摘要
•Two-phase flow behavior in 3D natural rock is calculated at various conditions.•Flow patterns are classified in the diagram of capillary number–viscosity ratio.•Optimum fluid saturation scales with capillary number and viscosity ratio.•Different flow patterns exist simultaneously in heterogeneous natural rock.•This approach is beneficial for identifying preferable reservoir conditions.