To address the technical challenge of water lock damage caused by fracturing fluid retention during the fracturing development of tight gas reservoirs, which restricts gas seepage and flowback efficiency, this study aims to develop a gas wettability reversal fracturing fluid system with both permeability enhancement and flowback promotion functions, and to provide an effective technical approach for mitigating water lock damage in tight gas reservoirs through systematic evaluation of its key performance indicators. The study first screened nine gas wetting agents using surface tension and core contact angle as evaluation indicators, identifying two high-performance systems, HB-2 and YS-2. Further screening through concentration optimization, high temperature aging, and salt resistance evaluation confirmed that HB-2 at a concentration of 0.3 wt% exhibited the best overall performance, withstanding temperatures up to 120°C and adapting to high salinity formation water environments.The gas-wetting fracturing fluid system built around 0.3 wt% HB-2 exhibits good compatibility with conventional additives. Its viscoelasticity and rheological properties meet the requirements of fracturing operations. Under the condition of 95°C, the system can be completely broken within 60 min. The viscosity of the broken gel fluid is lower than 3 mPa·s, and the residue content is lower than 50 mg/L. All indicators meet the industry standard (SY/T 6376-2008). Laboratory experiment results confirm that this system provides excellent formation damage control. Wettability tests show that after treatment with this system, the water phase contact angle of the core increases from a hydrophilic state (< 90°) to above 116°, achieving a wettability reversal of the reservoir rock from strongly hydrophilic to strongly hydrophobic (gas-wetting). Core displacement tests and nuclear magnetic resonance analysis indicate that compared with conventional fracturing fluid, this system can effectively mitigate the problems of pore reduction and permeability decline caused by solid phase retention, achieving a higher permeability retention rate for high-permeability cores and causing less damage to the reservoir pore structure.This study successfully developed a gas wettability reversal fracturing fluid system based on 0.3 weight percentage HB-2. The system not only exhibits excellent overall performance that meets industry standards, but more importantly, it can significantly alter the wettability of reservoir rock surfaces, achieving a reversal from strongly hydrophilic to strongly hydrophobic. It demonstrates favorable formation damage control effectiveness and permeability-increasing and flowback-promoting potential, providing an effective technical means for the efficient development of tight gas reservoirs.