Reservoir recovery study with stability analysis model constructed by water-driven oil flat sand filling experiment: example of well area X in Tankou oilfield, China

Abstract

The study of the law and degree of injection and extraction coupling in old oil areas is a difficult point that affects the recovery rate. The traditional experimental and numerical simulation research methods lack validation and working condition prediction. This study has improved the working steps and supplemented the lack of program validation link through the methods of data prediction and mathematical argumentation. This program has been implemented in the Tamkou field. In addition, we determined the relationship between different permeability, crude oil viscosity, and recovery rate influencing factors on recovery under the premise of a fixed well network, and the DGM (1,1) model prediction yielded the recovery rates of 8.93 and 12.08 for the next 2 time nodes. The analyses showed that adopting the means of water blending and dosing to adjust the crude oil viscosity to 90 mPa s, and adopting the water injection rate of 5 mL/min to extract the best recovery rate. Min water injection rate is optimal for extraction.