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51318-11308-Successful Application of Internal Corrosion Direct Assessment (ICDA) to determine the Integrity of of an Indian Offshore SPM Pipeline

Picture for Successful Application of Internal Corrosion Direct Assessment (ICDA) to determine the Integrity of of an Indian Offshore SPM Pipeline
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The study presents the internal corrosion direct assessment (ICDA) of a 48” x 18.7 km liquid petroleum pipeline carrying crude oil from a subsea pipeline end manifold (PLEM) to the onshore crude oil tank facilities.

Product Number: 51318-11308-SG
Author: Patrick J. Teevens / Sridhar Arumugam / Ashish Khera / Bidyut Baniah
Publication Date: 2018
Industries: Gas/Liquid Pipelines , Maritime
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The study presents the internal corrosion direct assessment (ICDA) of a 48” x 18.7 km liquid petroleum pipeline carrying crude oil from a subsea pipeline end manifold (PLEM) to the onshore crude oil tank facilities. The pipeline has handled over 100 different compositions of crude oil since commissioning of its operations in 2006. Three (3) hydrotests have been done for the offshore section (6.4 km) of the pipeline and the seawater used for the hydrotest was left stagnant in the pipeline for a cumulative period of 293 days since 2006. The pipeline had no internal corrosion monitoring program in place and had no baseline internal corrosion assessments done at the commencement of the ICDA in March 2015.

While performing ICDA, multiphase flow modeling was carried out to predict the pressure drop, temperature drop, inclination angle and flow regime variations along the pipeline. The most probable locations of water accumulation and solids deposition were predicted along the pipeline following Liquid Petroleum ICDA (SP0208-2008)1. The corrosion rates along the line were quantified using Multiphase Pipeline ICDA (SP0116-2016)2. The offshore section of the pipeline had higher predicted wall loss (%) in comparison to the onshore section of the pipeline. This was attributed to the prolonged exposure to of the offshore section of the pipeline to untreated seawater post hydrotest.

Detailed examinations at the selected sites based on the highest probability of internal corrosion showed good correlations between the predicted wall loss and the actual measured wall loss where at all of the assessment sites the predicted versus actual wall loss (%) were within the ±10% criteria as required by the MP-ICDA (SP0116-2016) standard practice.

Key words: internal corrosion, direct assessment, subsea pipeline, hydrotest

The study presents the internal corrosion direct assessment (ICDA) of a 48” x 18.7 km liquid petroleum pipeline carrying crude oil from a subsea pipeline end manifold (PLEM) to the onshore crude oil tank facilities. The pipeline has handled over 100 different compositions of crude oil since commissioning of its operations in 2006. Three (3) hydrotests have been done for the offshore section (6.4 km) of the pipeline and the seawater used for the hydrotest was left stagnant in the pipeline for a cumulative period of 293 days since 2006. The pipeline had no internal corrosion monitoring program in place and had no baseline internal corrosion assessments done at the commencement of the ICDA in March 2015.

While performing ICDA, multiphase flow modeling was carried out to predict the pressure drop, temperature drop, inclination angle and flow regime variations along the pipeline. The most probable locations of water accumulation and solids deposition were predicted along the pipeline following Liquid Petroleum ICDA (SP0208-2008)1. The corrosion rates along the line were quantified using Multiphase Pipeline ICDA (SP0116-2016)2. The offshore section of the pipeline had higher predicted wall loss (%) in comparison to the onshore section of the pipeline. This was attributed to the prolonged exposure to of the offshore section of the pipeline to untreated seawater post hydrotest.

Detailed examinations at the selected sites based on the highest probability of internal corrosion showed good correlations between the predicted wall loss and the actual measured wall loss where at all of the assessment sites the predicted versus actual wall loss (%) were within the ±10% criteria as required by the MP-ICDA (SP0116-2016) standard practice.

Key words: internal corrosion, direct assessment, subsea pipeline, hydrotest

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51318-11630-Internal Corrosion Direct Assessment of a Wet Gas Pipeline

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This work applied the Wet Gas-Internal Corrosion Direct Assessment (WG-ICDA) standard to assess the severity of internal corrosion of 2 segments along a pipeline used to transport wet gas from a gas mine.
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51316-7092-Internal Corrosion Direct Assessment For Offshore Pipelines

Product Number: 51316-7092-SG
ISBN: 7092 2016 CP
Author: Eugene Ogosi
Publication Date: 2016
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Inspection of offshore pipelines is essential to provide vital information required for integrity assessment to allow data driven engineering decisions to be made and prevent costly failures. This paper presents experience from applying Internal Corrosion Direct Assessment (ICDA) for offshore pipelines in the North Sea.
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51318-11300-Predicted and Actual Dig Outcome of Dry Gas Internal Corrosion Direct Assessment of Unpiggable Pipelines

Product Number: 51318-11300-SG
Author: C. Onuoha / S. McDonnell / E. Pozniak
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This paper illustrates how appropriate use of predictive flow models and pipeline inclination profiles, in conjunction with dew point analysis, improves the prediction of locations susceptible to internal corrosion.
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