Modelling the natural gas pipeline internal corrosion rate resulting from hydrate formation

Hydrate formation along a long natural gas pipeline has recently been established to initiate different types of internal corrosion along the pipe-length based on the formation stage and point. These corrosions may lead to disintegration of the pipe's properties and eventually result into the pipe's leakage or full-bore rupture. Apart from the enormous economic implications on the operating company, the conveyed fluid upon escape to the environment poses the risk of fire, reduction of air quality and other health hazards. This article develops a predictive model on internal corrosion rate resulting from hydrate formation along a natural gas pipeline based on the thermodynamics properties of the transported fluid with H2O being 90% of the clathrates and the predictive rates were plotted against different operating conditions. The model clearly showed that the corrosion rate increases with temperature, wall shear stress, superficial velocity, fluid fugacity and acidity. Since the result trends agree with those of existing models, then, this model can be said to be reliable. To minimize the problems, some predictive and corrective management options are recommended on hydrate formation