Naturgass til fremstilling av hydrogen - Naturgass-kjeden fra reservoar til bruker -
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Naturgass til fremstilling av hydrogen
- Naturgass-kjeden fra reservoar til bruker -
THE PRODUCTION OF HYDROGEN FROM NATURAL GAS
TPG4140 NATURGASS
11 Oktober 2010
10:15-11:00 & 11:15-12:00
NTNU Energi- og Prosessteknikk (EPT)
Prof. Dr.-Ing. Ulrich Bünger
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Outline
Lesson “One”
• Why hydrogen?
• Why hydrogen from natural gas?
• Hydrogen from natural gas
• NG to hydrogen process technology
Lesson “TWO”
• Hydrogen energy chains (= pathways)
• Emissions and costs in comparison to other pathways
• International strategies and projects
• Norwegian strategy
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Glossary
ATR auto-thermal reformer
CCS carbon capture and storage
CMG compressed methane gas
CNG compressed natural gas
CO carbon monoxide
CO2 carbon dioxide
DG-TREN Direction Generale Transport and Energy
DME di-methylester
EL electricity
EU European Union
FAME fatty acid methyl ester
FC fuel cell
FT Fischer Tropsch
GHG greenhouse gas (emissions)
GH2 gaseous hydrogen
HFP Hydrogen and Fuel Cell Technology Platform
H2 hydrogen
HT-FC high temperature fuel cell
ICE internal combustion engine
LH2 liquid hydrogen
NG natural gas
RME rape seed methyl ester
PE primary energy
PEMFC proton exchange membrane fuel cell
POX partial oxidation
PSA pressure swing adsorption
SMR steam methane reformer
TES Transport Energy Strategy
WGS water gas shift reactor
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Lesson “One”
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Early hydrogen vision
Source: GermanHy, 2008
HVDC power transport H2 – pipeline LH2 tanker routes
Canada
A global energydistribution system
Seasonal and daily distribution of renewable forms of energyand import to the industrial world (here: Germany)
Daily energyload levelling
Seasonal energyload levelling
N
S
W E
Source: Ludwig Bölkow, 1988
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Hydrogen‘s short term role – today‘s challenge
1930 1950 1970 1990 2010 2030 2050 2070 2090
5,000
10,000
15,000
20,000
Tota
l p
rim
ary
en
erg
y s
up
ply
in
[M
toe
]
5,000
10,000
15,000
20,000Legend
GeothermalHydroWindBiomassSolar collectorsSOTPVUraniumCoalGasOil
Geothermal
Hydropower
Wind power
Oil
SOT
Biomass
Solar collectors
2006 2030
PVGas
Coal
Uranium
WEO 2006
LBS
T,
AW
EO
200
6
Source: LBST, Alternative World Energy Outlook, 2006
Supplygap!
7
Sankey diagram Scotland 2002 [TWh]
Transport heavily depends on oil.What can replace dwindling oil in transport?
8
Replenish.raw mat.
Organicresiduals
(w(o wood)
Sun,hydro-/wind
power Wood
Fermen-tation
Fermen-tation
Elektrolys. Gasification
Reformer Reformer
renewable
Ethanol Biogas Hydrogen
Hydrogen/CO (HT-FC)
Fuel cell
HeatElectr.
Primaryenergy
Conversion
Secondary energy I
End-energy
Usable energy Heating/Processes
Power/light
Naturalgas Elec.-mix* Coal Min. oil
Gasificat.Reformer
Reformer Reformer Reformer
fossil
2CO2 from air/concentr.sources
Synthesis/electrolyis
Methanol Gasol.NG
Refinery
No primaryenergy carrier
also internalreforming
Alsonuclear energy
Secondary energy II
Why hydrogen from natural gas?
Refrig.
Cooling/Processes
*Also contains all forms of primary energy, such as nuclear energy
Large variety of sources and pathways!
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• In transition phase hydrogen from renewables is more expensive
• Specifically with fuel cells, hydrogen from NG has some GHG emission reduction potentials versus oil and coal
• NG infrastructure widely available in Europe
• In comparison to oil, NG supply in Europe has a longer term resource potential ( increased energy supply diversity)
• Today, hydrogen from NG is the least complex ( least expensive) pathway; steam-reforming of NG (SMR) is the best-known process but will become more costly over time
• SMR are scalable by size allowing potential transition to flexible onsite hydrogen production
• Carbon sequestration and storage (CCS) allows nearly CO2 free hydrogen production, if accepted publicallyand widely proven to be safe and economic
Why hydrogen from natural gas?
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EU Hydrogen Energy Roadmap HyWays* (2004 - 2008)Transition and long-term pathways
* HyWays – The European Hydrogen Energy Roadmap Project (2004-2008)
Prospect 2030with forwardlookingassumptions
• EU-wide analysis to understand regionally different approaches & options for H2 in transport
• Back- and forecasting with wide stakeholder involvement (industry, institutes, politics)
• Application of toolbox for technical, economic, emissions and policyimpact modelling
• No commercialization approach!
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Natural gas grid in Europe
Source: NaturalHy 2008
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Choice of most relevant hydrogen sources
Source: Daimler 2010
13NG to hydrogen process technologyMajor processes for hydrogen production from NG - reforming
NGreforming
Synthesisgas
clean-up
Hydrogenpurification
• Steam reforming• Partial oxidation• Autothermal reforming• Plasma reforming
• CO conversion (CO-shift)
Feed gasclean-up
• Dust separation• De-sulphurisation
• Catalytic processes• Adsorption• Diaphragm processes• Purification by metal-hydrides• Proton-/ion conductors• Iron-redox filter (Iron sponge process)
Raw NG NG H2 + CO(e.g. <10ppm)
Synthesis gas(H2, CO, CO2, CH4)
Pure H2
Large NG reformerHaldor Topsoe
Off-gas tank
Cleaning bystaged adsorption
Reformer reactor
Burner
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NG to hydrogen process technology
molekJHHCOOHCH /2063 224
Steam Reforming of Natural Gas (SMR)
• Steam reforming reaction for NG:
• Endothermic (catalytic) process with heating (700 - 800°C)
Partial Oxidation of NG (POX)
• Partial oxidation reaction for NG:
• Exothermic (non-catalytic) process at 1,300°C and 9 MPa with pre-heated O2 to 700 - 800°C, lower H2 efficiency and high dynamics, O2 taken from air leads to N2 contents in product gas
molekJHHCOOCH /3622/1 224
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NG to hydrogen process technologyComparison of reforming processes for NG
700 - 800°C 850 - 1,000°C1,300°C
SMR ATRCombined SMR/POXPOX
65 - 70% (small)81% (large)
65% (PE = 100%)37%
(PE EL = 33%)69% (large)
Low(endothermic)
High(exothermic)
High(exothermic)
Efficiency
Dynamics
Operatingtemperature
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NGreforming
Synthesisgas
clean-up
Hydrogenpurification
• Steam reforming• Partial oxidation• Autothermal reforming• Plasma reforming
• CO conversion (CO-shift)
Feed gasclean-up
• Dust separation• De-sulphurisation
• Catalytic processes• Adsorption• Diaphragm processes• Purification by metal-hydrides• Proton-/ion conductors• Iron-redox filter (Iron sponge process)
Raw NG NG H2 + CO(e.g. <10ppm)
Synthesis gas(H2, CO, CO2, CH4)
Pure H2
NG to hydrogen process technologyMajor processes for hydrogen production from NG – gas clean-up
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• Conversion reaction to oxidise CO (CO-Shift):
• Exothermic process at 190 - 260°C independant from pressure
• Also dubbed water gas shift reaction (WGS)
molekJHHCOOHCO /41222
NG to hydrogen process technologySynthesis gas clean-up: CO – conversion
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NGreforming
Synthesisgas
clean-up
Hydrogenpurification
• Steam reforming• Partial oxidation• Autothermal reforming• Plasma reforming
• CO conversion (CO-shift)
Feed gasclean-up
• Dust separation• De-sulphurisation
• Catalytic processes• Adsorption• Diaphragm processes• Purification by metal-hydrides• Proton-/ion conductors• Iron-redox filter (Iron sponge process)
Raw NG NG H2 + CO(e.g. <10ppm)
Synthesis gas(H2, CO, CO2, CH4)
Pure H2
NG to hydrogen process technologyMajor processes for hydrogen production from NG - purification
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NG to hydrogen process technologyHydrogen purification: adsorption
Phigh
Plow
Scheme of 4-stage PSA process
Product hydrogen
Adsorberair
InstrumentControlUnit
Feed gas Flushing gas
Vent stack
I - AdsorptionII, V - Pressure balanceIII - Pressure relaxationIV - FlushVI - Pressure rise
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Low(e.g. 3 bar)
High(10 bar)
High(20 bar)
Catalyticprocesses
MembranetechnologyPSA
High(catalyst)
High(Pd/Ag membrane)
High(system complexity)
High LowHigh(exothermic)
Costs
Dynamics
Pressure
NG to hydrogen process technologyComparison of hydrogen purification processes
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Flowsheet of Carbotech SMR at ARGEMUC(100 Nm3
H2/hr)
Source: Bünger, Haukedal, 2003
AirNG to burner SMR
WGS
Heat
Heat(start-up N2)
Offgas~ 1.000°CPSA-offgas
De-sulph.
OsmosisH2O
H2O
PSA
~ 350°C
~ 250°C
H2to storagetank (~ 30 bar)
De-ion
Bypass
NG
~15 bar
Offgas buffer
H2 buffer
Synthesis gas
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• 35,000 Nm3/h hydrogen
• 9-bed PSA (99.9 vol% purity)
Source: Linde
Large NG steam reformer Leuna/Bitterfeld
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Aerial View of SMR(330 Nm³/h)
Source: Caloric
Hydrogen product tanks
Reformer reactor
Offgas buffer tank (2 MPa)
4-stage PSA
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Major Components of SMR
Off-gas containerAdsorber
Steam-drum
Steam-reformer
Cooler Burner
Air blower for burner
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On-site SMR (100 Nm3 H2/h) with CO-Shift and PSA
Source: Mahler IGS
26Compact small scale SMR with integrated desulphurisation for residential PEM-fuel cells (0.5 - 1 kWel)
Source: Osaka Gas, 2004
Type FPS-1000 FPS-500
Class for net 1 kWel systems for net 500 Wel systems
CO removal process Preferential oxidation
Burner fuel Anode off gas + NG or NG only
CO in product gas < 1 ppm (initial), < 10 ppm (after 90,000 hours)
Thermal efficiency (LHV)*1 at nominal output 77% 75%
Life (without exchanging any catalysts) 90,000 hours (5 ppm-S in NG)
Size (including thermal insulation, without outer piping) 280Wx440Lx395H 260Wx370Lx395H
Start-up time ca. 1 hour
Turn down (net available H2 basis) 0% (self-sustainable) - 100%
Load change rate at increasing output > 1 W/sec*2
Load change rate at decreasing output Moment*2
Designed start-up and shut-down times 200 times
Pressure drop of fuel line < 5 kPa
Flow rate of natural gas*3 for process at nominal output 4.2 NL/min 2.1 NL/min
Steam/Carbon ratio at steam reformer 2.5
O2/CO Ratio at CO removal reactor 1.5
Flow rate of product gas at nominal output (dry) 23 NL/min 11.5 NL/min
H2 > 75 vol.%
N2 < 3 vol.%
CH4 < 2 vol.%
CO < 1 ppm
Product gas (dry %)
CO2 20 vol.%
*1 Thermal efficiency = Enthalpy of H2 consumed in cell stack / (Process natural gas + Burner natural gas) *2 depends on control procedure. *3 Composition of natural gas: CH4 = 88 vol.%, C2H6 = 6 vol.%, C3H8 = 3 vol.%, C4H10 = 3 vol.%
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Lesson “Two”
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Outline
Lesson “One”
• Why hydrogen?
• Why hydrogen from natural gas?
• Hydrogen from natural gas
• NG to hydrogen process technology
Lesson “TWO”
• Hydrogen energy chains (= pathways)
• Emissions and costs in comparison to other pathways
• International strategies and projects
• Norwegian strategy
29
Density CO2
kg/l MJ/kg MJ/l g/MJ
Gasoline 0.745 43.2 32.2 73.38
Diesel 0.832 43.1 35.9 73.25
Naphtha 0.720 43.7 31.5 71.22
Ethanol 0.794 26.8 21.3 71.38
FAME (biodiesel) 0.890 36.8 32.8 76.23
FT diesel 0.780 44.0 34.3 70.80
Methanol 0.793 19.95 15.8 69.1
DME 0.670 28.4 19.0 67.36
CNG 0.000790 45.1 0.0356 56.24
Hydrogen 0.000090 120.0 0.0108 0.0
LHV
Fuel emissions and costs in comparisonEnergy specific physical properties
Sources: CONCAWE/EUCAR/JRC, WtW calculations by LBST
http://ies.jrc.cec.eu.int/wtw.html
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Typical hydrogen energy chainHydrogen from NG (EU-mix)
Natural gassupply
(EU-mix)
Reformer(on site)
H2 compression
Electricitysupply
(EU-mix)
Energy source
Energy source
Energy loss
Electricity
NG H2
Energy loss Energy loss
CGH2
Electricity Electricity
NOX CH4 CO2 NOX CH4 CO2
NOX CH4 CO2
Energy loss
Natural gassupply
(EU-mix)
Reformer(on site)
H2 compression
Electricitysupply
(EU-mix)
Energy source
Energy source
Energy loss
Electricity
NG H2
Energy loss Energy loss
CGH2
Electricity Electricity
NOX CH4 CO2 NOX CH4 CO2
NOX CH4 CO2
Energy loss
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Emissions and costs in comparisonGHG emissions for various hydrogen (and reference) energy chains
Source: GM-WtW Study, LBST, 2003
MTA: Manual Transmission AutomaticDI-ICE: Direct injection ICE
Fuel production governs GHG emissions
End-use efficiency has a large impact on WtW efficiency!
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Manufacturer Haldor Topsoe 1998 Linde 1992 Units
Capacity 560 100.000 Nm3H2/h
NG input 1,4406 1,4167 kWh/kWhH2
LHV (NG) 10 10 kWh/Nm3
LHV (H2) 3 3 kWh/Nm3
LHV (H2) 33,33 33,33 kWh/kg
NG input 0,43 0,43 Nm3NG/(Nm3
H2)
Electricity input 0,0161 -0,05 kWh/kWhH2
Investment 2.172.990 77.716.366 EUR
Specific investment 3.880 777 EUR/Nm3/hEquivalent full load periods 8.000 8.000 h/a
Annual H2 production 403 72.007 tH2/a
Discount rate 8% 8%Economic lifetime 15 15 aCapital costs 253.869 9.079.568 EUR/a
NG costs 0,030 0,015 EUR/kWhElectricity costs 0,065 0,050 EUR/kWhAnnual NG costs 580.850 51.000.000 EUR/aAnnual electricity costs 14.065 -6.000.000 EUR/a
Maintenance 21.730 2.331.491 EUR/aNumber of operators 0 10Labour costs 0 50.000 EUR/a/operatorLabour 0 500000 EURaO&M total 21.730 2.881.501 EUR/aH2 costs 0,065 0,024 EUR/kWh
H2 costs 0,194 0,071 EUR/Nm3H2
Hydrogen production costs from SMRfor on-site and large plant [€/Nm³H2]
Source: LBST
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Specific investment costs of SMRsas function of capacity [Nm³H2/hr]
Source: HyWays, 2006
0
1.000
2.000
3.000
4.000
5.000
6.000
7.000
8.000
1 10 100 1.000 10.000 100.000 1.000.000
Capacity [Nm3/h]
Sp
ecif
ic in
vest
men
t [€
/(N
m3 /h
)]
SMR
Bio gasif
Electr.
Coal gasif
with CCS
in-situ gasificationwith CCS
with CCS
without CCS
large electrolysis unit &
HP electrolysis
HyGear (500 Nm³/h):~3,000 €/(Nm³/h)
onsite SMR
central SMR
Investment scales strongly with plant size!
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Hydrogen production costsInternational data compilation [€/kg]
Source: NextHyLights, 2010
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Evolution and selected milestones of EU‘s H2/FC-strategy
2002 200520042003 2006 2007
Vision Report: “Hydrogen energy and Fuel Cells – A vision of our future”June 2003
Hig
h Le
vel G
roup
H2
and
FC
(200
2-20
03)
EU Hydrogen&Fuel Cell Technology Platform founded January 2004 with participation of major stakeholders
Two key documents“Strategic Research Agenda” and “Deployment Strategy”Endorsed at HFP General Assembly March 2005
Strategic combination of both reportsJune/October 2005
“Operations Review Days”December 2005
HFP General AssemblyImplementation Plan endorsedOctober 2006
HyWays EU-H2-RoadmapJoint TechnologyInitiative kicked off
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Hydrogen production mix GermanyGermanHy - German Hydrogen Energy Roadmap
The future mix of energies for H2 production will depend on political targets and support, as well as technological achievements
Hydrogen to be produced from different primary energy sources depending on scenario and respective share of individual sources
political imperative: share of renewable energies
at least 50%
Shares of primary energy carriers in hydrogen production
100 PJ
480 PJ
100 PJ
470 PJ
90 PJ
440 PJ
‘Moderate’
‘Climate’
‘Resources’
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Hydrogen admixture to natural gas gridNaturalHy – European stakeholder study
Source: M.-B. Hägg, D. Grainger, J. A. Lie;Dept. of Chem. Eng., NTNU; NaturalHy, 2004
(e.g into storage cavern)
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Source: Onno Florisson, Gasunie, NaturalHy, 2007
• H2 does not separate from a layer of H2/NG in a confined room
• H2 has a significant impact on the laminar and turbulent flame velocity
• Mixtures up to 50% H2 in NG are not critical for the crack propagation in X52 steel pipes
• The permeability of H2 through PE pipes is about 8x the permeability of NG
Some results highlighted
Hydrogen admixture to natural gas gridNaturalHy – European stakeholder study
Admixture is option for „greening“ NG in public grids.
BUT:
H2-NG mixtures do not provide fuel for fuel cells.
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Automotive manufacturers‘ FCEV strategies
2010 20202015
Daimler
Fiat
PSA
Nissan Renault
Volkswagen
Ford
GM
Toyota
Honda
Hyundai Kia
SAIC
64A-class
2011 2012 2013 2014 2016 2017 2018 2019 2021
200 B-class
2009
1,000 B-class 10,000 p.a. B-class100,000 p.a.
C-class
20H2CNG Panda
> 20Panda
< 10FCVs
20 X-Trail FCV
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30 FCVs
110 Equinox 10,000 FCVs 100,000 FCVs 250,000 FCVs
>100 FCHV-adv FCV Sedan
200 FCX Clarity 1,000
> 100 1,000 10,000 30,000 100,000
6Rowe 750
190Rowe 750
Riversimple 30 5,000
307 CC FiSyPAC
Source: GM, LBST compilation
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Key data of fuel cells for transport
Source: Daimler, 2010
Massive technical learning!
Remaining challenges: FC system costs and H2-infrastructure
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Japan – Hydrogen and Fuel Cells Strategy
Source: Ishitani 2010
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Japan - H2- fueling stations in field test
Source: Monde 2010
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500 km major trunk roads
15 Quantum ToyotaH2 hybrid
1st fuelling station at Grenland
HyNor – (Extendable) Norwegian H2 Corridor
15 Mazda RX8H2 Wankel
Stavanger fuelling station
5 Th!nk (FCrange extender)
2 Alfa RomeoMiTo FC
10 DaimlerB-classF-CELL
5 vanHoolFC buses
2 70 MPa and 1 35 MPafuelling stations in Oslo
Økern, West Oslo, Lillestrøm
New EU Lighthouse cluster Oslo
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Possible hydrogen production mix NorwayNorWays – Norwegian Hydrogen Energy Roadmap project
0
20000
40000
60000
80000
100000
120000
140000
160000
180000
200000
2010 2015 2020 2025 2030 2035 2040 2045 2050
t H
ydro
gen
/a Biomass gasification
Byproduct hydrogen
NG-SMR
Electrolysis
0%
10%
20%
30%
40%
50%
60%
70%
80%
90%
100%
2010 2015 2020 2025 2030 2035 2040 2045 2050
%
>2020, central NG SMR (without carbon capture) and onsite electrolysis >2035, more electrolysis (sparsely populated areas deployed; increasing NG prices) By-product hydrogen, biomass gasification and SMR with CCS
do not appear economic under current assumptions.
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Hydrogen as future export opportunityNorWays – Norwegian Hydrogen Energy Roadmap project
LH2LH2
GTGT
SMRSMR
Chain 4b
Chain 4a
Chain 3b
Chain 3a
Chain 2b
Chain 2a
LNGLNG
LH2LH2
H2H2
SMRSMR
NGNG
H2H2
Chain 1a
Chain 1b
GH2
GH2
SMRSMR
LH2
LH2
GTGT
SMRSMR
650 km
650 km
580 km
650 km
50 km
2400 km
2400 km
2400 km
1800 km HVDC land 580 km sea
100 km
North
South
HydrogenElectricityNatural gas
Export of hydrogen from NG seems inferior to direct NG export (given the feasibility of CO2 storage at the destination)
Export of hydrogen from renewable energy from Norway to central Europe seems advantageous against HVDC in the future!
Source: NorWays 2008
46
H2 cars and fuelling stations worldwide
www.h2mobility.org
Source: LBST
www.h2stations.org
290 entries worldwide29 operated on NG ((de-)central+trucked LH2)147 in operation (out of which 16+ public)23 decommissioned, 7 under construction95 planned, or plans given up (e.g. Mexico)
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Weindorf, Bünger: Verfahren zur Reinigung von Wasserstoff für den Einsatz in kleinen Brennstoffzellen (in German), 1996.
Scholz: Verfahren zur großtechn. Erzeugung von Wasserstoff und ihre Umwelt-problematik. Berichte aus Technik & Wissenschaft 67/1992, Linde, pp. 13-21.
Ullmann’s Encyclopedia of Industrial Chemistry, Vol. B3, unit operations II, VCH, 1988, pp. 9-1 - 0-52.
Meyer Steinberg: Modern and prospective technologies for hydrogen production from fossil fuels, Int. J. Hydrogen Energy, Vol. 14, No. 11, pp. 797-820, 1989.
European High Level Group on Hydrogen&Fuel Cells: Hydrogen Energy and Fuel Cells – A Vision of Our Future, http://europa.eu.int/comm/research/rtdinfo_en.html, 2003.
The Hydrogen Economy – Opportunities and Challenges, Editors M. Ball, M. Wietschel, Cambridge University Press, 2009, ISBN 978-0-521-88216-3.
Selected Literature