Abstract: In order to address the issue of gas channeling during the development of high-temperature and high-salinity oil reservoirs, which seriously affects the development effect, the long carbon chain hydroxysulfobetaine and the short carbon chain hydroxysulfobetaine were compounded according to the mass ratio of 2∶1 to construct a temperature-resistant and salt-resistant foaming agent MHSB12, and the gas mobility was controlled by the foam generated by this foaming agent. The performance of MHSB12 in two kinds of simulated formation water with salt content of 11.19×10⁴ and 22.38×10⁴ mg/L was comprehensively compared by conducting experiments such as determination of critical micelle mass fraction, interfacial rheology and static adsorption capacity, evaluation of bulk phase foam performance foaming capacity in porous media. The results show that under high salt conditions, MHSB12 has lower critical micelle mass fraction, higher surface expansion modulus, stronger foaming performance and foam stability. When the mass fraction of MHSB12 is 1%, the foaming agent solution meets the surfactant adsorption standard for enhanced oil recovery, which is suitable for deep clastic rocks in Tarim Oilfield and other similar reservoirs. Under the same mass fraction of MHSB12, the adsorption capacity of foaming agent solution with higher salt content is slightly lower. Compared with low salt conditions, the mobility control ability of MHSB12 in the core under high salt conditions is significantly weaker. Hence the evaluation of flow experiment should be paid attention to when screening foaming agents for field use. The study has practical guiding significance for screening foaming and evaluating foaming agents forenhancing oil/gas recovery.

Key words: hydroxysulfobetaine, foaming agent, temperature and salt tolerance, flow test, foam