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where, Specific heat of water, SHw = 4.2 kJ/kg oC Specific heat of flue gas = SHfg (Generally, this is around 1.2 kJ/kg oC) Temperature rise in the cooling water (once through system) = Tw Drop in flue gas temperature = Tfg = (Tfg,i - Tfg) oF Tfg,i = Temperature of flue gas entering the direct contact cooler Tfg = Temperature of flue gas exiting the direct contact cooler mCaustic = m• m• kg NaOH/ hr NaOH • Process Water requirement CO2 Unit process water makeup = m• pw (tonne/ hr)/MW(net) Typically, the value of m• pw is about 0.114 tonne/hr per MW(net) (Smelster et al., 1991). Therefore, the process water requirement is: (Mpw) = m• pw MWnet tonne/hr • Cooling water requirement If there is a direct contact cooler installed, the required flow rate of cooling water is estimated based on the following assumptions Mass flow rate of flue gas = mfg tonne/ hr So, the required cooling water flow rate, Mcw = mfg*( Tfg / Tw )*( SHfg / SHw ) tonne/hr Therefore, the total water requirement is: (Mw) = Process water (Mpw) + Cooling water (Mcw) Steam requirement LP steam is extracted from the power plant steam turbine (or secondary steam turbine) in order to provide the sorbent regeneration heat in the reboiler. Based on the regeneration heat requirement and enthalpy of regeneration steam, the flow rate of steam may be estimated as follows From the performance equations, (Q/L) = f(yCO2, lean, C ) Total regeneration heat requirement, Q (MJ/ hr) = (Q/L)*(L) Mass flow rate of steam, msteam (tonne/hr) = Q / qsteam The equivalent energy penalty due to regeneration steam requirement is (Eregen). Depending upon the CO2 capture system configuration (source of regeneration steam supply), Eregen has to be estimated in two different ways. Integrated Environmental Control Model - Technical Documentation • 26PDF Image | Amine Based CO2 Capture
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