In the development of water-flooded oil fields entering the high water-cut stage

the remaining oil often accumulates at the top of structural high positions or thick oil layers

areas not effectively covered by the existing well network. Utilizing the intrinsic characteristics of the reservoir to inject CO

2

and form a gas cap drive can effectively improve development outcomes and achieve CO

2

sequestration. However

the suitability of specific reservoirs for gas cap drive development requires further study. This study delves into the effectiveness of CO

2

gas cap drive in high water-cut reservoir

s by examining the movement of the oil-gas interface during the gas cap drive process

using both numerical and physical simulations. Key evaluation metrics include enhanced oil recovery rate

oil displacement efficiency

time to reach the critical gas-oil ratio

and gas retention rate. The research assesses how various reservoir characteristics

such as formation dip angle

crude oil density

viscosity

reservoir confinement

permeability

and the strength of water drive

influence the efficiency of CO

2

gas cap drive for both oil displacement and sequestration. Focusing on these main evaluation criteria

the study identifies that the suitability of CO

2

gas cap drive in reservoirs during the high water-cut phase is significantly influenced by factors such as reservoir confinement

formation dip angle

crude oil viscosity

permeability

and reservoir thickness. These findings aim to provide a foundation for broadening the application of CO

2

flooding techniques. crude oil viscosity

reservoir permeability

and thickness

to provide a basis for expanding the application range of CO

2

flooding.