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. In this paper，the adaptability evaluation of high temperature and high salinity resistant foam-assisted gas flooding technology in this kind of reservoir was carried out through the optimization of foam system，the physical model oil displacement simulation experiment of weathering crust and the field pilot test. The results showed that the temperature-resistant and salt-resistant foam system TKQP-3，composed of 0.12 % anionic-nonionic surfactant SS-163 + 0.18% anionic surfactant AES + 0.2% foam stabilizer SAV-236，could stably adapt to the harsh reservoir environment with temperature of 120 ℃，salinity of 24×10⁴ mg/L and pressure of 30 MPa. The foaming volume was 4 times that of the base fluid，and the half-life of the foam was about 30 min. The foam retention rate after cutting adsorption was still as high as 97%. At 120 ℃，the resistance factor of the foam system was more than 40 when the gas-liquid ratio was 1.5∶1 in a simple fracture-cavity sand-filled tube model with a liquid phase permeability of about 1500 × 10^-3 μm². Indoor physical simulation experiments had confirmed that the system could effectively expand the swept volume and increase the recovery rate by an average of more than 10 percentage points through the mechanisms of regulating flow steering，improving the oil-gas mobility ratio，promoting foam-gas-water three-phase synergy and reducing interfacial tension. The field test further verified its application effect，and the cumulative oil increase of the A71 well group reached up to10 373 t. In summary，the foam-assisted gas flooding technology has shown good adaptability and development potential in Tahe fractured-vuggy reservoirs.