In order to solve the problem of difficult injection of ordinary water-based foaming agent in the process of gas channeling control in low permeability reservoirs，taking the reservoir of 530 well area in the eighth district of Xinjiang Oilfield as the research object，a CO₂ gas-soluble foam system was constructed，and the injection performance of the system was evaluated from interfacial tension，microstructure and rheology. The plugging effect of CO₂ gas-soluble foam and water-based foam was compared by core flow experiment，and the profile control and flooding effect was evaluated by parallel core flow experiment. The foam system under reservoir conditions was determined to be 0.4% QR-1529 + 1.0% ethanol. The interfacial tension of the foam system was as low as 1.47 mN/m at 30 ℃ and 24 MPa. The foam microstructure was compact and had a good skeleton structure，and the additive molecules enhanced the solubility of the foaming agent in CO₂. In addition，the rheology of the foam system contributed to its flow in the near wellbore area，exhibiting its good injectivity. The core flow experiment showed that the resistance factor and residual resistance factor of CO₂ gas-soluble foam were 18.5 and 13.0，which was higher 7.2 and 7.0 than those of water-based foam， respectively. When the core permeability difference was 2.54，the profile control effect of CO₂ gas-soluble foam was remarkable. The foam flooding of low permeability core enhanced the oil recovery rate by 13.7 percentage point，and the subsequent gas flooding enhanced the oil recovery rate by 15.88 percentage point. The CO₂ gas-soluble foam system has good injection performance and profile control ability.