
Figure 7-3. France around 1500 km of roads highly populated are not covered .........................................36
Figure 7-4. Italy situation. Just one station in the north for the time being ..................................................36
Figure 7-5. Increasing range about volume of HDVs ..........................................................................................37
Figure 7-6. Finland – none stations – and Sweden – 6 stations, none working in the north region.........37
Figure 7-7. Distances between LNG interesting points in Belgium. The planned stations have been
displayed.......................................................................................................................................................................39
Figure 7-8. Distances between LNG interesting points in Portugal .................................................................40
Figure 7-9. Distances between LNG interesting points in Italy. Current situation ........................................40
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Figure 7-10. Other LNG stations in Italy – not working in LNG. Current situation........................................41
Figure 7-11. Distances between LNG interesting points in France. The planned stations have been
displayed.......................................................................................................................................................................42
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