The hydraulic fracturing conductivity of reservoirs is a critical factor influencing the production enhancement in oil and gas fields. For deep tight reservoirs, conductivity diminishes rapidly due to reservoir characteristics, high closure pressure, and proppant type, severely affecting recovery rates. Choosing the appropriate proppant is crucial for the fracturing design of deep tight reservoirs. This study selects various types of ceramsite proppants to conduct fracture conductivity evaluation experiments. The results indicate that under high closure pressure, larger particle sizes lead to higher crush rates and a greater decrease in conductivity. High-strength proppants perform better in fracturing operations. The larger the proportion of large-sized proppants in the combination, the better the fracture conductivity. The optimal fracture conductivity is achieved when the combination of 40/70 and 70/140 mesh ceramic proppants is in a 2:1 ratio. Increasing the sand concentration enhances fracture conductivity and reduces the effects of proppant embedment; The factors influencing fracture conductivity in deep tight reservoirs are ranked in importance as follows: proppant particle size, strength, particle size combination ratios, sand concentration, and proppant embedment. Based on experimental determinations under high closure pressure conditions, proppant with 40/70 mesh and 70/140 mesh ceramsite in a mixture ratio of 2:1, sand concentration of 9.0 kg/m2, and strength of 103 MPa was preferred for on-site fracturing. The research findings offer valuable technical support for improving fracturing efficiency in deep tight reservoirs.