In recent years, Carbon capture and storage technology (CCS) has been recognized as one of the potential methods to reduce greenhouse gas emission and for mitigating global climate change. This practice can be done in the depleted reservoir as well as saline aquifer reservoir. Geological modeling is an important process to prove the suitable geologic formation in CCS project. The CO2 plume behavior depends on geology structure of storage formation. This study focuses on geological modeling and the simulation of CO2 plume behavior in saline sandstone of fluvial deposit, Nam Vang field, Cuu Long Basin, Vietnam. Channel sand and floodplain are defined based on well-logging data. Fluvial facies are distributed in the three-dimensional grid by using the object-based method with consideration of lateral continuity, vertical range and orientation in each facies. The porosity and permeability are modeled stochastically to conditioning to facies. The advantage of object-based modeling constrained the petrophysical model to facies model to assign the high porosities and permeability distributed within channel sand-dominated facies. The low porosities and permeability populated within floodplain-dominated facies. CO2injections were simulated using ECLIPSE300-CO2STORE. Sensitivity analysis has been conducted to investigate the behavior of CO2 plume for reservoir saline sandstone. Simulation results indicate the extent of CO2 plume dynamic is sensitivity to the geometry and sinuosity of the fluvial channel. The object-based modeling can construct the geological model to relate with fluvial channel facies correctly. This method is used to support for geological CO2 storage modeling in the fluvial deposit. As a general evaluation, this study can contribute to CO2 storage in an offshore area in Vietnam.

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