Numerical simulation of steam-chemical oil recovery processes require high temperature multiphase rock-fluid properties such as relative permeabilities and capillary numbers. These parameters are needed to predict and evaluate oil recovery performance and efficiency. Experiments in both Berea sandstone and sandpacks have been conducted to measure relative permeabilities of high and low tension oil-water mixtures at elevated temperatures. A new mathematical model consisting of sets of empirical correlations based on experimental data have been developed for relating endpoint relative permeabilities to both residual and mobile oil-water saturations and capillary numbers to residual oil-water saturations.

The tests were run over a wide range of temperature, 72° to 400°F, and overburden pressure range of 500 to 1000 psia. It is our belief that this model is new for the range of temperature and pressure of steam oil recovery processes with chemical additives. Predictive results made with empirical correlations are in good agreement with experimental results.

You can access this article if you purchase or spend a download.