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Modeling of Novel Mixed Salt CO2 Capture and Regeneration Process for Post-Combustion Related Applications
Palitha Jayaweera
Sr. Staff Scientist
Energy and Environment Center
SRI International
Oct 25-26, 2016 Florham Park New Jersey
2016 OLI Simulation Conference
Source: MIT technology review, 2012
US EPA New Ruling
Global CO2 emissions from fossil-fuel combustion reached 36 Gt in
2013. Coal accounted for 45% of total energy-related CO2 emissions, followed by oil
(35%) and natural gas (20%).
Solution: To impede climate change, scientific studies suggest, billions of tons of carbon dioxide need to be captured from hundreds of fossil-fuel power plants in the next few decades.
This coal power plant in
Saskatchewan is the first
commercial-scale coal power
plant to capture and bury most of
its carbon dioxide emissions.
Atmospheric CO2 for September 2016 ~ 400 ppm
The Reality: We will continue to use coal
for electricity production. “Even as low natural gas prices continue to drive
out coal-fired generation, coal will remain the
dominant fuel for electricity production through
2040. -U.S. Energy Information Administration’s
Annual Energy Outlook 2013”
2016 SRI International 4
Key benefits: - Reduced ammonia emissions
- Enhanced efficiency
- Reduced reboiler duty
- Reduced CO2 compression energy
A SIGNIFICANT PARASITIC POWER REDUCTION COMPARED TO MEA !
How it works: Selected composition of potassium carbonate and ammonium salts
• Overall heat of reaction 35 to 60 kJ/mol (tunable)
Absorber operation at 20o - 40o C at 1 atm with 30-40 wt.% mixture of salts
Regenerator operation at 120o - 180o C at 10-20 atm • Produce high-pressure CO2 stream
High CO2 cycling capacity
No Solids
K2CO3–NH3–CO2–H2O system
2016 SRI International 5
Published Data Showing Favorable Kinetics
for CO2 Absorption in Ammonia Solutions
Sources: Dave et al., (2009). Energy Procedia 1(1): 949-954 Puxty et al., (2010). Chemical Engineering Science 65: 915-922 CSIRO Report (2012). EP116217
Comparison of CO2 absorption rates for MEA and ammonia
Pseudo first-order rate constants for CO2 absorption in NH3
Source: Derks and Versteeg (2009). Energy Procedia 1: 1139-1146
Solvent kapp/103 s
-1
NH3 at 5°C 0.3
NH3 at 10°C 0.7
NH3 at 20°C 1.4
NH3 at 25°C 2.1
MEA at 25°C 6
MDEA at 25°C 0.58
Concentration = 1.0 kmol m-3
0.0
0.2
0.4
0.6
0.8
1.0
1.2
1.4
1.6
1.8
2.0
0.0 0.2 0.4 0.6 0.8 1.0
CO
2 A
bso
rpti
on
Rat
e (m
mo
l/s
m2
kP
a)
CO2 Loading (CO2/NH3 Molar Ratio)
Puxty et al., 2010 (6 M ammonia, 5 C)
Dave et al., 2009 ( 7 M ammonia, 5 C)
CSIRO, 2012 ( 5 M MEA, 40 C)
Wetted wall column data
Absorber side: Enhanced kinetics SRI small-bench scale data
Solvent kapp/103 s
-1
NH3 at 5°C 0.3
NH3 at 10°C 0.7
NH3 at 20°C 1.4
NH3 at 25°C 2.1
MEA at 25°C 6
MDEA at 25°C 0.58
Concentration = 1.0 kmol m-3
2016 SRI International 6
Mixed-salt Process Requires NO Solvent Chilling
-Can Operate with Significantly Reduced Water Use
0
2
4
6
8
10
0.2 0.3 0.4 0.5 0.6 0.7
NH
3 V
apo
r P
ress
ure
(kP
a)
CO2 Loading (molar ratio)
10 m NH3 at 20 C
SRI Mixed Salt at 30 C 30 wt.%
10 m NH3 at 5 C
Water use will be reduced by
a factor of 10 or more in the absorber
Reduced ammonia emission
Regenerator Ammonia Vapor Pressure is
Reduced
0
1
2
3
4
5
6
0.3 0.4 0.5 0.6 0.7
NH
3 V
apo
r P
ress
ure
(kP
a)
CO2 Loading (molar ratio)
Regenerator Top
10 m NH3
SRI mixed salt at 70 C
Water use will be reduced by
a factor of 5 or more in the regenerator
Reduced ammonia emission
Mixed-Salt has a Low Energy Requirement for
CO2 Stripping
Sources: MEA data: CSIRO report (2012), EP116217 K2CO3 data: GHGT-11; Schoon and Van Straelen (2011), TCCS-6 Mixed-salt data; SRI modeling
Estimated regenerator heat requirement for mixed-salt system with 0.2 to 0.6 cyclic CO2 loading. Comparison with neat K2CO3 and MEA is shown
Mixed-salt process has minimal energy demand for water stripping as regeneration is at high pressure.
20 bar
High purity CO2 stream
CO2/H2O < 0.02
Regenerator side: Reduced water evaporation
2016 SRI International 9
Mixed-Salt Requires Less Energy for
CO2 Compression
0
10
20
30
40
50
60
70
80
90
0 2 4 6 8 10 12 14 16 18 20 Desorber Pressure (bar)
kWh
/t-C
O2
4 3 2 No. of compression stages
Mixed-Salt
Electricity output penalty of compression to 100 bar
as a function of desorber pressure Source: Luquiaud and Gibbins., Chem Eng Res Des (2011)
CO2 Compression: High-pressure CO2 release 2016 SRI International 10
Amines
Key Project Goals • Demonstrate the absorber and regenerator processes individually
with high efficiency and low NH3 emissions
• Development of comprehensive thermodynamic modeling package
• Demonstrate the high-pressure regeneration and integration of the absorber and the regenerator
• Demonstrate the complete CO2 capture system, optimize system operation, and collect data to perform the detailed techno-economic analysis of CO2-capture process integration to a full-scale power plant
• Conduct EH&S analysis of the process
The overall project objective is to demonstrate that mixed-salt technology
can capture CO2 at 90% efficiency and regenerate (95% CO2 purity) at a cost
of $40/tonne to meet the DOE program goals.
2016 SRI International 11
Simplified PFD of the Integrated System
Flue Gas
20cfm
85% N2
15% CO2
Water
Wash
Clean
Flue Gas
Absorber 1
Absorber 2
Rich Solution 1
Lean Solution 2
Lean Solution 1
Rich Solution 2 Reboiler
Regenerator
Pressure 10-20 bar
CO2
160⁰C
120⁰-140° C
Water
Wash
H1
H2
H3
H4H5
2016 SRI International 12
AspenPlus® Flowsheet
2016 SRI International 13
Modeling results - Absorber
Composition and Temperature profiles
• RadFrac Columns
• Absorber 1: 12 stages
• Absorber 2: 10 stages
• Flue gas flow rate: 1000 lpm
Absorption efficiency: 94%
Ammonia emission: 55 ppm
Modeling Results - Regenerator
Composition and Temperature Profiles
• RadFrac Column
• Regenerator: 10 stages • Temperature :180°C
• Pressure: 15 bar
Regeneration energy: 1.8 MJ/kg of CO2
Ammonia emission: 14 ppm
Absorbers and the Dual Stage Regenerator
2016 SRI International 16
0.25 to 1 t-CO2/day capacity
Absorber temperature profiles during parametric testing
Regenerator temperature profiles during parametric testing
Regenerator pictures taken from different angles are shown
Integrated System Testing-March 2016
• 300 to 400 slpm simulated flue gas with 15% CO2
• 300-hour operation
Observed 90% capture efficiency and regeneration with cyclic loading of ~0.7
M/M of ammonia
17
Data showing relationship of the measured pH of rich and lean solutions from Absorber 1
Alkalinity of rich and lean solutions circulating in the integrated system
Observed 90% capture efficiency and regeneration with cyclic loading of ~0.7 mole of CO2/mole of ammonia
Integrated System Testing
90% CO2 capture efficiency with 0.19 to 0.40 cyclic CO2 loading in Absorber 1 Gas flow rate = 15 acfm
Test Data Modeling and Test Data
2016 SRI International 18
Rate Based Modeling of the Mixed –salt Process.
• Collect experimental and modeling data available in the
literature for the H2O-CO2-NH3-K2CO3 system.
• Determine speciation and compositions and include them in
the model.
• Develop a rate-based model from the SRI test data using ESP
(Electrolyte Simulation Program).
• Determine mass and energy balance for a two-process layout
to add a CO2 capture system for a full scale plant as specified
by DOE Case 11.
• Compare the results of the mixed-salt process and DOE Case
12; the reference carbon capture plant model.
2016 SRI International 19
MSE thermo thermo Standard-
state: HKF
(direct)
GEX: MSE no limit on
concentration
Solid phases: thermochemical
properties
Surface
tension
Interfacial
tension 2nd liquid phase:
MSE (ionic)
Electrical conductivity
Viscosity
Thermal
conductivity
Self -
diffusivity
Interfacial phenomena: ion exchange, surface
complexation, molecular adsorption
Mixed-Solvent Electrolyte Framework
RT
G
RT
G
RT
G
RT
G exII
exLC
exLR
ex
LR Long-range electrostatic interactions
LC Local composition term for neutral molecule interactions
II Ionic interaction term for specific ion-ion and ion-molecule interactions
Mixed-Solvent Electrolyte (MSE) Model
• The model reproduces
• VLE
• SLE
• Heats of mixing and dilution
• Heat capacity
• Density
• Ionic equilibria
0.0001
0.001
0.01
0.1
1
0 0.1 0.2 0.3 0.4 0.5
CO
2 P
art
ial Pre
ssure
, atm
moles CO2 / mole K2CO3
Carbon Dioxide Partial Pressure of 20 wt% Potassium
Carbonate
40C
50C
60C
70C
80C
Prediction of phase equilibria and thermodynamic properties in
wide temperature and composition ranges.
e.g., Vapor-liquid equilibria of K2CO3 – KHCO3 – CO2 – H2O
Vapor-liquid equilibria: NH3 – CO2 – H2O
• Total and partial pressures
• Phase equilibria combined with chemical equilibria
− Acid-base equilibria
− Complex (carbamate) formation
0.0001
0.001
0.01
0.1
1
0 0.2 0.4 0.6 0.8 1
PN
H3, PCO
2, atm
CO2/NH3, m/m
Aqueous Ammonia / Carbon Dioxide Partial Pressures
at 20 C for mNH30.1m0.5m1.0m2.2m
1
10
100
0 0.2 0.4 0.6 0.8 1 1.2 1.4 1.6
Pre
ssure
, atm
CO2/NH3, m/m
Aqueous Ammonia / Carbon Dioxide Pressure at 100
C for mNH3
1.0m2.0m3.9m6.0m7.3m8.0m9.6m11.0m
Process Flow Diagram for Mixed-salt Process
Simulation with OLI ESP
2016 SRI International 23
Modeling Results -comparison with Econamine
2016 SRI International 24
Performance Factors Econamine FG Plus
Baseline
SRI’s Mixed-Salt
Technology*
CO2 Capture, % 90.2 90.3
CO2 Purity (before compression), % 99.61 > 99.0
Stripper Pressure, atm 1.0 10.0
Raw Water Consumption, m3/min (gpm) 0.1 (36) 0.41 (107.5)
Raw Water Recycle, m3/min (gpm) 1,173-1,287
(310,000-340,000) 305 (80,569)
Auxiliary Power, KWe 20,600 3,581
Heat duty, MJ/Kg of CO2 3.56 2.0 * Comparison with respect to CDR unit only
Modeling Results -comparison with Shell Cansolv
Performance Factors Shell Cansolv
Baseline
SRI’s Mixed-Salt
Technology*
CO2 Capture, % 90.0 90.3
CO2 Purity (before compression), % 98.24 > 99.0
Stripper Pressure, atm 1.98 10.0
Raw Water Consumption, m3/min (gpm) 0.02 (5) 0.41 (107.5)
Raw Water Recycle, m3/min (gpm) Substantial amount
(data not presented) 305 (80,569)
Auxiliary Power, KWe 16,000 3,581
Heat duty, MJ/Kg of CO2 2.56 2.0
Graphical Presentation of the Cost of Electricity Data
for Econamine, Cansolv, and Mixed-salt Processes
66.4 72.2
57.1
110
14.5 15.4
15.4
12.1
14.7
12.6
35.3 30.9
32.3
11 9.6
10
0
20
40
60
80
100
120
140
160
DOE Case 12 DOE Case 12B Mixed-Salt Base Case Mixed-Salt Variants
Capital Fixed Variable Fuel CO2 T&S
10%
Auxiliaries
Cost Of Electricity ($/MWh)
Target Improvements 1. Regenerator operation at 160°C (mixed-salt base case is for 180°C) 2. Water-wash reduction by 2x 3. Process simplification 4. Advanced heat integration 5. Advanced packing from IHI
Eco
nam
ine
-op
tim
ize
d
Can
solv
-op
tim
ized
Mix
ed
-Sal
t
2016 SRI International 26
Process Modeling: SRI (ASPEN) and OLI (ESP) Cyclic Loading = 0.18 to 0.58 Reboiler Duty ~ 2.0 MJ/kg-CO2
Ammonia Emission < 10 ppm
Mixed-Salt Technology Summary
Process Summary
• Uses inexpensive, industrially available material (potassium and ammonium salts)
• Requires no feedstream polishing
• Does not generate hazardous waste
• Has the potential for easy permitting in many localities
• Uses known process engineering
•
Demonstrated Benefits
• Enhanced CO2 capture efficiency
• High CO2-loading capacity
• High-pressure release of CO2
• Reduced energy consumption compared to MEA
• Reduced auxiliary electricity loads compared to the
conventional ammonia processes
• Possible flexible carbon capture operation
US Patent 9,339,757 issued on May 17, 2016
2016 SRI International 27
Project Summary
• Collected experimental and modeling data available in the
literature for the H2O-CO2-NH3-K2CO3 system were; developed
a software package to determine speciation and compositions.
• Developed a rate-based model from the SRI test data; mass and
energy balance were determined for the mixed-salt CO2 capture
process.
• Demonstrated the operation of the two-stage absorber at high
temperature (20 to 40°C) with reduced ammonia emission.
• Demonstrated operation of the integrated system with >95%
efficiency (~ 0.25 ton/day CO2 capture) and the generation of
lean solutions with two compositions (ammonia rich, potassium
rich) using the novel two-stage regenerator.
2016 SRI International 28
Mixed-salt Project Team
• SRI International
− System design, installation and testing
• IHI Corporation, Japan
− Industrial partner
• OLI Systems, USA
− Modeling of process mass and energy
(rate-based)
• Aqueous Systems Aps, Denmark
− Thermodynamic modeling
• POLIMI, Italy
− Techno-economic analysis
• Stanford University (BP1), USA
− Technology comparisons
• Consultant (BP1)
IHI
Corporation
SRI & NETL
OLI Systems POLIMI
Stanford
University
Consultant Aqueous
2016 SRI International 29
Applied Energy 179 (2016) 1209–1219
Acknowledgements
NETL (DOE)
• Mr. Steve Mascaro, Ms. Lynn Bricket, and other NETL staff members
SRI Team
• Dr. Indira Jayaweera, Dr. Palitha Jayaweera, Ms. Regina Elmore,
Dr. Srinivas Bhamidi, Mr. Bill Olsen, Dr. Marcy Berding, Dr. Chris
Lantman, and Ms. Barbara Heydorn
Collaborators
• OLI Systems (Dr. Prodip Kondu and Dr. Andre Anderko), POLIMI
(Dr. Gianluca Valenti and others), Stanford University (Dr. Adam
Brant and Mr. Charles Kang), Dr. Eli Gal, and Dr. Kaj Thomsen
Industrial Partner
• IHI Corporation (Mr. Shiko Nakamura, Mr. Okuno Shinya,
Mr. Yasuro Yamanaka, Dr. Kubota Nabuhiko and others)
2016 SRI International 30
Disclaimer
This presentation includes an account of work sponsored by an agency of the United States Government. Neither the United States Government nor any agency thereof, nor any of their employees, makes any warranty, express or implied, or assumes any legal liability or responsibility for the accuracy, completeness, or usefulness of any information, apparatus, product, or process disclosed, or represents that its use would not infringe privately owned rights. Reference herein to any specific commercial product, process, or service by trade name, trademark, manufacturer, or otherwise does not necessarily constitute or imply endorsement, recommendation, or favoring by the United States Government or any agency thereof. The views and opinions of authors expressed herein do not necessarily state or reflect those of the United States Government or any agency thereof.
2016 SRI International 31
Headquarters 333 Ravenswood Avenue Menlo Park, CA 94025 +1.650.859.2000 Additional U.S. and international locations
www.sri.com
Thank You
Contact:
Dr. Indira Jayaweera
1-650-859-4042
Dr. Palitha Jayaweera
1-650-859-2989
“Last year was the warmest globally since at least the mid-to-late 1800s, according to the State of the Climate in 2015 report published Tuesday (Aug. 2, 2016) in the Bulletin of the American Meteorological Society by the National Oceanic and Atmospheric Administration’s National Centers for Environmental Information. “ Source: GHG Daily Monitor Vol. 1 No. 144, Aug 3, 2016
R
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