Offshore oil and gas production poses unique problems due to complex reservoir behaviour, limited accessibility, and the high expenditures of subsea infrastructure. Optimizing the performance of offshore production wells is thus critical to ensuring maximum hydrocarbon recovery, economic viability, and long-term field sustainability. Alpha, Beta, Gamma, Delta, and Epsilon are the five anticipated oil-producing wells that are expected to provide a 20-year production span from the Horizon Oilfield, which is situated offshore in south-west Ghana. The purpose of this study is to use PIPESIM to maximize these wells' performance in both natural flow and artificial lift scenarios. Sensitivity experiments on tube size, gas–liquid ratio (GLR), water cut, and reservoir pressure depletion were carried out in addition to Inflow Performance Relationship (IPR) and Vertical Lift Performance (VLP) evaluations. The findings show that by reducing frictional losses, a 7-inch tubing diameter optimizes flow-rate. However, because of hydro-static and back pressure accumulation, increases in GLR and water cut have a negative impact on well performance. The pressures associated with reservoir abandonment varied from 500 to 1000 psia. Electric Submersible Pumps (ESPs) were designed and selected for all wells to sustain production in the late phases of life, resulting in considerable improvements in drawdown and production rates even at 100% water cut. The findings provide strategic insights for optimizing well productivity and recovery in offshore reservoirs with long-term production.