Assessment of Hydrate Formation Risk in Niger Delta Gas Condensate Systems: Well Risk Ranking and Optimization of Meg Inhibition

This research presents an integrated approach to comprehending and managing natural gas formation of hydrate in offshore gas production systems, with a specific focus on condensates from the Niger Delta. The study commences with a comprehensive characterization of gas condensates from four wells (A, B, C, and D), showing compositional and physical properties that predispose them to the formation of hydrate under deepwater thermodynamic conditions. Notably, high concentrations of methane, propane, and acid gases such as CO₂ were found to influence hydrate risks across the wells appreciably. Hydrate formation envelope analysis showed that Well C has the narrowest operational margin, making it very sensitive to thermodynamic fluctuations. Conversely, Well A exhibited the widest operational margin, offering the most operational flexibility among the four wells. Monoethylene glycol (MEG) injection was shown to be an effective hydrate mitigation approach, with 50% MEG concentration achieving the greatest inhibition performance by considerably lowering the hydrate dissociation temperature across all wells, thus moving the formation boundary leftward and reducing hydrate risk. This result authenticates earlier research and validates MEG-based hydrate risk management as a practical and economical approach to sustaining continuous condensate flow in offshore systems.