Carbon dioxide sequestration into geological formations has been identified as an alternative to mitigate the global climate change. The CO2 invasion pattern is dependent on various factors such as fluid viscosity, interfacial tension, injection rate, and the characteristics of porous media. Among these variables, we provide a systematic experimental study on the influence of the injection rate and the phase of CO2 invading into a brine-saturated microfluidic chip in order to quantitatively assess the displacement ratio. Interfacial tension and contact angle are accurately measured under the temperature and pressure conditions relevant to in situ conditions. The injection rate varies 3 orders of magnitude for gaseous, liquid, supercritical CO2, and CO2-water foam invasion. The capillary number and the viscosity ratio are calculated for each experimental condition, and the displacement ratio (CO2 saturation) is obtained after CO2 invasion. The results show that the saturation of injected CO2 is controlled by manipulating the injection rate and the phase of invading fluid, which can be used to optimize the in situ storage capacity. Especially, the CO2-water foam displaces almost all brine out of the microfluidic chip, but the increase in CO2 saturation is 23% ~ 53% compared to pure gaseous CO2 injection due to the water initially mixed in the CO2-water foam. The potential advantages of using CO2-water foam in the geological CO2 sequestration were also discussed.
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©2017. American Geophysical Union. All Rights Reserved.
All Science Journal Classification (ASJC) codes
- Geochemistry and Petrology
- Earth and Planetary Sciences (miscellaneous)
- Space and Planetary Science