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A Novel Internal Corrosion Risk Management Methodology for Relief Lines

Picture for A Novel Internal Corrosion Risk Management Methodology for Relief Lines
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RLs are susceptible to internal corrosion that is influenced mainly by fluid corrosiveness including factors such as temperature, pH, carbon dioxide (CO2) and hydrogen sulfide (H2S) content, water chemistry, flow stagnation, wettability, and presence of deposits.


Generally, for corrosion to occur there must be liquid water with sufficient quantity to wet the pipe surface. Once water wet, the line will corrode at a rate determined by the chemistry of the water, acidity and quantity of deposits.

Product Number: 51323-19468-SG
Author: Ayman A. Alabdullatif, Faisal M. Al-Abbas, Rakan A. Al-Shebil, Lay Seong Teh
Publication Date: 2023
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$20.00

A new internal corrosion risk management methodology was developed and applied on more than 1000 relief lines (RLs) in upstream production facilities. The new methodology is qualitative and focuses on probability of failure considering system corrosivity, and inspection findings. System corrosivity is determined based on multiple factors including service, pressure, design configuration, and material of construction. For each of these factors, a risk score is calculated, and an overall system corrosivity is calculated as a composite measure of all the factors. As for inspection findings, the corrosion rate was used to evaluate the extent of the damage. Through this qualitative methodology, a very large number of relief lines were assessed and prioritized for further inspection. The methodology was verified against field data as High-risk lines have shown more severe corrosion on average compared to Medium-risk lines. As of the time of this paper, Low-risk lines are yet to be assessed.

A new internal corrosion risk management methodology was developed and applied on more than 1000 relief lines (RLs) in upstream production facilities. The new methodology is qualitative and focuses on probability of failure considering system corrosivity, and inspection findings. System corrosivity is determined based on multiple factors including service, pressure, design configuration, and material of construction. For each of these factors, a risk score is calculated, and an overall system corrosivity is calculated as a composite measure of all the factors. As for inspection findings, the corrosion rate was used to evaluate the extent of the damage. Through this qualitative methodology, a very large number of relief lines were assessed and prioritized for further inspection. The methodology was verified against field data as High-risk lines have shown more severe corrosion on average compared to Medium-risk lines. As of the time of this paper, Low-risk lines are yet to be assessed.

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Corrosion is defined as the degradation of a material or its properties due to a reaction with the environment and is one of the most common pipeline integrity threats for operators. External corrosion may be visually inspected during excavation; however, due to accessibility, additional non-destructive examination (NDE) methods must be utilized to identify the presence and severity of internal corrosion.


Understanding the chemistry and electrical properties of how corrosion occurs aids in mitigating the presence of corrosion, specifically internal corrosion.
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04199 Internal Corrosion of Dry Gas Pipelines during Upsets

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