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51314-3887-Enhancement of Internal Corrosion Threat Guidelines for Dry Natural Gas Pipelines

Picture for Enhancement of Internal Corrosion Threat Guidelines for Dry Natural Gas Pipelines
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Product Number: 51314-3887-SG
ISBN: 3887 2014 CP
Author: Xihua He
Publication Date: 2014
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$20.00
$20.00
Internal corrosion threat in dry natural gas pipelines is low because of the very low water content controlled under a tariff limit. However the threat may exist when liquid water is brought into the pipe by condensation hydrotesting or intrusion from lateral components. In an earlier project funded by Pipeline Research Council International (PRCI) probabilistic models and tools were developed to support guidelines to quantify the internal corrosion threat from condensation for a given dry natural gas pipeline operating conditions. The current project collected and analyzed more field data to enhance the probabilistic model especially in the conditions where the risk of internal corrosion is higher. The enhancement improved the practical tools and guidelines by attaining a confident prediction of the internal corrosion threat. With these tools an operator would be able to evaluate whether the current operation of its pipeline has an internal corrosion threat that is extremely unlikely or how to adjust the operating parameters to reduce the internal corrosion threat. The framework for predicting internal corrosion threat due to residual hydrotest water and condensate intrusion of liquid water from side branches also was enhanced and computational tools also were developed for field implementation.AcknowledgmentsThis work was sponsored by PRCI (Hans Deeb Administrative Representative). The technical lead by Laurie Perry of Southern California Gas Company is recognized. 
Internal corrosion threat in dry natural gas pipelines is low because of the very low water content controlled under a tariff limit. However the threat may exist when liquid water is brought into the pipe by condensation hydrotesting or intrusion from lateral components. In an earlier project funded by Pipeline Research Council International (PRCI) probabilistic models and tools were developed to support guidelines to quantify the internal corrosion threat from condensation for a given dry natural gas pipeline operating conditions. The current project collected and analyzed more field data to enhance the probabilistic model especially in the conditions where the risk of internal corrosion is higher. The enhancement improved the practical tools and guidelines by attaining a confident prediction of the internal corrosion threat. With these tools an operator would be able to evaluate whether the current operation of its pipeline has an internal corrosion threat that is extremely unlikely or how to adjust the operating parameters to reduce the internal corrosion threat. The framework for predicting internal corrosion threat due to residual hydrotest water and condensate intrusion of liquid water from side branches also was enhanced and computational tools also were developed for field implementation.AcknowledgmentsThis work was sponsored by PRCI (Hans Deeb Administrative Representative). The technical lead by Laurie Perry of Southern California Gas Company is recognized. 
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