226 co2 capture from igcc by low-temperature syngas ... · process flow diagram ... low-temperature...
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CO2 capture from IGCC by low-2 p ytemperature syngas separation
d ti l d ti f COand partial condensation of CO2
TCCS-6 Conference, June 15th 2011, TrondheimDavid Berstad, Petter Nekså, Rahul Anantharaman
[email protected] Energy Research
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Presentation outline
Brief introduction to the DECARBit projectBrief introduction to the DECARBit project Vapour-liquid equilibria in H2–CO2 systems
Gives the expected CO2 capture ratio for phase separationp 2 p p p
Principal process-level design for low-temperature syngas separation and CO2 capture
Main results from process simulations Conclusions
22
The DECARBit project (2008–2011)p j ( ) Assess and research new techniques for pre-combustion CO2
tcapture Develop advanced oxygen production techniques Continue the development efforts in FP6 projects in the pre- Continue the development efforts in FP6 projects in the pre
combustion area for key enabling technologies Underpin the cost reduction objective Establish collaborative schemes with emerging large-scale CCS
initiatives in Europe Perform an assessment of the advanced pre-combustion capture Perform an assessment of the advanced pre combustion capture
techniques to the benefit of other energy intensive industries
33
The DECARBit project (2008–2011)p j ( )
CO2-selective membranes
CO b t CO2 sorbents Novel solvent systems Low-temperature
syngas separation
44
y g p
The DECARBit project (2008–2011)p j ( )
Unit Syngas after H2S removal, sweet shift and H O removalH2O removal
Temperature °C 30Pressure bar 35.0Flowrate kg/s 114Composition mol-%
H2 54.14CO 1.73CO2 38.39N2 4.792 9Ar 0.94H2O ppm levels
H S ppm levelsH2S ppm levels
Other 0.02
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H2–CO2 vapour-liquid equilibria2 2 p q q100 %
Binary H2–CO2 mixtures at 220 K / -53°C
70 %
80 %
90 %o
50 %
60 %
apture ratio
Spano: 40% H2, 60% CO2
T&S: 40% H2, 60% CO2
PR: 40% H2, 60% CO2
Spano: 50% H2, 50% CO2
T&S 50% H2 50% CO2
20 %
30 %
40 %
CO2ca T&S: 50% H2, 50% CO2
PR: 50% H2, 50% CO2
Spano: 60% H2, 40% CO2
T&S: 60% H2, 40% CO2
PR: 60% H2, 40% CO2
Spano: 70% H2 30% CO2
0 %
10 %
0 10 20 30 40 50 60 70 80 90 100 110 120
Spano: 70% H2, 30% CO2
T&S: 70% H2, 30% CO2
PR: 70% H2, 30% CO2
0 10 20 30 40 50 60 70 80 90 100 110 120
Pressure [bar]Spano J, Heck C, Barrick P. Liquid-vapor equilibria of the hydrogen–carbon dioxide system. J. Chem. Eng. Data. 13(2), 169–171 (1968).Tsang C, Streett W. Phase equilibria in the H2/CO2 system at temperatures from 220 to 290 K and pressures to 172 MPa, Chem. Eng. Sci. 36, 993–1000 (1981)
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1000 (1981).
Vapour-liquid equilibriap q q60% H2 – 40% CO2 mixture
100 % Target: ≥ 85% capture ratio
80 %
90 %
Target: ≥ 85% capture ratio
50%
60 %
70 %
ure ratio
30 %
40 %
50 %
CO2capt
217 K / ‐56°C
218 K / ‐55°C
0 %
10 %
20 % 219 K / ‐54°C
220 K / ‐53°C
0 %
0 10 20 30 40 50 60 70 80 90 100 110 120
Pressure [bar]
77
Process flow diagramg
Auxiliary refrigeration (Propane)
Power recovery expander
H2-rich fuel to gas turbine
(25 bar)
Shifted syngas(35 bar)
Recycle Auxiliary refrigeration (Ethane) H2-rich phase
Phase separation
CO2-rich phase
CO2(110 bar)
CO2purification
88
CO2 pump
Process flow diagramg
Auxiliary refrigeration (Propane)
Compression of syngas feed to 110 bar Pressure ratio: 3.1–3.2 Power: 21–23 MW
Power recovery expander
H2-rich fuel to gas turbine
(25 bar)
Shifted syngas(35 bar)
Recycle Auxiliary refrigeration (Ethane) H2-rich phase
Phase separation
CO2-rich phase
CO2(110 bar)
CO2purification
CO2 pump
99
Process flow diagramg
Ethane utility cooling
Auxiliary refrigeration (Propane)
Ethane utility cooling Syngas temperature: -56°C Vapour fraction: 0.64 (molar basis)
0.26 (mass basis)
Power recovery expander
H2-rich fuel to gas turbine
(25 bar)
Shifted syngas(35 bar)
Recycle Auxiliary refrigeration (Ethane) H2-rich phase
Phase separation
CO2-rich phase
CO2(110 bar)
CO2purification
CO2 pump
1010
Process flow diagramg
Auxiliary refrigeration (Propane)
>15 MW of combustibles (LHV basis) recovered from the CO2purification section (0.4 MW lost).
Power recovery expander
H2-rich fuel to gas turbine
(25 bar)
Shifted syngas(35 bar)
Recycle Auxiliary refrigeration (Ethane) H2-rich phase
Phase separation
CO2-rich phase
CO2(110 bar)
CO2purification
Recycle compression power: 2.3 MWCO2 pumping power: 0.9 MW
CO2 pump
1111
Process flow diagramg
Auxiliary refrigeration (Propane)
Liquid phase 99.7% CO2 81.2 kg/s
Power recovery expander
H2-rich fuel to gas turbine
(25 bar)
Shifted syngas(35 bar)
Recycle Auxiliary refrigeration (Ethane) H2-rich phase
Phase separation
CO2-rich phase
CO2(110 bar)
CO2purification
CO2 pump
1212
Process flow diagramg
Auxiliary refrigeration (Propane)Expansion of fuel to 25 bar Recoverable power: 13–14 MW
Power recovery expander
H2-rich fuel to gas turbine
(25 bar)
Shifted syngas(35 bar)
Recycle Auxiliary refrigeration (Ethane) H2-rich phase
Phase separation
CO2-rich phase
CO2(110 bar)
CO2purification
CO2 pump
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Main results
35090%
CCR and specific capture work
325
350
85 %
90 %
g CO2]
o
300
325
75 %
80 %
ork [kJ/kg
ture ra
tio
27570 %
apture wo
CO2capt
CO2 capture ratio
25060 %
65 % Ca
O captu e at o
Capture work
30 40 50 60 70 80 90 100 110 120
Syngas pressure [bar]
1414
Main resultsPower consumption decomposed
40CO2 i
14,555
25
30
35CO2 pumping
Recycle compression
Aux. refrigeration
Syngas compression
Expansion recovery
16,172
15,994
15
20
25
[MW]
Expansion recovery
Net power
7,237
13,480
22,793
16,330
5
10
Power [
‐2,441‐5,987
‐9,243‐13,918
‐10
‐5
0
‐15
10
35 bar 52 bar 72 bar 110 bar
Syngas pressure
1515
Syngas pressure
Main results
Isentropic efficiency
Simulation parameters
Isentropic efficiencySyngas compressor % 82Propane compressor % 82Eth % 82Ethane compressor % 82Recycle compressor % 80Power recovery fuel expander % 85Liquid CO2 pump % 80
Pressure dropHeat exchangers bar 0.2Inter‐ and after‐coolers bar 0.5
Temperature approachHeat exchanger pinch °C 3Heat exchanger pinch C 3LMTD in propane–ethane cascade heat exchanger °C > 5
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Concluding remarksg A conceptual low-temperature syngas separation process for CO2
capture from IGCC has been developed and simulatedcapture from IGCC has been developed and simulated 85% capture ratio is achievable for shifted syngas with a CO2
concentration of 38 mol-%. Specific capture work for the considered system boundaries is around 330 kJ per kg CO2 captured
Partial capture is possible without the need of pre-compression Refrigeration cycles account for a significant part of the power Refrigeration cycles account for a significant part of the power
consumption and must be optimised Simulation of the overall IGCC with CO2 capture is required in order
to obtain a justified benchmarking with baseline technologies Syngas conditioning (water removal and desulphurisation) must be included
Overall performance analysis and techno-economic assessment, Overall performance analysis and techno economic assessment, equipment sizing and costing will be carried out in the last phase of DECARBit
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Acknowledgementsg
Participating industry partners
Funding industry partners
The research leading to these results has received funding from the European Union’s Seventh Frameworkfunding from the European Union s Seventh Framework Program (FP7/2007–2011) under grant agreement number 211971 (the DECARBit project).number 211971 (the DECARBit project).
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