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Development Of A New Top-Of-Line Corrosion Model For Sweet Wet Gas Pipelines

Picture for Development Of A New Top-Of-Line Corrosion Model For Sweet Wet Gas Pipelines
Available for download
Product Number: 51321-16812-SG
Author: Y. Zheng; J. Sonke; W. M. Bos
Publication Date: 2021
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$20.00
$20.00

Top-of-line corrosion (TLC) is known as one of the main corrosion threats in wet gas pipelines operating
in stratified flow conditions. Using a corrosion model is one of the key tools to identify and quantify the
threat and to identify the potential need for mitigation and control of this risk.
This paper will describe a new TLC model that can be used to assess the TLC risk for sweet wet gas
pipelines. This model is based on the mechanistic understanding from the latest literature and knowledge
generated in a JIP (Joint Industry Project with Ohio University). The new model addresses the following
relevant physicochemical phenomena:
The latest electrochemical CO corrosion model for the bare steel corrosion rate, including the
effect of organic acids as a pH buffering agent.
The Fe² flux balance
The condensation rate, condensation regime and condensing droplet size
FeCO3 formation and its effect on the corrosion rate
Incomplete substrate coverage during low condensation rates
Three sources or sinks in the Fe² flux balance equation are distinguished:
Fe² formation by corrosion
Fe² removal by FeCO3 precipitation
Fe² transportation by condensed water film convection
This model has been implemented into our in-house corrosion prediction software Hydrocor (HC). The
performance has been verified with a database compiled from the literature. The new TLC Model shows
a very good agreement with both experimental and field data on top of line corrosion.

Top-of-line corrosion (TLC) is known as one of the main corrosion threats in wet gas pipelines operating
in stratified flow conditions. Using a corrosion model is one of the key tools to identify and quantify the
threat and to identify the potential need for mitigation and control of this risk.
This paper will describe a new TLC model that can be used to assess the TLC risk for sweet wet gas
pipelines. This model is based on the mechanistic understanding from the latest literature and knowledge
generated in a JIP (Joint Industry Project with Ohio University). The new model addresses the following
relevant physicochemical phenomena:
The latest electrochemical CO corrosion model for the bare steel corrosion rate, including the
effect of organic acids as a pH buffering agent.
The Fe² flux balance
The condensation rate, condensation regime and condensing droplet size
FeCO3 formation and its effect on the corrosion rate
Incomplete substrate coverage during low condensation rates
Three sources or sinks in the Fe² flux balance equation are distinguished:
Fe² formation by corrosion
Fe² removal by FeCO3 precipitation
Fe² transportation by condensed water film convection
This model has been implemented into our in-house corrosion prediction software Hydrocor (HC). The
performance has been verified with a database compiled from the literature. The new TLC Model shows
a very good agreement with both experimental and field data on top of line corrosion.

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TOL corrosion is reported to occur in large diameter wet gas pipeline in stratified flow conditions
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The hydrocarbon exploration in the ocean and deep sea was started as early as early as the 1850s, when the first drilling was carried out in California, USA. Other early oil explorations activities were later recorded in Pakistan (1886), Peru (1869), India (1890) and Dutch East Indies (1893). The development of an offshore industry is directly related to the development of subsea pipelines as well. As the industry expands towards deeper waters, the pipelines are required to have better materials, designs, operation practices and maintenance strategies to withstand the challenging environments. These pipelines are exposed to elevated temperatures, high pressures, and corrosive fluids.
Picture for 09286 Top of the Line Corrosion Control by Chemical Treatment
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