This project focuses on optimizing production of a gas well. The reservoir in this study involves a gas condensate reservoir. Gas condensate reservoirs behave in a complex manner as it introduces liquid condensate near the wellbore region which leads to significant decrease in productivity of the well. Liquid hold up is also an important issue to consider in a gas condensate reservoir as this could impact the wells productivity. Parameters such as tubing size, skin factor, condensate gas ratio, wellhead pressure and water gas ratio are used to implement a sensitivity analysis in Prosper. Based on the Monte Carlo results from MBAL, there is a 90 percent probability of the gas condensate reservoir to produce 360 Bscf of gas and 23 MMstb of recoverable condensate. Overall, the 4.5 inch tubing pipe promotes the optimum rate based on water gas ratio, condensate gas ratio and wellhead pressure. The 4.5-inch tubing does not promote erosional velocity and liquid loading issues compared to various tubing sizes.