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02091 Analysis of Corrosion Rates on a Gas Transmission Pipeline

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Product Number: 51300-02091-SG
ISBN: 02091 2002 CP
Author: Robert G. Worthingham, Louis L. Fenyvesi, Thomas B. Morrison, and Guy J. Desjardins
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Beginning in 1991, methods to determine corrosion rates from multiple in-line inspections of pipelines have been developed and successfully implemented on a large transmission pipeline system. In 2000, investigations were performed to understand the characteristics of corrosion rates on a particular 500 km long pipeline that had been inspected three times over an 8 year period. The object of the study was to determine the variability of corrosion rates along the pipeline. With that data, authors applied the distribution of corrosion rates observed on the pipeline with multiple inspections to other similar pipelines that had been inspected only once. The results of the analyses are of great benefit in determining the appropriate re-inspection interval when compared to other methods which use a single assumed corrosion rate.
Beginning in 1991, methods to determine corrosion rates from multiple in-line inspections of pipelines have been developed and successfully implemented on a large transmission pipeline system. In 2000, investigations were performed to understand the characteristics of corrosion rates on a particular 500 km long pipeline that had been inspected three times over an 8 year period. The object of the study was to determine the variability of corrosion rates along the pipeline. With that data, authors applied the distribution of corrosion rates observed on the pipeline with multiple inspections to other similar pipelines that had been inspected only once. The results of the analyses are of great benefit in determining the appropriate re-inspection interval when compared to other methods which use a single assumed corrosion rate.
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06442 POSSIBLE GLYCOL CORROSION IN NOMINALLY DRY GAS PIPELINES

Product Number: 51300-06442-SG
ISBN: 06442 2006 CP
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Pipeline quality gas is normally dried in Triethylene Glycol (TEG).  This paper explores how TEG vapor can exist in a pipeline in a similar manner to water, and possibly lead to corrosion. TEG vapor can condense at long distances down a gas pipeline as the line cools.
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This paper describes a research program that was conducted to provide estimates of internal pipeline corrosion rates in inaccessible (offshore) locations from analyses of gas and water samples taken in accessible (onshore) locations.
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51318-11630-Internal Corrosion Direct Assessment of a Wet Gas Pipeline

Product Number: 51318-11630-SG
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This work applied the Wet Gas-Internal Corrosion Direct Assessment (WG-ICDA) standard to assess the severity of internal corrosion of 2 segments along a pipeline used to transport wet gas from a gas mine.
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