Optimizing Multiphase Flow Characterization via Core-flooding and Automated History Matching Using SENDRA Simulation

Using Core-flooding and SENDRA Simulation in Carbonate Rock Analysis

Abstract

Multiphase flow simulation within porous media is essential for predicting the reservoir performance and optimizing the oil recovery strategies. This paper aims to estimate the Relative Permeability (K_r) and Capillary Pressure (P_c) parameters by performing core flooding experiments using Sendra software. The laboratory experiments were carried out using a sandstone core under controlled conditions. A four-step protocol was developed to obtain the injection rates, production data and pressure responses, which were utilized for simulation and history matching. To analyze the experimental data and obtain K_r and P_c curves, the SENDRA-1D black oil simulator was used. The results were tested using a total of 25 correlation combinations to match the experimental results. The most convincing correlation was derived to be the Sigmund-McCaffery correlation and LET-Primary drainage correlation with least Residual Sum of Square (RSS) for oil production and pressure curves. The analysis identified a Critical Water Saturation (S_wc) of 40% which indicates the two-phase flow. While, Residual Oil Saturation (S_or) was obtained at 28%, which signifies oil volume left for post-water flooding. The P_c curve declined quickly with increasing S_wc and becomes zero above 45%, indicating a water-wet system. The results demonstrates that this automated simulation workflow using SENDRA software is much more effective and reliable in characterizing multiphase flows in both steady state and unsteady state processes. The proposed methodology saves experimental time and produces reliable data generation over a significant saturation range. Thus, making it a robust tool for reservoir analysis in multiphase flow systems.