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Chapter 5: Underground geological storage 207 Figure 5.7 Radial simulations of CO2 injection into a homogeneous formation 100 m thick, at a depth of 1 km, where the pressure is 10 MPa and the temperature is 40°C. The injection rate is 1 MtCO2 yr-1 for 20 years, the horizontal permeability is 10 –13 m2 (approximately 100 mD) and the vertical permeability is one-tenth of that. The residual CO2 saturation is 20%. The first three parts of the figure at 2, 20 and 200 years, show the gas saturation in the porous medium; the second three parts of the figure at 200, 2000 and 4000 years, show the mass fraction of dissolved CO2 in the aqueous phase (after Ennis-King and Paterson, 2003). Figure 5.8 Simulation of 50 years of injection of CO2 into the base of a saline formation. Capillary forces trap CO2 in the pore spaces of sedimentary rocks. (a) After the 50-year injection period, most CO2 is still mobile, driven upwards by buoyancy forces. (b) After 1000 years, buoyancy-driven flow has expanded the volume affected by CO2 and much is trapped as residual CO2 saturation or dissolved in brine (not shown). Little CO2 is mobile and all CO2 is contained within the aquifer (after Kumar et al., 2005).PDF Image | CARBON DIOXIDE CAPTURE AND STORAGE
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