Yanmuxi Oilfield of Tuha，a high salinity，medium and low permeability reservoir，has entered the stage of ultra-high water cut development. In order to meet the technical requirements of enhancing oil recovery of oilfield，the experimental study on the effect of inorganic gel flooding and parameter optimization in high salinity reservoir was carried out taking the geological characteristics and fluid properties of reservoir of Yanmuxi oilfield as simulation objects. The results showed that when the salinity was 151453 mg/L，the core permeability of high/middle/low permeability layer was 800×10-3/200×10-3/50×10-3μm2，the slug size of the main agent，0.03 mol/L sodium silicate solution，was 0.06—0.08 PV and the injection cycle was 5—6，the utilization degree of the low/medium permeability layer in the core was higher，the water cut decreased by 10% and the oil recovery increased by above 10%. Under the condition of the same amount of main agent，compared with the "equal concentration" injection method for each round of reagents，the“incremental injection”method had better effect on the deep fluid diversion and the recovery rate increased by 1.53%. Compared with "inorganic gel "or "Cr3+ polymer gel"，"inorganic gel + surfactant" or "Cr3+ polymer gel+surfactant" had higher efficiency of oil displacement in sweep area of profile control and flooding，and the final recovery rate increased by about 4%，however，the "output/input" ratio was smaller. Compared with the "inorganic gel"，the "Cr3+ polymer gel" had a larger increase in the recovery rate of the polymer flooding，but the preparation and injection process of the polymer solution was more complex and the technical and economic effect was poor.