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51318-11300-Predicted and Actual Dig Outcome of Dry Gas Internal Corrosion Direct Assessment of Unpiggable Pipelines

Picture for Predicted and Actual Dig Outcome of Dry Gas Internal Corrosion Direct Assessment of Unpiggable Pipelines
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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.

Product Number: 51318-11300-SG
Author: C. Onuoha / S. McDonnell / E. Pozniak
Publication Date: 2018
Industry: Pipelines, Tanks, and Underground Systems
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$20.00
$20.00

Dry Gas Internal Corrosion Direct Assessment (DG-ICDA) specified in NACE SP0206-2006 was developed in an attempt to proactively prevent and predict locations susceptible to internal corrosion in natural gas pipelines normally transporting dry gas. The DG-ICDA inspection program is used for pipelines that are difficult or impossible to pig or inspect with inline inspection (ILI), as well as piggable pipelines, where it can be used as a supplement to ILI. This inspection program is suitable for natural gas pipelines that normally carry dry gas, but may suffer from infrequent short-term upsets of condensation of moisture as a result of a shift in process variables such as pressure and temperature.

Research and industry experience have shown that predicting water accumulation points using water condensation is paramount to the success of DG-ICDA in unpiggable pipelines. As liquid water is necessary for internal corrosion to initiate, determining the existence of water in a pipeline would be vital to the success of any DG-ICDA inspection program.

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. This paper also discuss methodologies that contribute to ensuring that the most susceptible locations for internal corrosion are accurately pinpointed and addressed. Several case studies from previous DG-ICDA digs are presented to compare the predicted and actual dig results.

Key words: Dry Gas Internal Corrosion Direct Assessment, Predictive Flow Modeling, Critical Angle, Inclination Angle, Dew Point, Detailed Examination, DG-ICDA digs.

Dry Gas Internal Corrosion Direct Assessment (DG-ICDA) specified in NACE SP0206-2006 was developed in an attempt to proactively prevent and predict locations susceptible to internal corrosion in natural gas pipelines normally transporting dry gas. The DG-ICDA inspection program is used for pipelines that are difficult or impossible to pig or inspect with inline inspection (ILI), as well as piggable pipelines, where it can be used as a supplement to ILI. This inspection program is suitable for natural gas pipelines that normally carry dry gas, but may suffer from infrequent short-term upsets of condensation of moisture as a result of a shift in process variables such as pressure and temperature.

Research and industry experience have shown that predicting water accumulation points using water condensation is paramount to the success of DG-ICDA in unpiggable pipelines. As liquid water is necessary for internal corrosion to initiate, determining the existence of water in a pipeline would be vital to the success of any DG-ICDA inspection program.

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. This paper also discuss methodologies that contribute to ensuring that the most susceptible locations for internal corrosion are accurately pinpointed and addressed. Several case studies from previous DG-ICDA digs are presented to compare the predicted and actual dig results.

Key words: Dry Gas Internal Corrosion Direct Assessment, Predictive Flow Modeling, Critical Angle, Inclination Angle, Dew Point, Detailed Examination, DG-ICDA digs.

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

Product Number: 51318-11630-SG
Author: Xihua S. He / Debashis Basu / and Osvaldo Pensado / Jianyun Mei / Bibo Zhang / Hongbo Wu / Yongzhao Fan / Deqiang Cai / Yang Li
Publication Date: 2018
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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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51318-11308-Successful Application of Internal Corrosion Direct Assessment (ICDA) to determine the Integrity of of an Indian Offshore SPM Pipeline

Product Number: 51318-11308-SG
Author: Patrick J. Teevens / Sridhar Arumugam / Ashish Khera / Bidyut Baniah
Publication Date: 2018
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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.
Picture for Validation of Internal Corrosion Threat Guidelines for Dry Natural Gas Pipelines
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51316-7259-Validation of Internal Corrosion Threat Guidelines for Dry Natural Gas Pipelines

Product Number: 51316-7259-SG
ISBN: 7259 2016 CP
Author: Xihua He
Publication Date: 2016
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This study collected and analyzed field data to validate the probabilistic model developed previously for predicting internal corrosion threats resulting from condensed water from nominally dry natural gas.
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