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

3

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

4

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

5

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

35

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 Internationaljtanthana@rti.org+ 1.919.541.7208

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