Correction for capillary pressure influence on relative permeability by combining modified black oil model and Genetic Algorithm

The substantial interference of the tight reservoir's capillary pressure on relative permeability measurement can significantly diminish prediction accuracy oilfield production. This study established an innovative method to eliminate effect calculation by combining modified numerical simulation model and Genetic Algorithm. Steady-state measurements were conducted core sample (0.0321mD) obtain initial curves using Darcy's law. A that considers equivalent phase for water oil at outlet surface directly simulates fixed injection-rate boundary conditions without wells has been proposed. After analysis saturation distribution along core, absolute permeability, residual saturation, two-phase corresponding need be optimized Algorithm based match experimental results. outcomes show is 19.63% higher than experimentally measured value, 17.46% lower saturation. For other saturations, differences between results range from 25.93% 10.57%. whole divergence experiment about average inlet Kr 1.57%, far less 69.72% unoptimized curves. research great significance accurately obtaining reservoir with intense pressure.