The present paper aims at quantifying the amount of iron products that a sweet gas pipeline may produce even in the case of well controlled bottom of line and top of line corrosions. This quantification is made from about 10 field cases of wet gas pipelines operated with or without MEG as an hydrate inhibitor and with either corrosion inhibitor or pH control as corrosion mitigation solutions. Average residual Bottom Line Corrosion rates ranging from 10 to 100 µm/yr over 5 to 20% of the surface are relevant to most cases, depending on the temperature and the flow regime of the pipeline.
The possible contributions of mill scale, pre-rusting during storage of linepipes, and hydrotest water are also evaluated. A simple spreadsheet model including all these contributions is established to help carrying out such evaluations.
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