Corrosion is always recognized as one of the biggest flow assurance challenges of natural gas fields. During the pipeline design and maintenance, it is not enough to only use the equations of the limitation for the maximum erosional velocity from API RP 14E to deal with the balance of pipeline diameter, flow rate and the corrosion inhibitor film stability and effectiveness. In order to get more information of the relationship between flow and inhibitor for wet subsea pipeline, a HTHP-RC and a wet gas flow loop were employed to simulate typical flow conditions of subsea gas pipeline in this paper, as well as the research of corrosion behaviors before and after inhibitor injection. The stability of inhibitor film on the pipeline steel’s surface under high gas velocities under the CO2 wet gas corrosion environment was evaluated. The influence of pipeline operating parameters such as gas velocity, wall shear stress, CO2 pressure, total pressure, and inhibitor dosage, was investigated during the HTHP-RC tests and flow loop tests. The results give the recommendation of the gas velocity and the inhibitor limits of the subsea wet gas pipeline.

Subject
Stability, Flow loop, Corrosion rate, Inhibitor films, Flow velocity, Wall shear stress, Pipelines, Gas pressure, Gas velocity, Partial pressures, Corrosion inhibitors, Wet gas, Pitting
Keywords:
corrosion Inhibitor, flow loop, rotating cage, wall shear stress, wet gas
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2017
Association for Materials Protection and Performance (AMPP)
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