www.rti.orgRTI International is a registered trademark and a trade name of Research Triangle Institute.
Emissions Mitigation Technology for Advanced Water-Lean Solvent Based CO2 Capture
Processes
Jak Tanthana, Paul D. Mobley, Aravind V. Rayer, Vijay Gupta, Jonathan W. Thornburg, Ryan T. Chartier, Mustapha Soukri, and Marty A. Lail
DE-FE0031660DOE Project Manager: Sai V. Gollakota
Carbon Capture, Utilization, Storage, and Oil & Gas Technologies Integrated Review Meeting
Aug. 26th, 2019
Cumulative DOE funding > $9 MM and more than $2 MM funding from RTI industrial partners
Solvent development work finalized Pilot testing completed at SINTEF, Norway and National
Carbon Capture Center (NCCC) Pre-commercial demonstration (12 MW) planned at
Technology Center Mongstad (TCM), Norway in FY20
Long-term potential for large scale CO2 capture applications
Commercialization path via process technology licensing
Application potential for high-efficiency acid gas separations
Impact
Development History for Novel, Non-Aqueous Solvents
Technology Status
Key Technical Advantages
CO2 Capture Technology with substantially reduced energy consumption
Minimum changes to existing process to realize NAS optimal performance
Commodity-scale production ready
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Pilot Testing at Tiller Plant
(Norway, 2015-2018)Demonstration of all process components at pilot scale
NAS CO2 Capture Technology Path to Market
Large Bench-Scale System (RTI facility, 2014-2016)Demonstration of key process features (≤ 2,000 kJ/kg CO2) at bench scale
Lab-Scale Development &
Evaluation (2010-2013)
Solvent screening and Lab-scale evaluation
Engineering-Scale Validation(2018+)
Pre-commercial Demonstration at Technology Centre Mongstad, Norway (~12 MWe)
Test in late 2020
Pilot Testing at SSTU (NCCC, 2018)
Degradation, emission, and corrosion characterizations under real flue gas
Emissions control(Tiller, 2018+)
Effective emissions mitigation strategy for WLS at engineering-scale
~$2.7MM ~$3 MM6kW
~$21MM12 MW
~$3MM60 kW
~$3.5MM~$0.75MM50 kW
From lab to large scale (12 MW) demonstration through series of projects
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NCCC and Tiller Emission results
Similar emissions levels and species seen at SINTEF and NCCC
Intercooling reduces emissions by almost 10x
Largest minor emissions include hydrophobic diluent species and other degradation species
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1
10
100
1000
Emis
sion
s, p
pm
NCCC
SINTEF
SINTEF - Intercooling
Project Summary
Objective:Develop and optimize the emission control solutions to reduce the amine emission for advanced, 2nd generation solvent –WLS classKey Metrics• Emissions from absorber&desorber• Solvent loss and make-up cost reduction• Technoeconomic and EHS evaluation
Specific Challenges• Aerosols generation and
characterization• Amine reclaiming unit and process
integration• Organic wash solvent screening
Timeframe: BP1 10/01/18 to 03/31/20BP2 04/01/20 to 09/03/21Budget: BP1 Federal $1.7MM Cost Share $0.4MMBP2 Federal $1.2 MM Cost Share $0.4 MM
Potential emissions control technologies for WLS systems to be incorporated at the RTI’s BsGAS
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SO3 generator
Amine recoveryAdv. demister
Organic wash
Absorber
Regenerator
Rich Solvent Preheater
CO2-lean Solvent Pump
CO2-rich Solvent Pump
Interstage Coolers
Trim Cooler
Wash Section 1
Cross over Heat Exchanger
CO2 product
To Wash Section 1
Treated Flue Gas
Wash section 2
Flue gas
Amine Filters
Reboiler Steam
Condensate
SteamCO2 CO2
To Wash Section 1
From Wash Section 2
Interstage Heaters
Particulate filters
300-600 ppm
< 1 ppm 20-50 ppm
Project Team
Team Member Role Expertise
RTI
Prime recipient, project management, developer of NAS technology, emissions characterization, solvent screening, ECT design and modeling, and economic analyses
Effective project management and execution under DOE cooperative agreements
Lead developer of NAS CO2 capture technology
Process design, modeling, and engineering capabilities
Process technology scale-up and operation from lab to large precommercial demonstration systems
Aerosol emissions characterization
LindeTechnical advisory and contributor to joint-emission report
• Leading industrial gas supplier
• CO2 capture plant design and pre-commercial scale demonstration
• Advance front-end emission control equipment design and fabrication
TCMTechnical advisory and EH&S support
• World leading test facility for CO2 capture
• EH&S and quality standards
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BP1 Tasks and Project Goals
BP1 TasksTask 1.0: Project Management and PlanningTask 2.0: Establish emission baseline without ECT
• Aerosol generation at BsGAS• Baseline measurement• Empirical model development
Task 3.0: Prototype ECT for WLSs evaluation at RTI’s BsGAS• 2nd wash column and amine recovery process• Evaluation of BsGAS with ECTs
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Project Goals Control and manage amine emissions Identify emission pathways for WLSs Model the amine emission Refine Techno-economic analysis Gain operational experience on WLS process with ECTs
BP1 Key Tasks
Key Tasks Approaches/ planned Activities Planned Completion Date
Develop method to monitor and quantify emissions at the BsGAS
• Install SO3 injection at BsGAS• Particle counter and aerosols quantification
equipment tie-in
Completed
Update BsGAS flow sheet with emission control equipment necessary to reduce amine emissions with > 99% efficiency
• Install, commission, and evaluate ECTs at BsGAS
Completed
Baseline data for amine emissions using two water-lean solvents
• Parametric testing on 2 solvent candidates 08/31/19
Empirical process model for amine emissions from water-lean solvents with < 10% average absolute deviation based on critical process parameters
• Regression on experimental results 03/31/20
Complete testing of emission reduction performance at BsGAS to demonstrate amine emissions reduction to < 10 ppm
• Parametric testing 03/31/20
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SO3 generator
• V2O5/SiO2 catalyst in 3-zone heating furnace• 99.99% SO2 to SO3 conversion• SO3 is mixed with steam in the abs. gas
feed, producing H2SO4 mist (i.e., aerosols) feeding the absorber
• Concentration ranges from 0-10 ppm SO3
SO3 Generator at BsGAS: installation and setup
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190PCV
190API
190BPI
190CYL
FI190FI
C
R-190193
TSSH
193PTE
193TY
193STE
193HE
192TSSH
192PTE
192TY
192STE
192HE
191TSSH
191TY
191HE
195C
190C
190TI
190TE
NOTE 2
NOTE 1NOTE 3
TO C-200290-11010-102 G
191PTE
191STE
64
HV-190
C
HV-195
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191TIC
192TIC
193TIC
SO3 generator
• Aerodynamic Particle Sizer (APS, 0.5-20 µm) and Scanning Mobility Particle Sizer (SMPS, 15-660 nm) were installed to characterize the aerosols from abs. inlet, outlet, and WW outlet.
• Sampling probe is designed to take isokinetic samples at each location
Characterizing Aerosols: APS/SMPS Setup
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Isokinetic nozzle 0.035" orifice Isokinetic nozzle
0.3 slpm to SMPS
5 slpm to APS
Absorber
CO2-lean Solvent Pump
CO2-rich Solvent Pump
Interstage Coolers
Trim Cooler
Wash Section 1
Simulated FG with aerosols
APS/SMPS
Sampling Probe
APS/SMPS
SO3 Generator at BsGAS: Trial runs
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• Particle concentration and sizes are consistent with literature • Aerosols grow as they travels through the process• Large aerosols carry more mass
Particle concentration Particle mass
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
1.E+08
10 100
dN/d
logD
p (1
/cm
3 )
Particle Diameter (nm)
Absorber Inlet, 0 ppmWash Outlet, 0 ppmAbsorber Inlet, 3 ppmWash Outlet, 3 ppmAbsorber Inlet, 6 ppmWash Outlet, 6 ppm
1.E-01
1.E+00
1.E+01
1.E+02
1.E+03
1.E+04
10 100
dM/d
logD
p (1
/cm
3 )
Particle Diameter (nm)
Absorber Inlet, 0 ppmWash Outlet, 0 ppmAbsorber Inlet, 3 ppmWash Outlet, 3 ppmAbsorber Inlet, 6 ppm
SO3 Generator at BsGAS: Trial runs
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0
200
400
600
800
1000
1200
0 5 10 15 20 25
AMIN
E EM
ISSI
ON
(PPM
)
SO3 INJECTION (PPM)
Parametric Testing
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36 total runs have been scheduled, testing in progress
Parameters Units Low Medium HighSO3 Injection ppm 0 3 6Inlet Saturation Temp °C 20 25 30L/G kg/kg 3 4.5 6Regenerator Temp °C 95 105 115Lean Return Temp °C 30 40 50IC Top % 0 50 100IC Middle % 0 50 100IC Lower % 0 50 100
Adsorption Regeneration
Adsorption Regeneration Test
Length65 min 65 min
Sampling 4 min sample, every 10min
4-6min sample, 2 min between sample
Flow Rate ~4 mL/min 1% amine sol.
2 mL/min Steam
1% Amine
Solution
Bed - ~6 g of sorbent
Amine Recovery: Sorbent Testing
0
0.05
0.1
0.15
0.2
0.25
0.3
1 2 3 4 5
Wor
king
Cap
acit
y (g
-am
ine/
g-so
rben
t)
Cycle
Sorbent-1Sorbent-2
Working Capacity
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• A top candidate was selected with working capacity of ~0.25 g-amine/g-sorbent with 1 wt% amine solution
• Kinetic parameters measured for scaling up to BsGAS system
• Lab setup used to screen sorbents for amine recovery• Working capacity at different amine concentrations
used to evaluate sorbents
Absorber
Regenerator
Rich Solvent Preheater
CO2-lean Solvent Pump
CO2-rich Solvent Pump
Interstage Coolers
Trim Cooler
Wash Section 1
Cross over Heat Exchanger
CO2 product
To Wash Section 1
Treated Flue Gas
Wash section 2
Flue gas
Amine Filters
Reboiler Steam
Condensate
SteamCO2 CO2
To Wash Section 1
From Wash Section 2
Interstage Heaters
Particulate filters
300-600 ppm
< 1 ppm 20-50 ppm
BsGAS modifications with ECTs
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Particulate filters
2nd wash column
Adv. demister
CO2 acidification vessels
Accomplishments and Path forward
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Accomplishments• Installed SO3 Generator to generate aerosol with size distribution matches that of the
actual coal-fired power plant• Incorporated APS/SMPS for aerosol characterization and at BsGAS• Completed detail design for the particulate filters, advanced demister, additional wash
column, CO2 acidification vessels, amine recovery beds.
Path forward• Complete parametric testing at BsGAS: late Sep• BsGAS modification: Oct-Nov 2019• Evaluate the ECTs added to the BsGAS: Jan –Mar 2020• Empirical model development: Oct-Mar 2020
Acknowledgments
• Financial support provided by DOE NETL under DE-FE0031660
• DOE Project Manager: Sai Gollakota
• Linde:Project support
• TCM:Project support
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Jak Tanthana
Research Chemical EngineerCenter of Technology for Energy, Environment & Engineering
RTI [email protected]+ 1.919.541.7208
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