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This microfluidic study demonstrates salt precipitation in “real-rock pores” during CO2 injection into saline-saturated porous media. Large crystals and polycrystalline aggregates are found, where the former occurs within the fluid phase and the latter can grow beyond the water-gas interface. The kinetics of salt precipitation needs to be studied further to gain a better understanding of the potential effects on reservoir performance. Our ongoing study will investigate permeability and porosity changes during the injection, and how temperature may potentially affect the process. Elucidation of such questions will help to better manage geological CO2 sequestration and minimize risks of formation impairment.