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The use of amine absorption in carbon capture technologies is related with the formation toxic and potentially carcinogenic amine degradation products such as nitrosamines and nitramines. These substances can be created within both the solvent and the atmosphere when air components (mainly NOx) and amines react with each other. These substances may pose environmental and health risks depending on the level and duration of the exposure. In this paper, formation and occurrence of nitrosamines and nitramines in carbon capture plants were described. Emission reducing technologies have been also mentioned. Furthermore, an overview of experimental data of emission of nitrosamines and other major degradation products has been pointed out.

In the ethanolamine (MEA) solution, during the absorption and desorption of CO2 undesired compounds are produced as a result of degradation of an amine. Degradation not only reduces the absorption capacity of the solution but also leads to many operational problems. Furthermore, measuring of the degradation products is of great importance in terms of environmental issues. For the determination of MEA degradation products, mainly chromatographic techniques are used, sometimes coupled with other instrumental methods, e.g. GC-MS. As a part of this work, research was conducted to identifyMEA thermal and oxidative degradation products and to develop a method for quantitative analysis of the main thermal degradation products such as OZD, HEIA and HEEDA and oxidative degradation products: HEA and HEI. Samples drawn from a test bench for CO2 capture from synthetic flue gas with an increased content of carbon dioxide were tested. As a research result, a method for the quantitative determination of the main degradation products was developed, the concentrations of degradation products and the rate of their formation were determined, which allows to qualify the solution shelf life. [ABSTRACT FROM AUTHOR]

This paper presents results of studies of carbon dioxide capture process and its efficacy using ammonia aqueous solution. The studies were conducted in a laboratory stand (installation capacity up to 5 m3/h), where CO2 content of the inlet gas corresponded to gas emissions from soda ash manufacturing lines. Influence of the following process parameters on CO2 removal efficiency and energy consumption were investigated: power of the desorption column/stripper heater, temperature of the inlet lean solvent, liquid to gas ratio (L/G) and pressure in both the adsorption and desorption columns. The studies allowed determination of optimal process parameters of CO2 separation from the purified gas using aqueous ammonia at various CO2 concentrations in the range 10-30% (vol.). The most favorable liquid to gas ratio (L/G) for the feed gas with 10% CO2 content was 10-13 kg/kg, for the gas with 20% CO2 - 17-20 kg/kg while for 30% CO2 - 19-22 kg/kg. The optimum temperature of the lean amine directed to the absorption column was 25 oC, while the most favorable pressure there was 130 kPa. Total ammonia losses in the laboratory installation, primarily related to its emission from the absorption column, were about 40 gNH3/h at 25 oC. [ABSTRACT FROM AUTHOR]

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]

The article addresses the problem of carbon dioxide utilization through conversion with hydrogen to gaseous fuels. It describes methods which can be used to obtain Substitute Natural Gas (SNG) with as well as reactors where methanation process can be guided. There has been highlighted different economic and technical issues linked with carbon dioxide utilisation for production of methane. The last part of the article introduces global and local projects involved in developing this technology. [ABSTRACT FROM AUTHOR]

The densities of unloaded and partially carbonated piperazine (PZ) and 2-amino-2-methyl-1-propanol (AMP) aqueous solutions and their blends were measured at temperatures of 293.15 to 333.15 K. The results of these measurements were used to calculate excess molar volumes assuming that the volume of carbon dioxide dissolved in the solutions was zero. The excess molar volumes were correlated as a function of the CO2mole fraction using the Redlich–Kister equation. The results of the actual density are discussed in comparison with the case if no volume expansion occurs during the loading of the solutions. The no-volume-expansion model can be used to give an initial estimate of the density, while the Redlich–Kister equation is suitable for a precise density estimation. It must be noted that the no-volume-expansion model does not require any parameters except the density of the unloaded solution, unlike the Redlich–Kister equation, whose coefficients are regressed from experimental data. [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]