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Paul H.M. Feron
European CO2 Capture and Storage Conference
Towards Zero Emission Power PlantsBrussels 13-15 April 2005
Progress in post-combustionCO2 capture
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Presentation Overview CO2 capture technologies
Post-combustion capture: State of the art
Solvent technologiesPerformances
Post-combustion capture: Advanced processes
Improved solvent technologies
Other processes
Link to Hypogen
Conclusions
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What are challenges for CO2 capture?
Capture of CO2 can be done with technologies presently
available but:
Power generation costs will increase
More fossil fuel needed for same power generationcapacity
Increased reliance on fossil fuels on top of the existing
upward trend; increasing the supply security concerns
There is no experience with CO2 capture at the power
plant scale
Therefore the following questions need to be addressed:
How to reduce the additional power consumption as aresult of the capture process?
How to reduce the costs of the capture?
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Decarbonisation routes for power plants
air
separation
energy
conversionair
fuel
N2 CO2
powerO2
fuel
conversion
CO2
separation
air
fuel
power
flue gasenergy
conversionH2
air
CO2
energy
conversion
CO2separation
air
fuel
power CO2
flue gas Post-combustion
Pre-combustion
Denitrogenation
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The CO2 Capture toolkit: A portfolio approach
Combustion in
O2/CO2/H2O
atmosphere
Hydrogen combustionNovel power cyclesE-Conversion
Biomimetic
approaches
High pressure applicationsAlgae production
Biomimetic approachesBiotechnology
n.a.Direct decarbonisationn.a.Carbon extraction
O2/N2 absorbentNew solvents
Contactors
Process design
New solvents
Contactors
Process design
Solvents
O2/N2 adsorbents
High T adsorbents
Dolomite
Zirconates
Lime carbonationSorbents
Distillation for air
separation
CO2/H2 separationsLiquefactionCryogenic
O2-conducting
membranes
CO2/H2-separation: Ceramic,
polymeric, palladium,
membrane absorption
Membrane absorption,
polymeric, ceramic, FT, carbon
membranes
Membranes
DenitrogenationPre-combustionprocesses
Post-combustionprocesses
Capture method
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Leading technologies for CO2
capture(IEA GHG R&D programme - 2000)
Coal fired power stations
Base case: Pulverised coal fired power station
Post-combustion capture: 47 $/tonne CO2Pre-combustion capture: 54 $/tonne CO2
Gas fired power stationsBase case: Natural gas fired combined cycle
Post-combustion capture: 32 $/tonne CO2
Pre-combustion capture: 39 $/tonne CO2
Conclusion: There is no clear winning CO2 capture
technology
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Solvent process flow sheet
Absorber Regenerator
Heat exchanger
CondenserFlue gas out
Flue gas in
Reboiler
Cooler
CO2out
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State of the art post-combustion CO2-capture
State of the art = Amine based absorption processes:
Fluor Daniel Econamine FGSM
30% MEA solution incorporating additives to control corrosion and(oxidative and thermal) degradation
> 20 commercial plants in sizes between 0.2 and 15 tonnes CO2/h ABB-Lummus
15-20% MEA solution 4 commercial plants in size between 6 and 32 tonnes CO2/h Mitsubishi Heavy Industries
KS-1 sterically hindered amines 1 commercial plant: 9 tonne CO2/h
CANSOLV Mixture of amines no commercial plant
Praxair Mixture of amines no commercial plant
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Advantages post-combustion capture
Add-on to existing power plants and plant concepts
Capture technologies available, i.e. solvent
technologies, which are proven on a smaller scale
Similarities with cogeneration plant lead to proven
methods for integration
Flexibility in switching between capture no capture Learning by doing will lead to cost reductions similar
to experience with SO2 capture process development
Learning by searching will lead to better solvents andprocesses
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Thermal energy requirement for solvent
processes
Specific thermal energy requirement
0
1
2
3
4
5
6
0 50 100 150 200
Cyclic loading [tonne CO2/1000 m3 solvent]
Regeneratio
nenergy
[GJ/tonn
eCO2
]
Hc
R=0.4
R=0.8
R=1.2
5 M MEA
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Post-combustion capture process performances:
Past, present and future
0.196 kWh/kg CO20.306 kWh/kg CO20.446 kWh/kg CO2Total
0.103 kWh/kg CO20.108 kWh/kg CO20.114 kWh/kg CO2CO2 compressor
0.010 kWh/kg CO20.020 kWh/kg CO20.040 kWh/kg CO2Power for capture
0.083 kWh/kg CO2(0.15)
0.178 kWh/kg CO2(0.20)
0.292 kWh/kg CO2(0.25)
Power equivalent
(Factor used)
2.0 GJ/tonne CO23.2 GJ/tonne CO24.2 GJ/tonne CO2Thermal energy
201520051995Year
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Post-combustion capture in a coal fired power plant
(Emission factor: 0.1 tonne CO2/GJ)
82 kg CO2/MWh103 kg CO2/MWh141 kg CO2/MWhEmission with
90% capture
43.6 %35.1 %25.5 %Plant efficiency
with 90% capture
0.196 kWh/kg CO20.306 kWh/kg CO20.446 kWh/kg CO2Power loss due to
capture
720 kg CO2/MWh800 kg CO2/MWh900 kg CO2/MWhBase plant
emission
50 %45 %40 %Base plantefficiency
201520051995Year
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Development of capture technology hand in hand
with generation efficiency improvements
CO2 Emmision vs generation efficiency
coal fired power plant
0,0
0,2
0,4
0,6
0,8
1,0
0,25 0,35 0,45 0,55 0,65 0,75
Efficiency [-]
C
O2-emission
s[kg/kWh]
No capture
Max. efficiency
With capture
2015
1995
2005
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Issues for post-combustion CO2-capture
Solvent technologies are leading option but: Power cost increases >50% Generation efficiency decreases by 15 25%
Solvent process break-throughs required Energy consumption Reaction rates
Contactor improvements Liquid capacities Chemical stability/corrosion Desorption process improvements Hence cost reductions
Integration with power plant Heat integration with other process plant, particularly in relation to
desorption process
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CASTORCASTORCOCO22, from Capture to Storage, from Capture to Storage
a European Integrated Projecta European Integrated Project
(IFP(IFP Project Coordinator)Project Coordinator)
Castor
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Consortium participants
R&DIFP (FR)TNO (NL)SINTEF (NO)NTNU (NO)BGS (UK)BGR (DE)
BRGM (FR)GEUS (DK)IMPERIAL (UK)OGS (IT)TWENTE U. (NL)STUTTGARTT U. (DE)
Oil & GasSTATOIL (NO)GDF (FR)REPSOL (SP)ENITecnologie (IT)ROHOEL (AT)
Power CompaniesVATTENFALL (SE)ELSAM (DK)ENERGI E2 (DK)RWE (DE)PPC (GR)POWERGEN (UK)
ManufacturersALSTOM POWER (FR)MITSUI BABCOCK (UK)SIEMENS (DE)BASF (DE)GVS (IT)
Co-ordinator: IFP
Chair of the Executive Board: Statoil
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CASTOR main components
SP1 Strategy for CO2Reduction
WP1.1 Development of CO2reduction strategies
WP1.2 Geological storage
options for CO2 reduction
strategy
SP2 CO2 Post-CombustionCapture
WP2.1 Evaluation, optimisation
& integration of post-combustion
capture processes
WP2.2 Solvent development
WP2.3 Development of membrane
based solvent processes
WP2.4 Advanced processes
WP2.5 Process validation in
pilot plant
SP3 CO2 storageperformance
& risk assessment
studies
WP3.1 Field case "Casablanca"
WP3.2 Field case "Lindach"
WP3.3 Field case "K13b"
WP3.4 Field case "Snohvit"
WP3.5 Preventive & corrective
actions
WP3.6 Criteria for site
selection and
site management
Management
Dissemination
WP0.1 Project Management
WP0.2 Dissemination & Training
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Current costs
contribution
Cost
contribution byadvanced
process
Effected by
Investment costs
Absorber 25 % 10 15% Compact contactor
Simplified cost-optimised contactors
Membrane contactorsRest of equipment
(desorber, heat
exchangers)
25 % 10 15 % Halving of solvent flow rate
Optimised operational conditions for
advanced solvents
Total investment 50 % 20 30 %
Operational costs
Thermal energy 25% 10 15 % Halving of energy consumption through use of
advanced solvents (novel chemicals, additives
with low vaporisation enthalpy)
Integration of heat exchanger in desorber
Rest (cooling,
electricity,
chemicals)
25% 10 15 % Halving of solvent flow rate
Optimised operational conditions for
advanced process technologies and solventsSolvent stability improvements
Total operation 50 % 20 30 %
Total costs 100% 40 60 %
Estimate of contributions to the capture costs
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CASTOR SP2 Work package structure
WP 2.1: Evaluation, Optimisation and Integration of post-combustion capture
WP 2.5: Pilot plant validation with real flue gases
WP 2.2:
New solventdevelopment
WP 2.3:
Membrane
contactor
development
WP 2.4:
Advanced
process
development
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European post-combustion test facility
Capacity: 1 t/h CO2 capture
5.000 Nm3/h fluegas
(coal combustion)
In operation early 2006
4. marts 2004 2
Esbjergvrket
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CO2 Membrane Gas Absorption can reduce
investment costs
CO2, present in the flue gas, is selectively absorbed into a
proprietary absorption liquid through a porous membrane
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DECAB process flow diagram
Absorber
Flue gas in
Flue gas out
Reboiler
Heat exchanger
Cooler
Stripperwithintegratedheatexchanger
Condenser
60o
C Slurry
80 oC
90 oC
70 oC40 oC
Liquid
120 oC
CO2 out
90o
C
CO2
CO2
Precipitation the absorber will result in high loading of the
solvent and hence reduction of costs
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Other CO2
separation technologies
Adsorption processes
Sorbent development (selectivity, high temperature)
Scale-up (circulating fluidised bed, rotating wheels) Membrane processes
Membrane development (selectivity, high temperature)
Scale-up (using modularity)
Cooling processes Anti-sublimation process (CO2 available at high pressure)
Scale-up (available process equipment)
Process suitability will benefit from increased CO2 concentration:Use of flue gas recirculation and oxygen enrichment
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HICLON (High CO2/Low N2-capture process)
AirEnrichedair
N2
Exhaust gas
Fluegas
Recycle
O2 enrichment
Fuel
CO2Power
Energy conversion CO2 separation
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Linking post-combustion capture to
production of hydrogen and electricity(Hypogen concept)
Current lowest cost hydrogen production based on fossil
fuels (gas, coal) First step is fuel conversion, producing mixture of mainly
hydrogen and carbon monoxide
Next step is separation into hydrogen rich stream and
carbon monoxide rich stream using e.g. polymeric
membranes
Hydrogen supplied to end-users; Carbon monoxide as
fuel gas to gas turbine; Post-combustion capture from high CO2 content flue
gases
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Conclusions
At present there is no best technology for CO2capture, but there are several options
Post-combustion capture presents the approach with
least impact on power generation processes Potential for improvement by doing and searching
is large
CASTOR IP is aimed at achieving this potential Post-combustion capture is also applicable in a power
generation system with co-production of hydrogen.