A numerical study of the effects of temperature and injection velocity on oil-water relative permeability for enhanced oil recovery

The paper quantitatively explore the influence of injection rate and temperature on oil-water relative permeability curves during hot water flooding operations in a porous medium flow. ANSYS-CFD was used to construct numerical model hot-water into an oil saturated sandstone core sample. modelling technique is based Eulerian-Mixture model, using 3D cylindrical sample with known inherent porosity. Injection at 20 °C injected that kept 63 had 14-mD 26% For investigation, three distinct rates 2.9410–6 m/s, 4.41 × 10 ?6 5.88 m/s were utilised. Furthermore, same procedures repeated under conditions, but changed 90 °C, allowing us quantify immiscible results this study show strongly influenced by flow, while effect negligible. In addition, flow influences residual saturation, as well associated effective permeability. From there little sensitivity or temperature. This does not provide proof effects do exist genuine reservoir fluids, rocks, ranges. However, has demonstrated feasibility utilising CFD approaches estimate fluid permeability, combined change potential for considerable cost-time advantages.