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Table 1. Stream table of the ASC plant with integrated a PSA unit for CO2 capture and a CO2 compression unit. Stream 1 2 3 4 5 6 7 8 9 10 ṁ T kg/s °C 66,2 25,0 744,2 15,0 735,7 338,9 800,8 117,0 800,8 127,1 823,3 62,5 781,1 20,0 150,4 15,4 619,7 35,2 150,4 28,0 P MW Composition (% mol.) bar g/mol CO2 N2 O2 Ar SO2 H2O 1,0 - - - - - - - 1,0 28,9 0,03 1,0 29,9 14,9 1,0 29,8 13,6 1,0 29,8 13,6 1,0 29,3 13,1 1,0 30,4 14,3 1,0 43,2 95,1 1,0 28,6 1,7 110,0 43,2 95,1 77,3 20,7 74,1 2,9 74,4 4,4 74,4 4,4 71,3 4,2 77,8 4,6 4,6 0,3 91,8 5,4 4,6 0,3 0,9 0,9 0,9 0,9 0,9 0,94 - 1,0 0,04 7,2 0,04 6,7 0,04 6,7 0,002 10,5 0,002 2,3 0,02 - - 1,1 - - 0,02 - - 2.2. IGCC plant with CO2 capture by PSA The addition of a PSA unit to the IGCC plant requires a higher degree of integration compared to the post- combustion scenario. A major difference is that the CO2-lean gas stream leaving the PSA process (i.e., the H2-rich gas stream) is further processed in the plant, constituting the fuel for the gas turbine. The additional units, with respect to the reference IGCC plant [33], consist in a water-gas shift section, a PSA process and a compression stage for CO2 transport. The plant layout is represented in Figure 2. The characteristics of the most relevant streams are given in Table 2. The Water-Gas Shift (WGS) converts CO and H2O into CO2 and H2, providing a beneficial effect on the following CO2 separation due to the increase in the CO2 partial pressure. COS hydrolysis is also carried out in the WGS process. The syngas is then cooled down. During the cooling process, condensing water is removed. Thanks to the relatively high pressure, water presence is drastically decreased (≈ 0.6%). The syngas stream at an appropriate temperature is fed to the H2S removal unit and successively to the PSA unit. The outputs of the PSA process are a CO2-rich stream and a H2-rich stream. The latter is the fuel for the gas turbine cycle and is preheated by the syngas leaving the WGS process. Since the CO2-rich gas stream does not achieve the requirements for being processed and transported, a further purification step is implemented. It consists in the removal of impurities by means of two flash separators integrated in the CO2 compression section (see Figure 3). This approach has already been suggested for removing a selection of non-CO2 gases from oxy-combustion power plants [34, 35]. After a first partial compression (up to 30 bar) and a dehydration process, the CO2-rich gas stream enters a system of two multi-stream heat exchangers, each followed by a flash separator. The appropriately set temperature levels (-30°C and -54.5°C [35]) allow to separate two different streams: a CO2-rich stream, matching the requested purity specifications, which completes the compression process; a CO2-lean stream, rich in H2, which can be added to the syngas injected as fuel in the gas turbine. The CO2-rich stream is further compressed to 110 bar in an intercooled-compressor. An air expander is also present, providing an additional power output. It partially expands the air extracted from the gas turbine compressor and fed to the ASU, in order to recover part of the compression work.PDF Image | Evaluating Pressure Swing Adsorption as a CO2 separation technique in coal-fired
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