Modeling the H2S contribution to internal corrosion rate of natural gas pipeline
Corrosion has been identified as a major cause of pipeline failure, which leads to grievous environmental degradation, hence, the need for predicting the integrity of the service life of the pipeline. This work develops a predictive model on corrosion rate for natural gas pipeline with H2S as corrod...
| Main Author: | |
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| Format: | Journal Article |
| Published: |
Taylor & Francis
2009
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| Online Access: | http://hdl.handle.net/20.500.11937/42949 |
| _version_ | 1848756556944900096 |
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| author | Obanijesu, Emmanuel |
| author_facet | Obanijesu, Emmanuel |
| author_sort | Obanijesu, Emmanuel |
| building | Curtin Institutional Repository |
| collection | Online Access |
| description | Corrosion has been identified as a major cause of pipeline failure, which leads to grievous environmental degradation, hence, the need for predicting the integrity of the service life of the pipeline. This work develops a predictive model on corrosion rate for natural gas pipeline with H2S as corroding agent. The model is based on the thermodynamic properties of the fluid and the developed rate is plotted against various operating conditions. The model shows that corrosion rate increases with temperature, fluid fugacity, wall shear stress, superficial velocity, and acidity. It is recommended that H2S should be removed as much as possible from the sour natural gas before its transportation through the pipe length. |
| first_indexed | 2025-11-14T09:14:05Z |
| format | Journal Article |
| id | curtin-20.500.11937-42949 |
| institution | Curtin University Malaysia |
| institution_category | Local University |
| last_indexed | 2025-11-14T09:14:05Z |
| publishDate | 2009 |
| publisher | Taylor & Francis |
| recordtype | eprints |
| repository_type | Digital Repository |
| spelling | curtin-20.500.11937-429492017-09-13T14:30:53Z Modeling the H2S contribution to internal corrosion rate of natural gas pipeline Obanijesu, Emmanuel Corrosion has been identified as a major cause of pipeline failure, which leads to grievous environmental degradation, hence, the need for predicting the integrity of the service life of the pipeline. This work develops a predictive model on corrosion rate for natural gas pipeline with H2S as corroding agent. The model is based on the thermodynamic properties of the fluid and the developed rate is plotted against various operating conditions. The model shows that corrosion rate increases with temperature, fluid fugacity, wall shear stress, superficial velocity, and acidity. It is recommended that H2S should be removed as much as possible from the sour natural gas before its transportation through the pipe length. 2009 Journal Article http://hdl.handle.net/20.500.11937/42949 10.1080/15567030701528408 Taylor & Francis restricted |
| spellingShingle | Obanijesu, Emmanuel Modeling the H2S contribution to internal corrosion rate of natural gas pipeline |
| title | Modeling the H2S contribution to internal corrosion rate of natural gas pipeline |
| title_full | Modeling the H2S contribution to internal corrosion rate of natural gas pipeline |
| title_fullStr | Modeling the H2S contribution to internal corrosion rate of natural gas pipeline |
| title_full_unstemmed | Modeling the H2S contribution to internal corrosion rate of natural gas pipeline |
| title_short | Modeling the H2S contribution to internal corrosion rate of natural gas pipeline |
| title_sort | modeling the h2s contribution to internal corrosion rate of natural gas pipeline |
| url | http://hdl.handle.net/20.500.11937/42949 |