Tight gas, as an unconventional natural gas source, is characterized by low permeability, low porosity, and high water saturation in its reservoirs. When hydraulic fracturing is used for reservoir enhancement, the unclear relationship between fracture conductivity, fracture half-length, and reservoir parameters often leads to suboptimal fracture dimensions, thus limiting reservoir productivity. Consequently, a study was initiated to examine the rationality of fracture dimensions in artificial hydraulic fracturing operations. Utilizing reservoir numerical simulation, a numerical model calibrated with actual production data using Eclipse software, an optimization of fracture half-length and conductivity based on reservoir permeability was initially performed, with high gas production as the primary optimization objective. Subsequently, considering the high water saturation in tight gas reservoirs, fracture dimensions were optimized based on water saturation levels. An innovative approach involved adjusting the established conductivity optimization formula using water saturation. Introducing a saturation correction coefficient α, with a gas production amplitude of 5% as the benchmark, a modified formula for fracture conductivity, accounting for both reservoir permeability and water saturation, was derived. The results indicate that for tight gas reservoirs, long fractures with low conductivity are optimal for low-permeability reservoirs (K < 0.35), while short fractures with high conductivity are preferred for high-permeability reservoirs (K > 0.35) to maximize reservoir productivity. Higher water saturation levels require greater conductivity to achieve higher gas production. Validation of the optimized results against actual field fracturing data confirmed the accuracy of the fitting results. This study offers a scientific basis and convenient method for evaluating and designing fracture dimensions in the broader region or similar gas fields.