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[19]. Transport of CO2 to a storage site is typically assumed to be via pipeline. While the economic costs of CO2 storage appear to be low, the social and political acceptability of different options are not yet clear. 2.5. Limitations of the MEA Process Although MEA-based absorption process is the most suitable technology available for capture of CO2 from power plant flue gases, it has its own drawbacks. The main problems maybe enlisted as follows Energy Penalty: The stable carbamate ion requires substantial energy to break the bonds. So, a large amount of heat is required to regenerate the sorbent. Substantial energy also is needed to compress the captured CO2 for pipeline transport to a storage site. This heat and electricity requirement reduces the net efficiency of the power plant if it is extracted internally (by de-rating the power plant). Alternatively, a much bigger power plant needs to be built in order to achieve the same “net” power generation capacity, as it would have been without CO2 capture. Loss of Sorbent: Some of the sorbent is lost during the process because of a variety of reasons including mechanical, entrainment, vaporization and degradation (Stewart and Lanning, 1994). All the sorbent entering the stripper does not get regenerated. Flue gas impurities, especially oxygen, sulfur oxides and nitrogen dioxide react with MEA to form heat-stable salts, thus reducing the CO2-absorption capacity of the sorbent. Proprietary inhibitors are available that make the sorbent tolerant to oxygen. Flue gas NOx is not a major problem since nitric oxide (NO) is the predominant form (~ 90-95%) of total NOx in the flue gas, and does not react with inhibited amines (Suda et al., 1992; Leci, 1996). But, SO2 does degenerate MEA sorbent, so very low inlet concentrations (10 ppm) are desirable to avoid excessive loss of sorbent. However, untreated flue gases of coal-fired power plants contain about 700 to 2500 ppm SO2 (plus roughly 10-40 ppm NO2). The interaction of SO2 with CO2 control system is thus particularly important. The heat-stable salts that are formed may be treated in a side stream MEA-reclaimer, which can regenerate some of the MEA. Technologies such as electrodialysis are also being proposed for this purpose (Yagi et al., 1992). Corrosion: Corrosion control is very important in amine systems processing oxygen-containing gases. In order to reduce corrosion rates, corrosion inhibitors, lower concentrations of MEA, appropriate materials of construction and mild operating conditions are required (Barchas and Davis, 1992). 3. Performance Model Development A number of previous studies have reported some cost and/or performance data for specific amine-based systems, including hypothetical applications to coal-fired power plants (Smelster, 1991; Kohl and Nielsen, 1997; Chapel et al., 1999; Herzog, 1999; Chakma and Tontiwachwuthikul, 1999; Simbeck, 1999; Marion et al., 2001). However, there are no generally available process models that can be used or modified for detailed studies of CO2 removal options. Cost data also are relatively limited and often incomplete. The rate of removal of CO2 from flue gas using an amine scrubber depends on the gas-liquid mass transfer process. The chemical reactions that permit diffusion of CO2 in the liquid film at the gas-liquid interface enhance the overall rate of mass transfer. So, the CO2 removal efficiency in the absorber is a function of various parameters that affect the gas-liquid equilibrium (e.g., flow rates, temperature, pressure, flue gas composition, MEA concentration, equipment design, etc.). Absorption of CO2 in an alkaline medium may be considered as a first order reaction. Higher CO2 concentration thus improves the efficiency of the absorption system. Even at low concentration of CO2, MEA has great affinity for CO2. The solubility of CO2 in MEA is much higher as compared to many other conventional solvents. Integrated Environmental Control Model - Technical Documentation • 14PDF Image | Amine Based CO2 Capture
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