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Impact Of Maintenance Activities On Future Integrity Of Transmission Pipelines

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Transmission pipeline companies utilize successive ILI tool runs to identify, size, and determine the corrosion growth rate (CGR) of pipeline features that may be detrimental to the operation of the pipeline [1, 2]. The importance of back-to-back ILI tool runs in monitoring and maintaining the safe operation of a pipeline is further supported by the methodologies’ incorporation by US regulators for high consequence areas. The calculated CGR from the ILI tool runs is used to determine maintenance digs required to mitigate the identified features prior to the next scheduled re-inspection interval.

Product Number: 51322-17504-SG
Author: Haralampos Tsaprailis, Jiajun Liang, Mike Hill
Publication Date: 2022
Industries: Corrosion Monitoring and Control , Coatings and Linings , Coatings
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Transmission pipeline operators regularly inspect their assets using in-line inspection (ILI) tools to monitor for potential internal and external threats to the system. When these tools identify features that meet excavation criteria, the operators will complete mitigation activities to reduce or remove the threat. Typically, these mitigation activities include excavation of the pipeline, removal of the coating, and non-destructive examination at the targeted feature. Upon completion of the maintenance activities, the pipeline is then re-coated and the backfill restored.

Transmission pipeline operators regularly inspect their assets using in-line inspection (ILI) tools to monitor for potential internal and external threats to the system. When these tools identify features that meet excavation criteria, the operators will complete mitigation activities to reduce or remove the threat. Typically, these mitigation activities include excavation of the pipeline, removal of the coating, and non-destructive examination at the targeted feature. Upon completion of the maintenance activities, the pipeline is then re-coated and the backfill restored.

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Product Number: 51322-17629-SG
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Inline cathodic protection current mapping is a unique method of assessing a pipeline’s cathodic protection. This is accomplished by measuring the actual current received by the pipeline continuously along the entire pipeline length. Unlike pipe to soil potentials, which can have a great deal of error in them due to forces often beyond our control, the CP mapping tool uses the physical properties of the pipe itself to measure the CP current. The pipe is a very stable part of the circuit, unlike the soil surrounding it.
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Product Number: 51322-17666-SG
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Publication Date: 2022
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In this paper, the CP current distribution with changing resistivities and the area of influence required to meet effective CP criteria, is studied. The results indicate that the tank pad electrolyte resistivity plays a significant role in achieving uniform CP current distribution. The paper also explores the use of Vapor Corrosion Inhibitor (VCI) and its effect on electrolyte resistivity and the resulting CP current distribution.
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NACE MR0175 / ISO 15156 document part 2 provides material requirements for selecting cast irons and low-alloy steels for sour environments.1 Figure 1 is reproduced from this standard and describes different regions of environmental severity for Sulfide Stress Cracking (SSC): service in region 0 being the least susceptible to cracking, even for very sensitive materials, and region 3 being the worst.
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