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07169 Internal Corrosion Direct Assessment Methodology for Liquid Petroleum Pipelines

Picture for 07169 Internal Corrosion Direct Assessment Methodology for Liquid Petroleum Pipelines
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Product Number: 51300-07169-SG
ISBN: 07169 2007 CP
Author: Oliver C. Moghissi, Conchita Mendez, Wei Sun, Jose R. Vera, and Trevor Place
Publication Date: 2007
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$20.00
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A proposed method for Liquid Petroleum Pipeline Internal Corrosion Direct Assessment (LP-ICDA) has been developed that is consistent with the general principles of other Direct Assessment (DA) methods. The scope of LP-ICDA complements those of dry gas ICDA (DG-ICDA) and wet gas ICDA (WGICDA). LP-ICDA (as with other DA methods) is intended to serve as an integrity verification tool, playing the same role within pipeline integrity management as in-line inspection (ILI) and hydrotesting (either as a replacement or as a complement). The method relies on 1) identifying a mechanism for corrosion susceptibility, 2) detecting a property associated with this mechanism through an indirect measurement, 3) performing a direct observation of the pipe (e.g., by excavation), and 4) correcting for any discrepancies between the predictions and observations. The underlying basis of the proposed approach is simple; corrosion in liquid petroleum pipelines is most likely where water and/or solids accumulate. Secondary factors affecting the distribution of corrosion between locations of water and solids accumulation are also considered.
A proposed method for Liquid Petroleum Pipeline Internal Corrosion Direct Assessment (LP-ICDA) has been developed that is consistent with the general principles of other Direct Assessment (DA) methods. The scope of LP-ICDA complements those of dry gas ICDA (DG-ICDA) and wet gas ICDA (WGICDA). LP-ICDA (as with other DA methods) is intended to serve as an integrity verification tool, playing the same role within pipeline integrity management as in-line inspection (ILI) and hydrotesting (either as a replacement or as a complement). The method relies on 1) identifying a mechanism for corrosion susceptibility, 2) detecting a property associated with this mechanism through an indirect measurement, 3) performing a direct observation of the pipe (e.g., by excavation), and 4) correcting for any discrepancies between the predictions and observations. The underlying basis of the proposed approach is simple; corrosion in liquid petroleum pipelines is most likely where water and/or solids accumulate. Secondary factors affecting the distribution of corrosion between locations of water and solids accumulation are also considered.
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