Jesse G. Thompson, Reynolds Frimpong, Joseph E. Remias, Jim K. Neathery, Kunlei Liu

  • Center for Applied Energy Research, CAER, University of Kentucky, 2540 Research Park Drive, Lexington, KY 40511, USA

Received: May 8, 2013
Revised: November 19, 2013
Accepted: November 19, 2013
Download Citation: ||https://doi.org/10.4209/aaqr.2013.05.0150 

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Cite this article:
Thompson, J.G., Frimpong, R., Remias, J.E., Neathery, J.K. and Liu, K. (2014). Heat Stable Salt Accumulation and Solvent Degradation in a Pilot-Scale CO2 Capture Process Using Coal Combustion Flue Gas. Aerosol Air Qual. Res. 14: 550-558. https://doi.org/10.4209/aaqr.2013.05.0150


 

ABSTRACT


Solvent degradation is a major factor in the cost associated with carbon capture using aqueous amine solutions. Heat stable salts (HSS) from oxidative amine degradation and acidic flue gas components, including SO2, NOx and HCl can accumulate in amine solvents and lead to corrosion, extra energy requirements and reduced capture efficiency. Accurate and reliable quantitation of HSS concentration is essential to monitor solvent degradation and corrosion potential inside the system. Two separate amine solvents were tested in a 0.1 MWth carbon capture pilot plant. 30% Monoethanolamine (MEA) was used as a baseline solvent and compared to a developed amine solvent, CAER-B2. Six HSS were identified in each solvent and the accumulation rates were determined. The observed HSS build-up was similar in magnitude to other published amine based CO2 capture plant data. The 30% MEA solvent accumulates HSS at a higher rate (48 ppm/hr vs. 22 ppm/hr) as the CAER-B2 which can be attributed to higher input SO2 levels during the solvent test campaign. Corrosion benchmark levels of HSS were exceeded for CAER-B2 and 30% MEA within a few days of normal operation.


Keywords: Heat stable salts; Carbon capture; Corrosion; Amine degradation; Flue gas contaminants


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