Modeling the H2S contribution to internal corrosion rate of natural gas pipeline
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Corrosion has been identified as a major cause of pipeline failure, which leads to grievous environmental degradation, hence, the need for predicting the integrity of the service life of the pipeline. This work develops a predictive model on corrosion rate for natural gas pipeline with H2S as corroding agent. The model is based on the thermodynamic properties of the fluid and the developed rate is plotted against various operating conditions. The model shows that corrosion rate increases with temperature, fluid fugacity, wall shear stress, superficial velocity, and acidity. It is recommended that H2S should be removed as much as possible from the sour natural gas before its transportation through the pipe length.
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