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03178 EXPERIENCES IN ASSESSING INTERNAL CORROSION FOR MULTIPHASE FLOW PIPELINES

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Product Number: 51300-03178-SG
ISBN: 03178 2003 CP
Author: Carlos A. Palacios T., Danielli Quintero
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Multiphase flow pipelines can be exposed to very high corrosion rates due to the presence of gas, water, oil and sand. In the pipeline system described here, the fluid is composed of crude oil, a continuous gas phase containing CO2/H2S, high water cuts and some sand. This combination and the fact that many of the pipelines run along hilly terrains, develop different flow patterns along the pipeline. Many of these factors combined, represent a real challenge when determining the corrosion potential and corrosion control strategies to maintain the pipeline technical integrity. Corrosion rates, were determined by a theoretical corrosion model in combination with: two-phase flow modeling techniques, in-line monitoring, and ultrasonic inspections. With this information, fitness-for-purpose was determined and some sections of the pipeline replaced. Removed pipeline was inspected and their wall loss compared with determined corrosion rates and UT measurements were rechecked. It was also determined that the sections with higher corrosion rates, having a high number of leaks and; therefore, replaced, were sections having slug type flow. Based on this assessment, the pipeline technical integrity strategy was implemented: Pigging, Inspection frequency, corrosion monitoring, and corrosion control strategies. Key Words: Risk based analysis, slug flow corrosion, and internal corrosion assessment.
Multiphase flow pipelines can be exposed to very high corrosion rates due to the presence of gas, water, oil and sand. In the pipeline system described here, the fluid is composed of crude oil, a continuous gas phase containing CO2/H2S, high water cuts and some sand. This combination and the fact that many of the pipelines run along hilly terrains, develop different flow patterns along the pipeline. Many of these factors combined, represent a real challenge when determining the corrosion potential and corrosion control strategies to maintain the pipeline technical integrity. Corrosion rates, were determined by a theoretical corrosion model in combination with: two-phase flow modeling techniques, in-line monitoring, and ultrasonic inspections. With this information, fitness-for-purpose was determined and some sections of the pipeline replaced. Removed pipeline was inspected and their wall loss compared with determined corrosion rates and UT measurements were rechecked. It was also determined that the sections with higher corrosion rates, having a high number of leaks and; therefore, replaced, were sections having slug type flow. Based on this assessment, the pipeline technical integrity strategy was implemented: Pigging, Inspection frequency, corrosion monitoring, and corrosion control strategies. Key Words: Risk based analysis, slug flow corrosion, and internal corrosion assessment.
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