Deep saline aquifer formations are expected to have a large potential for carbon dioxide (CO
2) storage. Host rocks of the aquifers are mostly porous sandstones. Laboratory experiments on CO
2/brine displacement flow in porous sandstones under aquifer's temperature and pressure conditions are important for better understanding the CO
2 trapping mechanism in aquifers. A high resolution X-ray CT scanner gives in situ images of CO
2 and brine distributions in porous sandstone. The images give important clues for clarifying mechanisms of CO
2 trapping in porous sandstones. In this article, we discuss mechanisms of CO
2/brine displacements revealed by employing a high-resolution medical CT scanner, and then in the succeeding article, we discuss changes of seismic velocity during the displacements. Considering the role of capillary pressure in porous sandstone and the inhomogeneity revealed in reservoir rocks by petrological and sedimentological analyses, the following points are important for the CO
2 migration and trapping in deep saline aquifers. 1. Locally-biased CO
2 flow paths appear during CO
2 injection in brine-saturated sandstone because the fine-scaled local fluctuation (about mm sizes) in pore-size distribution. 2. In simultaneous flow of CO
2 and brine, tapping and flow behaviors of CO
2 depend on the directional relationship between anisotropy in porosity distribution and flow direction. 3. The above phenomena arise from slight differences in capillary pressure accompanied by differences in pore size distributions. 4. Flow and trapping of CO
2 are governed by sizes of CO
2 clusters in pore spaces. 5. Sizes of CO
2 clusters in pores are different between the processes of CO
2 injection and brine reinjection. 6. Heterogeneity scales from pore size to geologic structure affect CO
2 flow behavior in the reservoir at CO
2 storage sites. 7. When fractures or large pore sized channels exist in a reservoir and its surrounding formations, capillary pressure has no effect on CO
2 flow.
View full abstract