The application of morphological operations, level sets, and phase field methods in CO2 displacement

The tight sandstone reservoir is recognized as a promising alternative resource in the realm of oil and gas exploration. However, once the peak production of the reservoir is surpassed, there is a sharp decline in output. The implementation of CO2 injection in these tight oil blocks for enhanced oil recovery is seen as a viable development strategy. The traditional Darcy flow model has faced significant challenges in accurately capturing the intricate dynamics of multiphase flow within the fine-grained matrix of such reservoirs. The characterization of micro pore models in tight reservoirs presents a major obstacle.This study employs advanced morphological operations and level set methods to characterize and establish a high-fidelity microscale mesh model for the pore throat network in tight reservoir rocks. By utilizing the Navier Stokes equation and phase field equation, we simulated the concurrent flow behavior of oil and CO2 within the model. We elucidated the factors contributing to the formation of multiple residual oils within the pores. Through varying simulation parameters, we demonstrated that the reduction in fluid dynamics, coupled with decreased interfacial tension and increased carbon dioxide injection rate, synergistically enhance the overall displacement effect following enhanced injection schemes.