Previous studies in literature and field experience indicates that hydrates mitigation can increase production cost by 15%. Hence, the need for optimum hydrates inhibitor selection. In this study, a deepwater oil field; currently producing at over 100,000 bbl/d had experienced hydrates and an integrated production modelling approach was utilized to model this scenario via MAXIMUS 6.20. The key input data to model were reservoir pressure at 2650 psia; Oil API Gravity at 35.4 °API; GOR at 1324 scf/stb and the produced water rate at an average of 3138 STB/d. Key results indicates that the injection of LDHI into the hydrate lattice within the hydrocarbon stream dispersed the hydrates particles in an unsteady manner and subsequently prevented the formation of hydrates at 40 gal/day. The cost of using LDHI was lower by over $520/day, from simulation results. This study also assessed technical benefits and challenges of using LDHI and MEG in deepwater scenario.
