Abstract: To investigate the adaptability and oil displacement efficiency of oxygen-reduced air foam flooding in tight sandstone reservoirs and optimize key parameters, a comprehensive study involving 3D geological modeling and numerical simulation was conducted based on the actual reservoir conditions of Block P in Yanchang Oilfield. The results prove that oxygen-reduced air foam flooding exhibits significantly superior advantages in enhancing oil recovery compared to water flooding, continuous gas flooding, and water-alternating-gas (WAG) flooding. Furthermore, regarding the implementation method of foam flooding, the gas-liquid alternating slug injection approach outperforms simultaneous co-injection. Particularly, it can increase the 10-year recovery factor by more than 3.5 percentage points and reduce the water cut by over 8 percentage points compared to water flooding. Sensitivity analysis of key injection-production parameters reveals that the injection-production ratio presents the most significant impact on displacement efficiency, followed by the gas-liquid ratio and foam solution concentration, while the slug cycle shows relatively less effect. In field application, it is recommended to maintain the injection-production ratio no less than 1.2, gas-liquid ratio of 3∶1, foam solution concentration of 0.45%, and slug cycle of 40 days, with subsequent adjustments based on dynamic injection-production responses. The field test results show that by implementing optimal well group selection, compared to water flooding, the water cut in reduced-oxygen air foam flooding was decreased by up to 24 percentage points, while the oil production was increased up to 88.46%. These findings provide a feasible approach for effectively improving the development performance in tight sandstone reservoirs and serve as valuable references for oxygen-reduced air foam flooding in similar reservoirs.