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The goal of reducing energy consumption of the CO2 removal process from flue gas may be pursued by developing new solvents as well as by modifying the technological process itself. This paper provides a discussion of the experimental results obtained from a process development unit (PDU) using an aqueous 2-amino-2-methyl-1-propanol (AMP) solution activated with piperazine (PZ) for post-combustion carbon capture located at the Clean Coal Technologies Centre in Poland. The results are compared for two distinct process setups, namely one with the lean amine stream being split - a solution referred to as split flow, and a system with standard configuration. © 2017 Society of Chemical Industry and John Wiley & Sons, Ltd. [ABSTRACT FROM AUTHOR]

With regard to the climate policy that has been adopted, the implementation of the carbon capture and storage and carbon capture and utilization technologies seems to be the unavoidable solution to reduce emissions from the energy sector. As most Polish energy is derived from coal, the government has taken steps to reduce CO emissions by initiating a strategic research program-'Advanced technologies for energy generation: Development of a technology for highly efficient zero-emission coal-fired power units integrated with CO capture.' This paper presents the results of an investigation of a process for continuous removal of CO from the gas stream on a laboratory unit. This study was conducted at the Institute for Chemical Processing of Coal in Zabrze, Poland. The purpose of the tests that were conducted was to establish the effect of the sorption column load on CO recovery and on the process regeneration heat duty. In the second part of the paper, a simple comparison of three amine solvents is presented as a part of the solvent selection process for further pilot plant tests. [ABSTRACT FROM AUTHOR]

In this study, the densities of carbonated aqueous solution of amines (ethanolamine, methylethanolamine, aminoethylethanolamine, and N‐methyldiethanolamine with piperazine) in various concentration and CO2 loadings were measured with temperatures ranging from 20°C to 60°C. The measured densities are in good agreement with those reported in the literature. The density experimental data were correlated with temperature and CO2 loading. Additionally, in case of the monoethanolamine, amine concentration was included into the correlation. Furthermore, an obtained correlation for density prediction of carbonated monoethanoloamine solutions was compared with Jouyban–Acree model. The fitted models are able to predict the density of carbonated amine solutions with a satisfactory precision. Presented correlations can be used either to predict the density of carbonated amine solutions or to determine CO2 loading of the investigated solution, if the density is known. The results of this paper may have an industrial application as a tool for process control of CO2 capture systems. [ABSTRACT FROM AUTHOR]