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Classification Of Active And Passive Conditions Based On Different Relaxation Response For External Corrosion Coated Pipelines

Classification Of Active And Passive Conditions Based On Different Relaxation Response For External Corrosion Coated Pipelines
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External corrosion on buried pipelines can result in gradual and usually localized metal loss on the exterior surface of failure coating, resulting in reduction of the wall thickness of the metallic structure. Indirect technologies, such as DC basis (i.e. DCVG, CIPS) have been able to detect and pinpoint two conditions in the pipeline, intact and holiday (active surface or coating anomaly) with good confidence. Classic DC methodologies monitor and characterize the state of the coating and effectiveness of cathodic protection by using transfer function principle (i.e. resistance). The formation of an electrochemical cell, such as buried coated pipeline with cathodic protection (steel in electrolyte) is formed at macro scale conditions [1-2]. The expected damage evolution of the coated pipeline includes the electrolyte (soil+water) uptake within the coating

Product Number: 51322-18052-SG
Author: H. Castaneda, Lin Chen, Hui Wang, Sreelakshmi Sreeharan
Publication Date: 2022
Industries: Corrosion Monitoring and Control , Coatings
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$20.00
$20.00

The energy transportation network of the United States consists of over 2.5 million miles of buried pipelines. It is of prime importance the integrity of the metallic assets due to degradation in soil conditions because of their constant exposure to the aggressive, dynamic, and heterogeneous environment. This degradation process, involves a sequence of process starting with the coating damages/failures and the following electrochemical reactions. External corrosion can result in gradual and usually localized metal loss on the exterior surface of failure coating, resulting in reduction of the wall thickness of the metallic asset. Indirect technologies, such as DC basis have been able to detect and pinpoint two conditions in the pipeline, intact and holiday (active surface or coating anomaly) with good confidence. In this work we consider different levels of corrosion surface severity when a coating holiday (anomaly) exists. Different X52 metallic samples were characterized by using DC polarization and AC impedance to distinguish the differences in terms of capacitive and surface corrosion severity when the metallic samples get a coating failure.

The energy transportation network of the United States consists of over 2.5 million miles of buried pipelines. It is of prime importance the integrity of the metallic assets due to degradation in soil conditions because of their constant exposure to the aggressive, dynamic, and heterogeneous environment. This degradation process, involves a sequence of process starting with the coating damages/failures and the following electrochemical reactions. External corrosion can result in gradual and usually localized metal loss on the exterior surface of failure coating, resulting in reduction of the wall thickness of the metallic asset. Indirect technologies, such as DC basis have been able to detect and pinpoint two conditions in the pipeline, intact and holiday (active surface or coating anomaly) with good confidence. In this work we consider different levels of corrosion surface severity when a coating holiday (anomaly) exists. Different X52 metallic samples were characterized by using DC polarization and AC impedance to distinguish the differences in terms of capacitive and surface corrosion severity when the metallic samples get a coating failure.

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Cathodic Protection Of Mooring Chain In Offshore Environment

Product Number: 51322-17722-SG
Author: Faisal Shahzad, Nils Olav Digre, Kristian Varne
Publication Date: 2022
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Corrosion in Mooring systems for permanently moored floating production units has been identified as a problem area by authorities as well as industry. A Joint Industry Project (JIP) initiated by the Bureau of Safety and Environmental Enforcement (BSEE) with participation from major global oil and gas operators as well as equipment suppliers was established in 2014 to review the problem area. 1 Studies performed as a part of this program have shown that especially mooring chains located in tropical waters have shown signs of rapid corrosion, both general and localized with corrosion rates significantly larger than those specified in design standards. Increased corrosion allowance, as well as increased inspection requirements, have been recommended and corrosion has been reported as the leading cause for pre-emptive replacement of mooring.
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