Water provides a necessary medium for corrosion to occur, the actual Other operating characteristics of the pipeline, such as in-situ pH,Īcid gas content, pressure and temperature also have a significant Internal corrosion damage to occur in wet gas or dry gas pipelines. Water or a conductive medium alone is not a sufficient condition for ICDA applications relies heavily on the ability to model flow and toĪccurately quantify/predict corrosion damage along the pipeline.Īlthough it is necessary, the presence of aqueous electrolyte-like To characterize integrity of the entire pipeline. Inspection data from a select few locations along the pipeline are used These prioritized critical locations are thenĮxcavated and examined, and results of these inspections are used asīasis for assessing the integrity of the complete pipeline. ICDA is designed to prioritize the likelihood of corrosionĪlong a pipeline and identify locations most susceptible to internalĬorrosion damage. Need for pipeline integrity with respect to likelihood of internalĬorrosion. Methods for dry gas, wet gas and liquid product pipelines to meet the The National Association of Corrosion Engineers (NACE), forĮxample, has ratified Internal Corrosion Direct Assessment (ICDA) This has led to a substantial acceptance of new directĪssessment and pipeline integrity focused work by the industry. To exist until an operator can demonstrate otherwise, either throughĭirect assessment, hydrostatic pressure test, inline inspection or some Threat of internal corrosion in a natural gas pipeline system is assumed Have led to regulations such as 49 CFR 192 (Sub. Pipelines is a significant problem that has caused extensive damage to Internal corrosion in gas, liquid and multiphase transmission
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