Recently, the development of unconventional oil and gas reservoirs has routinely used hydraulic fracturing, the majority of these reservoirs have low permeability, tight formations, or shale formations, necessitating the use of specialized technologies to produce hydrocarbons. Improved hydrocarbon production can be achieved through hydraulic fractures; but, if not controlled, they can cause environmental problems in the aquifer zones by penetrating the overlying cap rock. This research evaluates the effect of different types of fracturing fluid and proppant (utilizing different perforation intervals) on post-fracture vertical gas well performance in the Cotton Valley Sandstone Formation of Eastern Texas, USA. Fracpro fracture simulator was used to model a hydraulic fracture and four different perforation lengths were tested, including 20, 40, 80, and 100 ft, along with hybrid and slick water frac fluids, and sand and ceramic proppants. Sixteen scenarios were used, and numerical results showed that Scenario 16 produced the best-propped fracture geometry and dimensionless conductivity from a 100-foot perforation, hybrid fracturing fluid, and ceramic proppant. After ten years of forecasting, Scenario 16 with the highest recovery increased gas recovery from 13.56 to 63.68% with a flow rate of 110.6 Mscf/day. Economic analysis was conducted using simulations of propped hydraulic fractures for all scenarios. The findings of the simulation indicated that Scenario 16 had the highest net present value (NPV).