CO₂ plume geothermal system (CPGS) plays a significant role in reducing carbon emissions and promoting geothermal development. Current research mainly focuses on high-temperature saline aquifers or abandoned high-temperature oil reservoirs, with limited studies on the wellbore-reservoir coupling of depleted high-temperature gas reservoirs. The high-temperature gas reservoirs of the Yellow River Formation in the Yingge Basin were chosen as the research subject. The COMSOL software was utilized to establish an ideal well-reservoir coupled CPGS model. The heat exchange characteristics during the operation of CPGS were analyzed, and a sensitivity study was conducted on the injection and production parameters. The simulation results indicate that excessive injection and production rates can accelerate temperature decline. It is recommended to adjust injection rates at different stages to mitigate this effect. Shortening the well spacing can expedite thermal breakthrough, while appropriately increasing well spacing can extend the system's lifespan. The injection temperature has a relatively minor impact on heat extraction. Increasing the injection temperature can raise the outlet temperature but decreases the heat extraction rate. Balancing these two factors is necessary during development.