Upload
lamtruc
View
221
Download
2
Embed Size (px)
Citation preview
Chemical Looping Technology –Reaction, Reactor and Solids Flow
Issues
L. S. FanDepartment of Chemical and Biomolecular
Engineering The Ohio State University
Columbus, Ohio 43210
by
August 17, 2011
0
10
20
30
40
50
60
70
80
90
0 20 40 60 80 100
% Electricity
Ov
era
ll P
roc
ess
Eff
icie
nc
y
0
10
20
30
40
50
60
70
80
90
SCL
Gasfication-WGS
IGCC-SELEXOL
Subcritical MEA
Ultra-supercritical MEA
Ultra-Supercritical Chilled Ammonia
Syngas CLC
H2 Membrane WGS
CO2 Membrane WGS
CDCL
Comparison Among Gaseous Chemical Looping, Direct Coal Chemical Looping and Traditional Coal to Hydrogen/Electricity Processes
Assumptions used are similar to those adopted by the USDOE baseline studies.
BasePlant
MEAPlant
CDCLPlant
Coal Feed, kg/h (lb/h)198,391
(437,378)278,956
(614,994)210,118
(463,231)
CO2 Emissions, kg/MWhnet (lb/MWhnet)856
(1,888)121
(266)~0
(~0)
CO2 Capture Efficiency, % 0 90 ~100
Solid Waste,a kg/MWhnet (lb/MWhnet)35
(77)49
(108)39
(87)
Net Power Output, MWe 550 550 550
Net Plant HHV Heat Rate, kJ/kWh (Btu/kWh)
9,788(9,277)
13,764(13,046)
10,357(9,817)
Net Plant HHV Efficiency, % 36.8 26.2 34.8
Energy Penalty,b % - 29 5
Aspen Plus® Modeling Results
aExcludes gypsum from wet FGD. bRelative to Base Plant; includes energy for CO2 compression.
Topics
• Two Types of Chemical Looping Systems
• Particle Synthesis and Ionic Diffusion Mechanism
• Modes of Reactor Operation
• Stability of Solids Flow
• Chemical Looping System Efficiency
• Commercialization Potential
5
Chemical Looping for Fossil Fuel Conversions
Two typical types of looping reaction systems
Oxygen Carrier (Type I)
Me/MeO, MeS/MeSO4
CO2 Carrier (Type II)
MeO/MeCO3
“1st Meeting of High Temperature Solids Looping Cycle
Network”, Oviedo, Spain, September 15-17 (2009).
“1st International Conference on Chemical
Looping”, Lyon, France, March 17-19 (2010).
Macroscopic Properties of Calcium OxideSintered_CaO
Hydrated_CaO
- Hydrated_CaO has smaller particles size - Hydration caused cracks on the surface
7
Fuels &
ChemicalsAir
Separation
Hydrogen
Fuel
Cell
Steam
Slag Steam
Turbine
Gas Turbine
Air
Compressor
Stack
HRSG
Rotary
Calciner
INTEGRATED
WGS +H2S
+COS + HCL
CAPTURE
Generator
Gasifier
BFW
To Steam
Turbine
CO2
Air
Air
Oxygen
CaO
CaCO3
Steam
H2+O
2
OSU Calcium Looping
Process
HeatOutput Heat
Input
Pure CO 2 gas
Calcination: CaCO 3 CaO + CO 2
CO + H 2O CO 2 + H 2
CaO + CO 2 CaCO 3
CaO + H 2S CaS + H 2OCaO + COS CaS + CO 2
Chloride CaO + HCl CaCl 2 + H 2O
Syngas
Hydrogen
reactor
RegenerationReaction
HeatOutput Heat
Input
Pure CO 2 gas
Calcination: CaCO 3 CaO + CO 2
WGSR : CO + H 2O CO 2 + H 2
CO2 removal : CaO + CO 2 CaCO 3
Sulfur : CaO 2S CaS OCaO CaS + CO 2
: CaO + HCl CaCl 2 + H 2O
Syngas
Hydrogen
Hydrogen reactor
CaCO3
CaO
Calciner
Calcium Looping Sub-pilot Unit for Hydrogen production
Air
Separation
Unit
Gasifier
Quench
Shift
Reactors
Syngas
Scrubber
2-Stage
Selexol
Coal Prep
and Feed
Slag
Handling
CO2
Compression
Dehydration
Pressure
Swing
Adsorber
Boiler
Radiant
Cooler
Syngas
Cooling
Mercury
Removal
Claus
Plant
Steam
TurbineCoal
Water
Air
Slag
Sulfur
Flue Gas
Pure H2
CO2
Air
220,904 kg/h
1316°C
56 bar
464,968 kg/h
677°C
56 bar
153 bar
0.999 v/v H2
≥ 22 bar
Base Coal-to-Hydrogen Process
Air
Separation
Unit
Gasifier
Coal Prep
and Feed
Slag
Handling
CO2
Compression
Dehydration
Pressure
Swing
Adsorber
Radiant
Cooler
Steam
TurbineCoal
Water
Slag
Pure H2
CO2
Air
220,904 kg/h
1316°C
56 bar
153 bar
0.999 v/v H2
≥ 22 bar
464,968 kg/h
677°C
56 bar Calcium
Looping
Process
Coal
Limestone
Solid Waste
CLP Coal-to-Hydrogen Process
CLP Process Flow DiagramCoal-to-Hydrogen Plant
Syngas
from
Radiant
Cooler
Coal
Solids Purge
Limestone
Expander Ca
rbo
na
tor
CycloneFiretube
Boiler
Condensing
Heat
Exchanger
Condenser
H2 to
PSA
PSA
TailgasCa
lcin
erVent Gas
AirASU
Hy
dra
tor
H2O
CO2 to
Compression
CO2 Recycle
Cyclone
Fabric
Filter
Condenser
CaCO3
CaO
Ca(OH)2
O2
HRSG
Lockhopper
Lockhopper
Ash
Indicates heat is
recovered for steam cycle
650°C
23 bar
Ca/C = 1.3 mol/mol
875°C
1 bar
677°C
56 bar
464,968 kg/hLockhopper
Cyclone
Exhaust
Gas
Coal-to-Hydrogen Case SMR Case
BasePlant
CLPPlant
BasePlant
CLPPlant
First-Year Capital ($/kg) $2.26 $2.58 $0.62 $0.96
Fixed O&M ($/kg) $0.43 $0.57 $0.16 $0.26
Fuel ($/kg) $0.36 $0.55 $1.22 $1.40
Electric Powera ($/kg) -$0.03 -$1.13 $0.14 -$0.70
CO2 Emissions ($/kg) $0.06 $0.00 $0.03 $0.00
Other Variable O&M ($/kg) $0.04 $0.14 $0.02 $0.05
TOTAL FIRST-YEAR COH ($/kg) $3.12 $2.72 $2.19 $1.98
TOTAL FIRST-YEAR COE ($/MWh) $105.00 $91.61 $105.00 $94.91
∆ = -13%
Economic Analysis ResultsCoal-to-Hydrogen and SMR Cases
aComputed using electricity price equal to the total COE value shown in the table.
∆ = -10%
13
ε ≈ 1
Partial oxidation
/Gasification
ε = 0.88
H2 + CO
407.7 kJ
358.9 kJ
0 Heat Loss
48.8 kJ Exergy Loss
Water Gas Shift
H2 +CO2
393.4 kJ
322.9 kJ
ε = 0.82
ε = 0.89
Fe
514.8 kJ
456.4 kJFe3O4 @1023K
(0.395 mol)
107.1 kJ
71.9 kJ
ε = 0.669
14.3 kJ Heat Loss
36 kJ Exergy Loss
H2 + Fe3O4
485.5 + 107.1 kJ
396.9 +71.9 kJ
ε = 0.82
Carbon
407.7 kJ/mol
407.7 kJ/mol
23.2 kJ Exergy Loss77.8 kJ thermal
energy @ 380 K
12.41kJ Exergy
ε = 0.16
Partial oxidation
I
II
Substance
Enthalpy of degradation
Exergy
Exergy Rate (ε)
Energy/Exery Loss
Additional Energy Input
Final Product
ε ≈ 1
Partial oxidation
/Gasification
ε = 0.88
H2 + CO
407.7 kJ
358.9 kJ
0 Heat Loss
48.8 kJ Exergy Loss
Water Gas Shift
H2 +CO2
393.4 kJ
322.9 kJ
ε = 0.82
ε = 0.89
Fe
514.8 kJ
456.4 kJFe3O4 @1023K
(0.395 mol)
107.1 kJ
71.9 kJ
ε = 0.669
14.3 kJ Heat Loss
36 kJ Exergy Loss
H2 + Fe3O4
485.5 + 107.1 kJ
396.9 +71.9 kJ
ε = 0.82
Carbon
407.7 kJ/mol
407.7 kJ/mol
23.2 kJ Exergy Loss77.8 kJ thermal
energy @ 380 K
12.41kJ Exergy
ε = 0.16
Partial oxidation
I
II
Substance
Enthalpy of degradation
Exergy
Exergy Rate (ε)
Energy/Exery Loss
Additional Energy Input
Final Product
I. Contional Process
Exergetic Efficiency
322.9/407.7 = 79.2%
II. Chemcial Looping Process
Exergetic Efficiency
396.9/(407.7 + 12.41)=94.5%
Exergy Analysis on Hydrogen Production
14
Historical Development of Chemical Looping Technologiesfor Fossil Energy Conversions
TechnologiesLane Process and
Messerschmitt Process
Lewis and
Gilliland ProcessIGT HYGAS Process
CO2 Acceptor
Process
Time Early Twentieth Century 1950s 1970s 1970s
Looping Media Fe/FeO/Fe3O4 Cu2O/CuO FeO/Fe3O4 CaO/CaCO3
Reactor Design Fixed bed Fluidized bed Staged fluidized bed Fluidized bed
Lane Process
Lewis and Gilliland Process
IGT Process
CO2 Acceptor Process
15
IGT Steam Iron HYGAS Process
MO=> M M=> MO
Gas Conversion (%) 65 45
Solid inlet 80% Fe3O4- 20% FeO 95% FeO- 5% Fe
Temperature (oC) 900 900
Reactor Fluid Bed Fluid Bed
– Poor solid phase conversions: Used only about 25% oxygen
capacity of the particles.
– Low gas phase conversions:
– Used iron ore: Low reaction rates
– Only about 40% efficient
– The process not geared towards making pure CO2
Poor Thermo
Recyclability of Commercial Fe2O3
17
Performance of Composite Fe2O3
0
50
100
150
200
250
300
350
400
450
Fresh
10 Cycles
100 Cycles
Forc
e (N
)
100 Cycle Pellet Reactivity
100 Cycle Pellet Strength
Oxygen Carrier Selection
Primary Metal Fe Ni Cu Mn Co
Potential Supports Al2O3, TiO2, MgO, Bentonite, SiO2, etc
Cost + – – ~ –
Oxygen Capacity1(wt %) 30 21 20 253 21
Thermodynamics for
CLC
+ ~ + + +
Kinetics/Reactivity2 – + + + –
Melting Points + ~ – + +
Strength + – ~ ~ ~
Environmental& Health ~ – – ~ –
Hydrogen Production + – – – –
1. Maximum theoretical oxygen carrying capacity; 2. Reactivity with CH4; 3. Mn3O4 is the highest oxidation state based on thermodynamics, although not thermodynamically favorable, Mn is assumed to be the lowest oxidation state
Structures of Iron Oxide
NaCl Type
oxygen close-packed
cubic pattern
iron occupy all
octahedral interstices
inverse Spinel Type
FeO Fe3O4
octahedral interstices
1/2 occupation rate
tetrahedral interstices
1/8 occupation rate
20
Pellet Reaction Mechanism – Ionic
Diffusion for Unsupported Iron
21
Partially oxidized Fe with support Pt mapping
Pt Epoxy Resin PtPellet bulk phase
Pellet Reaction Mechanism – Ionic
Diffusion for Supported Iron
Role of Support – Oxidation of Fe and Fe/TiO2Simulation
Energy barrier for O2- can be reduced after support addition
Oxygen anion transfer in Wüstite and Ilemnite
Modes of CFB Chemical Looping Reactor SystemsMode 1- reducer: fluidized bed or co-current gas-solid (OC) flows
Mode 2 - reducer: gas-solid (OC) counter-current dense phase/moving bed flows
Zone 2
Enhancing Gas
Fe
Coal/biomass
Fe2O3CO2/H2O
Zone 1 Zone 1
Zone 2
Zone 3
Zone 4
Coal/biomass
Thomas, T., L.-S. Fan, P. Gupta, and L. G. Velazquez-Vargas, “Combustion Looping Using Composite Oxygen Carriers” U.S. Patent No. 7,767,191 (2010, priority date 2003)
Chalmers University 10-kWth CLC System
Fluidized Bed Reducer
Contercurrent Gas-Solid(OC)
Reducer
fuel/reducing gas
air
Reducer
fuel reaction products
combustor gas
OC
OC
combustor gas
OC
Riser combustor
combustor gas
fuel reaction products
fuel/reducing gas
Reducer
air
OC
combustor gas
OC
OC
Riser combustor
Design Variation from Mode 1 to Mode 2
Original VUT 120-kWth CLC System (2007)
Modified VUT 120-kWth CLC System (2010)
25
Chemical Looping Reactor Design
FeOy
FeOx
CO/H2
CO2/H2O
(x>y)
FeOy CO/H2
(x>y)
FeOx CO2/H2O
Fluidized BedMoving Bed
FeOy CO/H2
(X>Y)
FeOx CO2/H2O
Fluidized Bed Moving Bed
Moving Bed – The Selected Reactor Type
FeOy
FeOx
CO/H2
CO2/H2O
(X>Y)
Fluidized Bed v.s. Moving Bed
Maximum Solid Conversion
Gas Velocity
Particle Size
11.11%
> Umfv
Small
50.00%
< Umfv
Large
Fluidized Bed v.s. Moving Bed
Maximum Solid Conversion
Gas Velocity
Particle Size
11.11%
> Umfv
Small
50.00%
< Umfv
Large
Maximum Solid Conversion
Gas Velocity
Particle Size
11.11%
> Umfv
Small
50.00%
< Umfv
Large
1.E-01
1.E+00
1.E+01
1.E+02
1.E+03
1.E+04
1.E+05
1.E+06
1.E+07
200 400 600 800 1000
Temperature (C)
PC
O2/P
CO
Fe2O3
Fe3O4
FeO
Fe
1.E-01
1.E+00
1.E+01
1.E+02
1.E+03
1.E+04
1.E+05
1.E+06
1.E+07
200 400 600 800 1000
Temperature (C)
PC
O2/P
CO
Fe2O3
Fe3O4
FeO
Fe
Fluidized Bed
Moving Bed
(x>y)
26
Particle Type Ni Cu Fe
Type of Data
Lab
Scale
CFB 120
kW
Lab
Scale CFB 10kW Lab Scale
CFB
300W
Moving Bed -H2
25 kW
Particle Type
NiO/
MgAl2O4
NiO/
MgAl2O4
CuO/
Al2O3 CuO/Al2O3
Fe2O3/
MgAl2O4
Fe2O3/
Al2O3 Composite Fe2O3
Air Flow Rate @1000 MWth and 10% Excess (mol/s) 11784 1309
Volumetric Air Flow Rate at 1 atm and 900 ºC (m3/s) 1134 126
Particle Circulation Rate @ 1000 MWth (kg/s) 4000 10000 3000 6000 8000 10000 800
Reducer Solids Inventory (tonne) 230 160 70total
2100
500 12001500 Total
Oxidizer Solids Inventory (tonne) 390 80 390 n/a 350
Medium Particle Size (μm) 153 120 300 200 153 151 2000
Particle Density (g/cm3) 1.9 5 2.5 2.5 4.1 2.15 2.5
Ut (m/s) 2 0.8 2 1.2 1.1 0.6 11
Uc (m/s) 4 4.8 4.9 4.2 4.8 3.6 4
Use (m/s) 6 6.7 7.5 6.1 6.9 4.9 9.7
Typical Riser Superficial Gas Velocity (m/s) 7.00 12
Bed Area Turbulent Section (if Required) at 1 atm (m2) 231.47 25.18
Bed Area Required for Riser Section at 1 atm (m2) 162.03 10.49
Corresponding Riser Diameter (m) 14.37 3.66
Solids Flux at 1 atm (kg/m2s) 24.69 61.72 18.52 37.03 49.37 61.72 76.23
Number of Beds Needed given 8 m ID Riser 3.23 <1
Number of Beds Needed given 1.5 m ID Riser 91.73 5.94
Ug for a Single 1.5 m ID Riser at 1 atm (m/s) 642.14 71.29
Ug for a Single 8 m ID riser at 1 atm (m/s) 22.58 2.5 (Ug < Ut; N/A)
Required Pressure for a Single 1.5m ID Riser (atm) 91.73 10.00
Solids Flux for a Single 1.5 m ID Riser (kg/m2s) 2264.69 5661.71 1699 3397.03 4529.37 5661.71 452.88
Required Pressure for a Single 8 m ID Riser (atm) 3.23Ug < Ut; N/A
Solids Flux for a Single 8 m ID Riser (kg/m2s) 79.62 199.04 59.71 119.43 159.24 199.04
4000 – 10000 kg/s or 14,000 – 36,000 ton/hour
< 3,000 ton/hour
27
Single Loop High Density CFB System (Kirbas et al., 2007)
Two Loop High Density CFB System (Kulah et al., 2008)
Kirbas G, Kim SW, Bi X, Lim J, Grace JR. Radial Distribution of Local Concentration Weighted Particle Velocities in High Density Circulating Fluidized Beds. Paper presented at: The 12th International Conference on Fluidization - New Horizons in Fluidization Engineering; May 13-17, 2007; Vancouver, Canada.
Kulah G, Song X, Bi HT, Lim CJ, Grace JR. A NOVEL SYSTEM FOR MEASURING SOLIDS DISPERSION IN CIRCULATING FLUIDIZED BEDS. Paper presented at: 9th International Conference on Circulating Fluidized Beds; May, 13 – 16, 2008; Hamburg, Germany.
Circulating Fluidized Bed Systems
Particle Fixed Bed Tests
Bench Scale Tests
Time
Sca
le
Sub-Pilot SCL
Integrated Tests
0
5
10
15
20
25
30
35
40
45
50
0 5 10 15 20 25 30 35
Axil Position (inch)
So
lid
Co
nv
ers
ion
(%
)
0
10
20
30
40
50
60
70
80
90
100
Gas C
on
vers
ion
s (
%)
Solid H2 COParticle Reactivity Confirmed
Maximum Operating Temperature Determined
Reactor Performance Confirmed
OSU Syngas Chemical Looping Process Development
Consolidation and Yield of Bulk Solids
0c
c
fff
: flowability of bulk solids
Flow Properties of Bulk Solids
Stress of Bulk Solids in Vertical Reactor
1
2
1 sin
1 sin
Flowing Condition
Arching Condition
1 2
1 sin
1 sincf
Piling of Bulk SolidsStress Condition of Bulk Solids
fc
Stress Distribution in Flowing Solids
lift upwardW F F
2
0 sW R h g 1 2( )sin 2liftF R h 2
support 0 2F R
22
0
2sin sin 2
(1 sin )s
dg
R dh
2 0( ) ahb b e
0
0
2sin sin 2
(1 sin )
(1 sin )
2sin sin 2s
aR
Rb g
1 2 1 2sin sin 2 (1 sin cos 2 ) tan2 2
xy
sinsin(2 ) sin
sin
2
v
v
Limitation from wall: fully developed wall angle
With counter-current interstitial gas flowDrag force can be treated as a reduction of gravity
0 (1 sin )
2sin sin 2s D
Rb g F
: angle of friction between the powder and the wall
σ0: external normal stress at the top of the solid surface
Stress Distribution in Arched Solids
' min( , / 4) Limiting Condition: Maximum lift force
' 21 2( )sin 2s
dg
dh
2 0( ) ahb b e '
0
0
'
2sin sin 2
(1 sin )
(1 sin ) (1 sin )
2sin sin 2 2sin
cs
aR
R fb g
Requirement for arching: 2 0
With counter-current interstitial gas flow: 0
'
(1 sin ) (1 sin )
2sin sin 2 2sin
cs D
R fb g F
Reactor Size Criteria for Arching
• No External Stress on Top
2 (1 )ahb e
0
'
(1 sin ) (1 sin )0
2sin sin 2 2sin
cs
R fb g
'
0
sin 2c
s
fR
g
Influence of Some Critical Parameters
1. Gas Flow
Counter-Current Interstitial gas flow causes reduction of gravity, and thus needs a larger reactor size
''
0 0
sin 2c
s D
fR R
g F
2. Particle Size
Smaller particles need larger reactor size
unconfined yield strength of some alumina-powders (*)
*: Kohler, T. and H. Schubert, Influence of the Particle-Size Distribution on the Flow Behavior of Fine Powders. Particle & Particle Systems Characterization, 1991. 8(2): p. 101-104
'
0
sin 2
1
c
s
c n
p
fR
g
fd
3. Mixing with Fine Powders
The flowability governed by flow properties of the fine powders as shearing takes place across the fines.
4. Layer of Fine Powders
'
' ' '
0
1ln
bh
a b
h
H0
Arching Criteria:
depend on height of fine powder layerσ1
kPa
European Chemical Looping Reforming/Gasification Application - I
Reducer:MeO + CH4 Me + CO + 2H2
Oxidizer:Me + O2 MeO
Overall Reaction:CH4 + 1/2O2 CO + 2H2
Juan adanez, International Journal of Hydrogen energy, 2011
European Chemical Reforming/Gasification Application - II
Ryden, M., and A. Lyngfelt, International Journal of Hydrogen energy, 2006
37
OSU Chemical Looping Integrated with Fuel Cell Application – 3
2H2 + O2 2H2O + Electricity
C + H2O/O2 H2 + CO2/Heat
Re
ac
tor 1Biomass
Sequestrable
CO2 and H2O
MeOx
An
od
e
Cath
od
e
H2 rich gasS
OF
C
Steam rich exhaust to Reactor 2
Compressed Air
Oxygen lean air
to Reactor 3
Oxygen lean air
from SOFC
cathode (Optional)
Re
ac
tor 3
Electric
Power
MeOy (y < x)MeOy (y < x)
MeOz
(y<z≤x)
Re
ac
tor 2
Re
ac
tor 1Biomass
Sequestrable
CO2 and H2O
MeOx
An
od
e
Cath
od
e
H2 rich gasS
OF
C
Steam rich exhaust to Reactor 2
Compressed Air
Oxygen lean air
to Reactor 3
Oxygen lean air
from SOFC
cathode (Optional)
Re
ac
tor 3
Electric
Power
MeOy (y < x)MeOy (y < x)
MeOz
(y<z≤x)
Re
ac
tor 2
38
OSU Syngas Chemical Looping in CTL Applications – II
Steam
from F-T
Biomass
and F-T
byproduct
MeOx
H2 rich gas
MeOy (y < x)
MeOz
(y<z≤x)Air (Optional)
F-T and
Product Upgrade
CO2
H2O
Sequestrable CO2
H2O
Liquid Fuel
Product
Byproduct to
Reactor 1
H2O
(Cooling)
Steam to
Reactor 2
Reac
tor 3
Reac
tor 1
Reac
tor 2
Steam
from F-T
Biomass
and F-T
byproduct
MeOx
H2 rich gas
MeOy (y < x)
MeOz
(y<z≤x)Air (Optional)
F-T and
Product Upgrade
CO2
H2O
Sequestrable CO2
H2O
Liquid Fuel
Product
Byproduct to
Reactor 1
H2O
(Cooling)
Steam to
Reactor 2
Reac
tor 3
Reac
tor 1
Reac
tor 2
3H2 + CO2 -(CH2)- + 2H2O
C + H2O/O2 H2 + CO2/Heat
39
Coal/
O2
Particulateremoval
H2S Removal
F-Treactor
Productseparation
Liquid Fuel
Gas
Phase
HRSG
H2
H2/CO = 0,5
H2 /CO=2
Gas
ifie
r
OSU Syngas Chemical Looping in CTL Applications – I
Fuel
Rea
ctor
H2
Rea
ctor
CO2
Air
N2
N2
Organization/Location Process Size Features
HUNOSA, Spain CaCO3 – CaO (CaOling)
looping for post combustion
CO2 capture
2 MWth CO2 is from the flue gas
generated from 50 MWe coal
power plant .
Technical University of
Darmstadt, Germany
CaCO3 – CaO (LISA)
looping for post combustion
CO2 capture
1 MWth Capture plant is an extension to
a 1052 MWe hard coal-fired
power plant; carbonator and
calciner both are CFBs.
Technical University of
Darmstadt, Germany
ECLAIR – ilmenite
Redox with coal for looping
combustion application
1 MWth Solid fuel conversion uses a
fluidized bed reducer operated
in a CFB looping system
Alstom, U.S. CaCO3 – CaO looping for
CO2 capture
/CaSO4 –CaS redox with
coal for looping combustion
application
3 MWth Process uses two calcium –
based loops in a chemical
looping system
OSU, U.S. Iron based oxygen carrier
redox with gaseous fuels for
H2 production in a Syngas
Chemical Looping (SCL)
gasification process
250 kWth High pressure SCL enables
high purity H2 generation and
high purity CO2 generation
using a countercurrent moving
bed reactor
Upcoming large-scale demonstrations of chemical looping technology
Concluding Remarks
• Chemical Looping embodies all elements of particle science and technology - particle synthesis, flow and contact mechanics, gas-solid reaction engineering…
• Success achieved in the operation of sub-pilot units reflect the likelihood of commercialization of this technology in the near future