Shales are currently
regarded as potential hydrocarbon resources.
At the same time, utilization of carbon dioxide (CO2) in
enhanced oil recovery applications is being brought to the forefront
worldwide. This necessitates that the mechanisms of oil recovery using
CO2 are well understood. In this study, the wettability
alteration and volumetric expansion upon CO2 injection
into a system comprising organic-rich shale, water, and a model oil
is investigated. Captive bubble tests performed at 0.1, 10, and 15
MPa and 60 °C using different aqueous phase compositions reveal
that the shale is water wet under atmospheric pressure. Additionally,
it is found that CO2 has an in situ aging effect that leads
to reduced surface water wetting due to the expulsion of hydrocarbons
from organic matter pores. This aging effect is in direct proportion
to the CO2 pressure applied. Further, at elevated pressures,
divalent ions promote a reduction in water wetness, while monovalent
ions have less effect. Similar to contact angle measurements, the
volumetric expansion is found to increase with pressure. The solubility
of CO2 in the oil phase at 10 and 15 MPa is estimated to
be around 20 and 28%, respectively.