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To meet the engineering requirements for predicting the migration characteristics of CO2 injected into saline layers, a finite element numerical model for geological storage of CO2 in saline layers was established based on the COMSOL Multiphysics platform. The influences of factors such as formation porosity, temperature, and CO2 injection flow rate on CO2 migration behavior in saline layers were explored, and a portable simulation software was developed. Finally, a finite element numerical simulation based method for predicting CO2 migration behavior in geological storage was developed. Taking the Shiqianfeng Formation of China Shenhua Group"s Saline Layer Carbon Dioxide Capture and Geological Storage Project as an example, the finite element numerical modeling, influencing factors and laws of CO2 migration behavior were studied. It has been shown that: (1) in the early stage of CO2 injection, CO2 migrates approximately horizontally and forms a high-pressure area around the injection well; with the continuous injection of CO2, the distribution area of CO2 in the saline layer gradually forms a tongue shape with a wide top and a narrow bottom, and the pressure in the saline layer decreases to some extent; after the injection of CO2 is stopped, the pressure of the saline water layer gradually decreases to the original formation pressure level, leading to the phenomenon of reverse displacement of CO2 by saline water; (2) as the porosity of the formation decreases, the formation pressure increases exponentially after CO2 is injected into the saline water layer, and the change in porosity affects the migration pattern of CO2; after the injection of CO2 is stopped, as the porosity of the saline layer increases, the reverse displacement phenomenon of saline water becomes more obvious, and the accumulation of CO2 at the top of the saline layer increases; (3) the increase in formation temperature enhances the reverse displacement effect of saline water, and the boundary angle of the tongue-shaped area increases during CO2 migration; the lateral distribution range of CO2 at the top of the saline layer gradually expands; (4) the diffusion range of CO2 expands with the increase of the injection flow rate; under the same injection flow rate, the diffusion rate of CO2 decreases over time; after the injection of CO2 is stopped, the lower the injection flow rate, the more obvious the reverse displacement phenomenon; (5) the simulation software developed in this work has functional modules such as numerical model establishment and simulation data analysis, and the test results indicate the usability of the software. The research results can provide a theoretical and model basis for the selection of CO2 geological storage sites, optimization of injection conditions, and leakage monitoring.