Effect of Secondary Cooling Rate in Corrosion Performance of Line Pipe Material in Sour Service Applications
Publication: Journal of Pipeline Systems Engineering and Practice
Volume 12, Issue 2
Abstract
The majority of hydrocarbon reservoirs discovered in recent years contain considerable corrosive hydrogen sulfide. The pipeline material for this application needs to be resistant to hydrogen-induced defects. API 5L PSL2 X60MS is one of the most common material grades for use in sour service applications. However, due to the complexity of affecting parameters, the fabrication of this type of material is still challenging. This study investigates the effect of the cooling rate during the steel-making process on the corrosion resistance of API 5L X60MS grade. Dozens of mechanical and corrosion resistance tests were performed to investigate the susceptibility of the material for hydrogen-induced cracking (HIC) and sulfide stress cracking (SSC) failure mechanisms. They found that the cooling rate is the most influential factor in the HIC/SSC performance of the samples. The slab cooling rate dictates the final hydrogen content of the plates; in slow cooling rate regimes, the atomic hydrogen finds more chances to escape from the steel. This study experimentally revealed how the arrangement of the slabs in bundles during the slow cooling process can affect the HIC and SSC test results. This study also indicated that altering the arrangement of the slabs enhanced the HIC/SSC performance of the plate samples.
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Data Availability Statement
All data, models, and code generated or used during this study appear in the published article.
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Published In
Journal of Pipeline Systems Engineering and Practice
Volume 12 • Issue 2 • May 2021
Copyright
© 2021 American Society of Civil Engineers.
History
Received: Mar 25, 2020
Accepted: Oct 20, 2020
Published online: Jan 31, 2021
Published in print: May 1, 2021
Discussion open until: Jun 30, 2021
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