Development of Tools to Estimate Actual Corrosion Growth Rates of Gas Pipelines

Song, Frank; Southwest Research Institute

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Development of Tools to Estimate Actual Corrosion Growth Rates of Gas Pipelines

2011-10-01
By Song, Frank

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English

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Creators:

Song, Frank
Corporate Creators:

Southwest Research Institute
Corporate Contributors:

United States. Dept. of Transportation. Pipeline and Hazardous Materials Safety Administration
Subject/TRT Terms:

[+]

Carbon Dioxide Coatings Corrosion Debonding Estimating Field Tests Gas Pipelines Guidelines Hydrogen Sulfide Laboratory Tests Maintenance And Preservation Oxygen Research Hub Validation
Publication/ Report Number:

20.14082
Resource Type:

Tech Report
Geographical Coverage:

United States
TRIS Online Accession Number:

01641056
Edition:

Final Report
Corporate Publisher:

Southwest Research Institute
Abstract:

Both external and internal corrosion of gas pipelines can pose threats to pipeline safety by thinning the pipe wall, leading to leaks or ruptures. To ensure the pipeline safety, it is important to know both pipeline internal and external corrosion rates. In an earlier Pipeline and Hazardous Materials Safety Administration (PHMSA)-funded project (DTRS56-04-T-0002 completed in 2006), models were developed to predict pipeline external and internal corrosion rates for natural gas pipelines. However, the external model did not consider the effect of coating permeability and the effect of the geometry of the coating disbondment. The internal corrosion model was unable to distinguish the different corroding conditions for wet and dry gas pipelines. The goal of this work is to expand the earlier modeling work and develop guidelines for pipeline operators to predict field corrosion growth rates through (1) Improving the existing external corrosion rate model of Southwest Research Institute (SwRI) to include the effect of CO₂ permeation from soil into a coating-disbonded region, and validate the model with laboratory and field data; (2) Developing a thin-film internal corrosion model to predict corrosion rates in dry gas pipelines due to gas quality upsets (e.g. water condensation), and validating the model using laboratory and field corrosion rate data; and (3) Improving the current existing internal corrosion rate model of SwRI for wet gas pipelines by including the effects of carbon dioxide (CO₂), hydrogen sulfide (H₂S), and oxygen (O₂), and validating the model using laboratory and field corrosion rate data.
Format:

PDF
Funding:

DTPH 56-08-T-000003
Collection(s):

PHMSA Collection US Transportation Collection
Main Document Checksum:

[+]

urn:sha256:2f59d281536fe3eedc3c88f800eac13ba4085d8d45d03b5a220fe5902dc8a7d5
Download URL:

https://rosap.ntl.bts.gov/view/dot/36474/dot_36474_DS1.pdf
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Development of Tools to Estimate Actual Corrosion Growth Rates of Gas Pipelines

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