Fractured-vuggy carbonate reservoirs in Tahe Oilfield pose significant challenges for enhanced oil recovery during mid-to-late development, due to their high-temperature, high-salinity conditions and complex storage structures. To address this, an adaptability assessment of foam-assisted gas flooding technology resistant to such harsh conditions was carried out. The study encompassed three main aspects: foam system screening and performance evaluation, physical model displacement experiments, and field pilot testing. Results show that the selected TKQP-3 foam performs excellently at a mass concentration of 0.5%. Under high-temperature and high-pressure conditions, it maintains a foam volume expansion factor above 4, with a drainage half-life of approximately 30 minutes. After rock cuttings adsorption, the foam volume retention remains at 97%, and the resistance factor exceeds 40 at a gas-liquid ratio of 1.5:1. Laboratory simulations confirmed that the system enhances sweep efficiency through mechanisms including flow diversion, improved gas-oil mobility ratio, synergistic foam-gas-water interaction, and reduced interfacial tension, contributing to an average EOR increase of over 10%. Field pilot tests further validated its effectiveness, with the A71 well group achieving a cumulative incremental oil production of 10,373 tons. Overall, foam-assisted gas flooding demonstrates strong adaptability and considerable potential for EOR in Tahe fractured-vuggy reservoirs.