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dc.contributor.authorObanijesu, Emmanuel
dc.date.accessioned2017-01-30T15:03:24Z
dc.date.available2017-01-30T15:03:24Z
dc.date.created2016-09-12T08:36:47Z
dc.date.issued2009
dc.identifier.citationObanijesu, E. 2009. Modeling the H2S contribution to internal corrosion rate of natural gas pipeline. Energy Sources Part A-Recovery Utilization and Environmental Effects. 31 (4): pp. 348-363.
dc.identifier.urihttp://hdl.handle.net/20.500.11937/42949
dc.identifier.doi10.1080/15567030701528408
dc.description.abstract

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.

dc.publisherTaylor & Francis
dc.titleModeling the H2S contribution to internal corrosion rate of natural gas pipeline
dc.typeJournal Article
dcterms.source.volume31
dcterms.source.number4
dcterms.source.startPage348
dcterms.source.endPage363
dcterms.source.issn1556-7036
dcterms.source.titleEnergy Sources Part A-Recovery Utilization and Environmental Effects
curtin.departmentDepartment of Chemical Engineering
curtin.accessStatusFulltext not available


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