TransCanada was faced with a significant challenge to inspect a 941 km NPS 48 pipeline. The options for the inline inspection (ILI) were multiple segments which would cause an increased cost with new pigging facilities required and a delay to the ILI schedule or attempt to pig the longest natural gas pipeline section in North America. The extraordinary proposal would require a massive 48″ combination Magnetic Flux Leakage (MFL) tool to traverse a high-speed gas pipeline 941km from Burstall, Saskatchewan to Ile des Chenes, Manitoba, Canada. Given the alternative of the installation of 3 additional launcher and receiver stations and the risk to overall project schedule from extended inspection operations, TransCanada took the bold decision to perform an MFL inspection in a single pass. However, as expected, this option created a new set of challenges to guarantee first run success in one of the harshest environments for an ILI tool and in a line where the cleanliness condition was unknown. This last factor, was a critical concern as the volumes of debris that could be collected with the highly aggressive MFL tool brushes, could easily and very quickly have led to very significant debris build up during inspection that at best would likely cause degraded data leading to an unwanted re-run and at worst the possibility of a stuck pig and subsequent retrieval program. From a project perspective either occurance was considered to be mission critical — if either occurred there was no easy solution to collecting the much needed condition data of the pipeline. In July 2017, a successful VECTRA HD GEMINI inspection was completed. This paper discusses the main program risks, mitigation steps taken over and above a standard ILI run. Key considerations and actions taken relating to additional engineering and tool modifications to various components of the inspection vehicle itself will be discussed. Lastly, insight will be given into an extensive smart cleaning program developed with the ILI vendor, using a combination of mechanical cleaning associated and debris level assessment, specifically designed and tailored for the project to ensure that the pipeline was both ready for ILI and that cleaning had reached optimum for ILI so that full, high quality MFL data would be collected the first time.
TransCanada公司在检查一条941公里长的NPS 48管道时面临着重大挑战。直管检查(ILI)的选择是多段的，这将增加成本，需要新的清管设施，并推迟ILI计划，或者尝试清管北美最长的天然气管道段。这项特别的提案将需要一个巨大的48″组合漏磁(MFL)工具来穿越一条高速天然气管道，从萨斯喀彻温省的Burstall到加拿大马尼托巴省的Ile des Chenes，全长941公里。考虑到额外安装3个发射和接收站的可能性，以及延长检查作业对整个项目进度的风险，TransCanada公司做出了一个大胆的决定，即一次完成MFL检查。然而，正如预期的那样，该选择带来了一系列新的挑战，以确保在ILI工具最恶劣的环境之一以及清洁度条件未知的生产线中首次成功运行。最后一个因素是一个关键的问题，因为高强度的MFL工具刷可以收集大量的碎屑，在检查过程中很容易、很快就会导致大量碎屑堆积，最好的情况是可能导致数据退化，导致不必要的重新下入，最坏的情况是可能卡住清管器，导致后续的回收程序。从项目的角度来看，任何一种情况都被认为是关键任务，如果发生任何一种情况，都没有简单的解决方案来收集急需的管道状态数据。2017年7月，VECTRA HD GEMINI成功完成了一次检查。本文讨论了在标准ILI运行之上所采取的主要规划风险和缓解措施。将讨论与检查车辆本身各部件的额外工程和工具修改相关的关键考虑因素和采取的行动。最后，将深入了解与ILI供应商共同开发的广泛智能清洁计划，该计划结合了机械清洁和碎屑水平评估，专门为该项目设计和定制，以确保管道既为ILI做好了准备，又达到了ILI的最佳清洁水平，以便第一次收集到完整、高质量的MFL数据。
{"title":"Achieving North American Record for Longest Intelligent Inspection of a Natural Gas Pipeline","authors":"S. Epur, Aaron Schartner, F. Sander","doi":"10.1115/IPC2018-78601","DOIUrl":"https://doi.org/10.1115/IPC2018-78601","url":null,"abstract":"TransCanada was faced with a significant challenge to inspect a 941 km NPS 48 pipeline. The options for the inline inspection (ILI) were multiple segments which would cause an increased cost with new pigging facilities required and a delay to the ILI schedule or attempt to pig the longest natural gas pipeline section in North America. The extraordinary proposal would require a massive 48″ combination Magnetic Flux Leakage (MFL) tool to traverse a high-speed gas pipeline 941km from Burstall, Saskatchewan to Ile des Chenes, Manitoba, Canada. Given the alternative of the installation of 3 additional launcher and receiver stations and the risk to overall project schedule from extended inspection operations, TransCanada took the bold decision to perform an MFL inspection in a single pass. However, as expected, this option created a new set of challenges to guarantee first run success in one of the harshest environments for an ILI tool and in a line where the cleanliness condition was unknown. This last factor, was a critical concern as the volumes of debris that could be collected with the highly aggressive MFL tool brushes, could easily and very quickly have led to very significant debris build up during inspection that at best would likely cause degraded data leading to an unwanted re-run and at worst the possibility of a stuck pig and subsequent retrieval program. From a project perspective either occurance was considered to be mission critical — if either occurred there was no easy solution to collecting the much needed condition data of the pipeline. In July 2017, a successful VECTRA HD GEMINI inspection was completed. This paper discusses the main program risks, mitigation steps taken over and above a standard ILI run. Key considerations and actions taken relating to additional engineering and tool modifications to various components of the inspection vehicle itself will be discussed. Lastly, insight will be given into an extensive smart cleaning program developed with the ILI vendor, using a combination of mechanical cleaning associated and debris level assessment, specifically designed and tailored for the project to ensure that the pipeline was both ready for ILI and that cleaning had reached optimum for ILI so that full, high quality MFL data would be collected the first time.","PeriodicalId":273758,"journal":{"name":"Volume 1: Pipeline and Facilities Integrity","volume":"35 1","pages":"0"},"PeriodicalIF":0.0,"publicationDate":"2018-09-24","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"125051358","PeriodicalName":null,"FirstCategoryId":null,"ListUrlMain":null,"RegionNum":0,"RegionCategory":"","ArticlePicture":[],"TitleCN":null,"AbstractTextCN":null,"PMCID":"","EPubDate":null,"PubModel":null,"JCR":null,"JCRName":null,"Score":null,"Total":0}
Spirally welded pipelines can make up significant portions of operator transmission systems, and may contain manufacturing anomalies that are susceptible to fatigue growth. Modifications to inputs of crack assessment models, such as CorLAS®, are required to account for the angle these cracks make with respect to the longitudinal pipe axis, given that these crack assessment models were developed for longitudinally orientated cracks. Two such modifications were investigated and are discussed in this paper. One approach considered the normal stress component perpendicular to the angled crack, for which a stress transformation calculator was developed. Another approach, adapted from API 579 and BS7910 standards, used an effective crack length calculated as the longitudinal projection of the full length of an angled crack. Failure pressures calculated using these approaches were compared to validated finite element (FE) results. For both modifications, the pressure capacity increased for angled cracks versus longitudinal cracks. The transformed normal stress approach resulted in non-conservative failure pressure predictions with respect to the FE models, whereas the modified crack length approach was conservative. Additionally, the extended finite element method (XFEM) was used to investigate the propagation behavior of angled cracks. It was found that the general tendency was for propagation parallel to the longitudinal pipe axis; however, when considering weld residual stresses, the crack propagation would be directed toward the direction of the spiral seam.
{"title":"Assessment of Pipeline Spiral Weld Cracks Subjected to Internal Pressure","authors":"Mark A. C. Neuert, T. Dessein, M. Sen","doi":"10.1115/IPC2018-78293","DOIUrl":"https://doi.org/10.1115/IPC2018-78293","url":null,"abstract":"Spirally welded pipelines can make up significant portions of operator transmission systems, and may contain manufacturing anomalies that are susceptible to fatigue growth. Modifications to inputs of crack assessment models, such as CorLAS®, are required to account for the angle these cracks make with respect to the longitudinal pipe axis, given that these crack assessment models were developed for longitudinally orientated cracks. Two such modifications were investigated and are discussed in this paper.\u0000 One approach considered the normal stress component perpendicular to the angled crack, for which a stress transformation calculator was developed. Another approach, adapted from API 579 and BS7910 standards, used an effective crack length calculated as the longitudinal projection of the full length of an angled crack.\u0000 Failure pressures calculated using these approaches were compared to validated finite element (FE) results. For both modifications, the pressure capacity increased for angled cracks versus longitudinal cracks. The transformed normal stress approach resulted in non-conservative failure pressure predictions with respect to the FE models, whereas the modified crack length approach was conservative.\u0000 Additionally, the extended finite element method (XFEM) was used to investigate the propagation behavior of angled cracks. It was found that the general tendency was for propagation parallel to the longitudinal pipe axis; however, when considering weld residual stresses, the crack propagation would be directed toward the direction of the spiral seam.","PeriodicalId":273758,"journal":{"name":"Volume 1: Pipeline and Facilities Integrity","volume":"79 1","pages":"0"},"PeriodicalIF":0.0,"publicationDate":"2018-09-24","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"121059914","PeriodicalName":null,"FirstCategoryId":null,"ListUrlMain":null,"RegionNum":0,"RegionCategory":"","ArticlePicture":[],"TitleCN":null,"AbstractTextCN":null,"PMCID":"","EPubDate":null,"PubModel":null,"JCR":null,"JCRName":null,"Score":null,"Total":0}
Tao Zhang, Xinhua Wang, Yingchun Chen, Z. Ullah, Yizhen Zhao
Non-contact geomagnetic anomaly detection, as one of passive non-destructive testing (NDT) techniques, can be used to locate pipeline defects, while its accuracy is affected by random noise and detection orientation. In order to extract effective geomagnetic anomaly signals of pipeline defects, a method based on empirical mode decomposition (EMD) and magnetic gradient tensor was studied. In order to filter random noise, EMD was performed to self-adaptively decompose magnetic field signals into a series of intrinsic mode functions (IMFs), and then Hurst exponent was implemented to exclude false modes; The calculation method of magnetic gradient tensor modulus (MGTM) was proposed to obtain precise defect locations according to tensor symmetry; Subsequently, the remote pipeline defect model was built based on the magnetic dipole theory, and the relationship between detection orientation and MGTM was discussed. The experimental results showed that the proposed method could realize high precision and reliable non-contact geomagnetic localization of pipeline defects.
{"title":"Non-Contact Geomagnetic Localization of Pipeline Defects Using Empirical Mode Decomposition and Magnetic Gradient Tensor","authors":"Tao Zhang, Xinhua Wang, Yingchun Chen, Z. Ullah, Yizhen Zhao","doi":"10.1115/IPC2018-78258","DOIUrl":"https://doi.org/10.1115/IPC2018-78258","url":null,"abstract":"Non-contact geomagnetic anomaly detection, as one of passive non-destructive testing (NDT) techniques, can be used to locate pipeline defects, while its accuracy is affected by random noise and detection orientation. In order to extract effective geomagnetic anomaly signals of pipeline defects, a method based on empirical mode decomposition (EMD) and magnetic gradient tensor was studied. In order to filter random noise, EMD was performed to self-adaptively decompose magnetic field signals into a series of intrinsic mode functions (IMFs), and then Hurst exponent was implemented to exclude false modes; The calculation method of magnetic gradient tensor modulus (MGTM) was proposed to obtain precise defect locations according to tensor symmetry; Subsequently, the remote pipeline defect model was built based on the magnetic dipole theory, and the relationship between detection orientation and MGTM was discussed. The experimental results showed that the proposed method could realize high precision and reliable non-contact geomagnetic localization of pipeline defects.","PeriodicalId":273758,"journal":{"name":"Volume 1: Pipeline and Facilities Integrity","volume":"24 1","pages":"0"},"PeriodicalIF":0.0,"publicationDate":"2018-09-24","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"126441341","PeriodicalName":null,"FirstCategoryId":null,"ListUrlMain":null,"RegionNum":0,"RegionCategory":"","ArticlePicture":[],"TitleCN":null,"AbstractTextCN":null,"PMCID":"","EPubDate":null,"PubModel":null,"JCR":null,"JCRName":null,"Score":null,"Total":0}
K. Ralston, B. Padgett, D. Norfleet, Liu Cao, B. Delanty, Mark B. Klages, J. Beavers, T. J. Prewitt
A comprehensive metallurgical investigation of multiple, externally-initiated, in-service leaks on an above-ground, oil emulsion (multiphase) pipeline concluded that the crack-initiating mechanism was stress corrosion cracking (SCC). A technical root cause analysis (RCA) was performed, utilizing faults trees, to evaluate the potential contributors to the SCC from the time of construction through the identification of the first in-service leak. This paper outlines the RCA findings and current understating of the primary contributors given that SCC on above-ground, insulated carbon steel pipelines has not previously been reported.
{"title":"Root Cause Analysis of an Above-Ground Pipeline With Stress Corrosion Cracking","authors":"K. Ralston, B. Padgett, D. Norfleet, Liu Cao, B. Delanty, Mark B. Klages, J. Beavers, T. J. Prewitt","doi":"10.1115/IPC2018-78544","DOIUrl":"https://doi.org/10.1115/IPC2018-78544","url":null,"abstract":"A comprehensive metallurgical investigation of multiple, externally-initiated, in-service leaks on an above-ground, oil emulsion (multiphase) pipeline concluded that the crack-initiating mechanism was stress corrosion cracking (SCC). A technical root cause analysis (RCA) was performed, utilizing faults trees, to evaluate the potential contributors to the SCC from the time of construction through the identification of the first in-service leak. This paper outlines the RCA findings and current understating of the primary contributors given that SCC on above-ground, insulated carbon steel pipelines has not previously been reported.","PeriodicalId":273758,"journal":{"name":"Volume 1: Pipeline and Facilities Integrity","volume":"38 1","pages":"0"},"PeriodicalIF":0.0,"publicationDate":"2018-09-24","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"126911713","PeriodicalName":null,"FirstCategoryId":null,"ListUrlMain":null,"RegionNum":0,"RegionCategory":"","ArticlePicture":[],"TitleCN":null,"AbstractTextCN":null,"PMCID":"","EPubDate":null,"PubModel":null,"JCR":null,"JCRName":null,"Score":null,"Total":0}
Chike Okoloekwe, Muntaseer Kainat, Doug Langer, S. Hassanien, S. Adeeb
Pipeline integrity management commonly leverages nondestructive inspection of pipeline defects via inline inspection (ILI) and assessment of the resultant data. Key parameters for dent analysis include the feature geometry measured by caliper tools and the presence/severity of any interacting features (such as cracks or areas of corrosion) which can be measured with a variety of technologies (such as magnetic flux leakage or ultrasonic tools). Dent profile measurements can be especially susceptible to noise due to the measurement techniques employed, signal quality, and overall tool performance. Analytical methods for strain assessment of dents can employ curve/surface fitting techniques to estimate the curvature and calculate the strain of the dent based on the fitted curve/surface. Noise in the measured profile can result in local areas of high perceived strain, which could lead to misinterpretation of a dent’s true severity, especially when using automated or purely analytical assessment methods. A deterministic strain-based approach for evaluating the severity of dented pipelines has been presented previously which leverages multi-dimensional B-spline functions to more accurately apply the non-mandatory ASME B31.8 equations for dent assessment. The approach presented previously requires relatively smooth dent profile information to minimize the effects of signal noise. While low pass filters can effectively eliminate noise in the signal, they may also lead to loss of accuracy (e.g. excessive smoothing can reduce the depth and sharpness of a measured dent’s profile). This paper discusses how low pass filters can be optimally used to smooth the raw ILI signals to allow for analytical representation of the dent shape without underestimating its severity. The conclusion of this venture is a detailed workflow for the analytical assessment of dented pipelines for the rapid characterization of the severity of deformation in pipelines with limited computational demand. This type of assessment allows for initial ranking and assessment of large and complex pipeline systems to select features requiring more detailed assessment or mitigation.
{"title":"Algorithms for the Strain Based Analysis of Dented Pipelines","authors":"Chike Okoloekwe, Muntaseer Kainat, Doug Langer, S. Hassanien, S. Adeeb","doi":"10.1115/IPC2018-78433","DOIUrl":"https://doi.org/10.1115/IPC2018-78433","url":null,"abstract":"Pipeline integrity management commonly leverages nondestructive inspection of pipeline defects via inline inspection (ILI) and assessment of the resultant data. Key parameters for dent analysis include the feature geometry measured by caliper tools and the presence/severity of any interacting features (such as cracks or areas of corrosion) which can be measured with a variety of technologies (such as magnetic flux leakage or ultrasonic tools). Dent profile measurements can be especially susceptible to noise due to the measurement techniques employed, signal quality, and overall tool performance. Analytical methods for strain assessment of dents can employ curve/surface fitting techniques to estimate the curvature and calculate the strain of the dent based on the fitted curve/surface. Noise in the measured profile can result in local areas of high perceived strain, which could lead to misinterpretation of a dent’s true severity, especially when using automated or purely analytical assessment methods.\u0000 A deterministic strain-based approach for evaluating the severity of dented pipelines has been presented previously which leverages multi-dimensional B-spline functions to more accurately apply the non-mandatory ASME B31.8 equations for dent assessment. The approach presented previously requires relatively smooth dent profile information to minimize the effects of signal noise. While low pass filters can effectively eliminate noise in the signal, they may also lead to loss of accuracy (e.g. excessive smoothing can reduce the depth and sharpness of a measured dent’s profile). This paper discusses how low pass filters can be optimally used to smooth the raw ILI signals to allow for analytical representation of the dent shape without underestimating its severity.\u0000 The conclusion of this venture is a detailed workflow for the analytical assessment of dented pipelines for the rapid characterization of the severity of deformation in pipelines with limited computational demand. This type of assessment allows for initial ranking and assessment of large and complex pipeline systems to select features requiring more detailed assessment or mitigation.","PeriodicalId":273758,"journal":{"name":"Volume 1: Pipeline and Facilities Integrity","volume":"27 1","pages":"0"},"PeriodicalIF":0.0,"publicationDate":"2018-09-24","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"123654767","PeriodicalName":null,"FirstCategoryId":null,"ListUrlMain":null,"RegionNum":0,"RegionCategory":"","ArticlePicture":[],"TitleCN":null,"AbstractTextCN":null,"PMCID":"","EPubDate":null,"PubModel":null,"JCR":null,"JCRName":null,"Score":null,"Total":0}
R. Dotson, Christine F Holliday, Luis Torres, D. Hagan
A significant amount of effort has been expended in the area of advancing pipeline dent remaining life assessment methods beginning in the late 1980s and extending to the current day. Initial research efforts were primarily empirical in nature while more recent research efforts have incorporated finite element modelling. Coupled with advancements in assessment techniques, the capabilities of advanced in-line inspection (ILI) tools have increased to a point where they can provide consistent, reliable information that is suitable for dent assessments. As a result of these advancements in assessment models and ILI tools, operators can now perform remaining life assessments using ILI data, and a multitude of remaining life assessment models are available, including solutions from the European Pipeline Research Group (EPRG), Pipeline Research Council International (PRCI), American Petroleum Institute (API), and finite-element based approaches. In addition to these remaining life assessments, many operators routinely perform strain-based assessments based on guidance from ASME B31.8. To date, there have been few studies comparing the various assessment methods on large numbers of dents, and as a result, significant questions persist as to the conservatism inherent in each method. In addition, the EPRG and PRCI methods are largely based on full-scale testing and finite-element models performed with idealized indenter shapes while actual pipeline dents typically exhibit complex shapes and interactions between multiple dents. Each model also has limitations and advantages that are discussed in this paper, such as ease of use and how pipeline geometry and weld association are considered. This paper provides a robust comparison of selected dent assessment methodologies on 220 actual dents from a 24-inch pipeline with depths ranging from 0.6–4.5% OD, and 32 dents from a 30-inch line with depths ranging from 1–2.5% OD. The assessment includes both top and bottom of line dents and investigates the influence of restraint on remaining life. The results presented in the paper are based on high-resolution ILI caliper data collected during two in-line inspections. Furthermore, the paper provides statistical comparisons between strain and remaining life methodologies and also between the various remaining life assessments. The paper also provides a comparison of the restraint parameter from the PRCI model with calculated stress concentration factors from finite-element models. The paper provides a first of its kind comparison of the various methods and discusses how the work may be extended to other pipe diameters and wall thicknesses.
{"title":"An Authoritative Comparison of Remaining Life Assessments for Pipeline Dents","authors":"R. Dotson, Christine F Holliday, Luis Torres, D. Hagan","doi":"10.1115/IPC2018-78247","DOIUrl":"https://doi.org/10.1115/IPC2018-78247","url":null,"abstract":"A significant amount of effort has been expended in the area of advancing pipeline dent remaining life assessment methods beginning in the late 1980s and extending to the current day. Initial research efforts were primarily empirical in nature while more recent research efforts have incorporated finite element modelling. Coupled with advancements in assessment techniques, the capabilities of advanced in-line inspection (ILI) tools have increased to a point where they can provide consistent, reliable information that is suitable for dent assessments. As a result of these advancements in assessment models and ILI tools, operators can now perform remaining life assessments using ILI data, and a multitude of remaining life assessment models are available, including solutions from the European Pipeline Research Group (EPRG), Pipeline Research Council International (PRCI), American Petroleum Institute (API), and finite-element based approaches. In addition to these remaining life assessments, many operators routinely perform strain-based assessments based on guidance from ASME B31.8. To date, there have been few studies comparing the various assessment methods on large numbers of dents, and as a result, significant questions persist as to the conservatism inherent in each method. In addition, the EPRG and PRCI methods are largely based on full-scale testing and finite-element models performed with idealized indenter shapes while actual pipeline dents typically exhibit complex shapes and interactions between multiple dents. Each model also has limitations and advantages that are discussed in this paper, such as ease of use and how pipeline geometry and weld association are considered. This paper provides a robust comparison of selected dent assessment methodologies on 220 actual dents from a 24-inch pipeline with depths ranging from 0.6–4.5% OD, and 32 dents from a 30-inch line with depths ranging from 1–2.5% OD. The assessment includes both top and bottom of line dents and investigates the influence of restraint on remaining life. The results presented in the paper are based on high-resolution ILI caliper data collected during two in-line inspections. Furthermore, the paper provides statistical comparisons between strain and remaining life methodologies and also between the various remaining life assessments. The paper also provides a comparison of the restraint parameter from the PRCI model with calculated stress concentration factors from finite-element models. The paper provides a first of its kind comparison of the various methods and discusses how the work may be extended to other pipe diameters and wall thicknesses.","PeriodicalId":273758,"journal":{"name":"Volume 1: Pipeline and Facilities Integrity","volume":"97 1","pages":"0"},"PeriodicalIF":0.0,"publicationDate":"2018-09-24","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"124766084","PeriodicalName":null,"FirstCategoryId":null,"ListUrlMain":null,"RegionNum":0,"RegionCategory":"","ArticlePicture":[],"TitleCN":null,"AbstractTextCN":null,"PMCID":"","EPubDate":null,"PubModel":null,"JCR":null,"JCRName":null,"Score":null,"Total":0}
Clément Soret, J. M. Djouda, M. Bonnaudet, M. Zaréa, Y. Madi
Due to external interference, pipelines used for onshore as well as offshore operations can present dent and gouge defects. As such defects can seriously impair facilities’ integrity and performance, it is necessary to evaluate the strains in the vicinity of these defects. The development of non-destructive approaches to assess defects severity remains an issue in the pipeline industry. In the present study, micro-hardness - strain relationships are established for three steel grades of pipeline materials: API X52 modern, API X52 vintage and API X63 vintage. The micro-hardness – strain correlations of the three pipe materials are analyzed in order to verify if they can be described by a master curve. For that purpose, Notched Tensile (NT) tests are performed in Longitudinal (L) and Transverse (T) directions for each grade in order to reach high strain values (up to 70%). The relationship proposed by Tabor was improved with the introduction of three new parameters that allow considering actual material behavior.
{"title":"Implementation of a New Tool for Pipelines Integrity Evaluation: A Correlation Between Local Strains and Hardness","authors":"Clément Soret, J. M. Djouda, M. Bonnaudet, M. Zaréa, Y. Madi","doi":"10.1115/IPC2018-78547","DOIUrl":"https://doi.org/10.1115/IPC2018-78547","url":null,"abstract":"Due to external interference, pipelines used for onshore as well as offshore operations can present dent and gouge defects. As such defects can seriously impair facilities’ integrity and performance, it is necessary to evaluate the strains in the vicinity of these defects. The development of non-destructive approaches to assess defects severity remains an issue in the pipeline industry. In the present study, micro-hardness - strain relationships are established for three steel grades of pipeline materials: API X52 modern, API X52 vintage and API X63 vintage. The micro-hardness – strain correlations of the three pipe materials are analyzed in order to verify if they can be described by a master curve. For that purpose, Notched Tensile (NT) tests are performed in Longitudinal (L) and Transverse (T) directions for each grade in order to reach high strain values (up to 70%). The relationship proposed by Tabor was improved with the introduction of three new parameters that allow considering actual material behavior.","PeriodicalId":273758,"journal":{"name":"Volume 1: Pipeline and Facilities Integrity","volume":"67 252 1","pages":"0"},"PeriodicalIF":0.0,"publicationDate":"2018-09-24","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"125962118","PeriodicalName":null,"FirstCategoryId":null,"ListUrlMain":null,"RegionNum":0,"RegionCategory":"","ArticlePicture":[],"TitleCN":null,"AbstractTextCN":null,"PMCID":"","EPubDate":null,"PubModel":null,"JCR":null,"JCRName":null,"Score":null,"Total":0}
Mexico’s Energy Reform has opened up various interesting and unique opportunities for energy infrastructure. A CO2 pipeline project that was recently completed in southern Mexico provides a perfect example of how to breathe new life to deteriorated pipeline infrastructure — infrastructure that would have typically been written off. By coupling a unique pipeline inspection method with a novel lining system, two 28-kilometer (17 mile) pipelines were rehabilitated in record time and in a cost-effective manner. The project consisted of two 12 and 18-inch (300 and 450 millimeters) CO2 transport pipelines that had been out of service for 22 years and that are a central component for a high-profile fertilizer project. Replacing these deteriorated assets with a new transport pipeline was not an option due to time, environmental, permitting and budgetary constraints. The rehabilitated system had to offer a minimum 25-year service life required by the owner. To put this aging infrastructure back into service, it was essential to assess the condition of the pipelines with a high level of accuracy and precision which would allow for the rehabilitation of the pipeline and installation of an interactive liner to extend the system’s serviceable life for a minimum of 25 years. The challenge, however, was that these pipelines were non-piggable by traditional methods. By using a tethered MFL and Caliper ILI solution, the pipelines were each inspected in 13 separate sections with the level of detail necessary to assess the condition and suitability of the rehabilitation strategy selected for the project. Fast-track scheduling constraints required 24-hour data analysis turnaround of reports identifying and discriminating areas of modest and significant corrosion as well as deformations including areas of significant weld slag which could complicate the installation of the liners. Once high-quality data was available, pinpoint repairs were possible with a combination of carbon fiber reinforcement and steel pipe replacement. Afterwards, the pipelines were internally lined with a patented process that effectively provides a double containment system. A grooved liner and the host steel pipe create an annular space that is pressurized with air and remotely monitored. The system is able to detect even a small pressure drop in the annulus that would occur in case the integrity is breached, or a pinhole develops in the steel pipe. With the grooved liner, external repairs can be conducted while the line continues to operate without interrupting CO2 service to the plant. By applying these novel solutions, the rehabilitated pipelines will transport carbon dioxide to a revitalized fertilizer plant in a safe and efficient manner for the next 25 years.
{"title":"Breathing New Life to Aging Pipeline Infrastructure Using Unique Wireline Inspection Techniques and Pipe-Lining Technology","authors":"C. Goudy, Alex Gutiérrez","doi":"10.1115/IPC2018-78594","DOIUrl":"https://doi.org/10.1115/IPC2018-78594","url":null,"abstract":"Mexico’s Energy Reform has opened up various interesting and unique opportunities for energy infrastructure. A CO2 pipeline project that was recently completed in southern Mexico provides a perfect example of how to breathe new life to deteriorated pipeline infrastructure — infrastructure that would have typically been written off. By coupling a unique pipeline inspection method with a novel lining system, two 28-kilometer (17 mile) pipelines were rehabilitated in record time and in a cost-effective manner. The project consisted of two 12 and 18-inch (300 and 450 millimeters) CO2 transport pipelines that had been out of service for 22 years and that are a central component for a high-profile fertilizer project. Replacing these deteriorated assets with a new transport pipeline was not an option due to time, environmental, permitting and budgetary constraints. The rehabilitated system had to offer a minimum 25-year service life required by the owner.\u0000 To put this aging infrastructure back into service, it was essential to assess the condition of the pipelines with a high level of accuracy and precision which would allow for the rehabilitation of the pipeline and installation of an interactive liner to extend the system’s serviceable life for a minimum of 25 years. The challenge, however, was that these pipelines were non-piggable by traditional methods.\u0000 By using a tethered MFL and Caliper ILI solution, the pipelines were each inspected in 13 separate sections with the level of detail necessary to assess the condition and suitability of the rehabilitation strategy selected for the project. Fast-track scheduling constraints required 24-hour data analysis turnaround of reports identifying and discriminating areas of modest and significant corrosion as well as deformations including areas of significant weld slag which could complicate the installation of the liners.\u0000 Once high-quality data was available, pinpoint repairs were possible with a combination of carbon fiber reinforcement and steel pipe replacement. Afterwards, the pipelines were internally lined with a patented process that effectively provides a double containment system. A grooved liner and the host steel pipe create an annular space that is pressurized with air and remotely monitored. The system is able to detect even a small pressure drop in the annulus that would occur in case the integrity is breached, or a pinhole develops in the steel pipe. With the grooved liner, external repairs can be conducted while the line continues to operate without interrupting CO2 service to the plant.\u0000 By applying these novel solutions, the rehabilitated pipelines will transport carbon dioxide to a revitalized fertilizer plant in a safe and efficient manner for the next 25 years.","PeriodicalId":273758,"journal":{"name":"Volume 1: Pipeline and Facilities Integrity","volume":"14 1","pages":"0"},"PeriodicalIF":0.0,"publicationDate":"2018-09-24","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"124615892","PeriodicalName":null,"FirstCategoryId":null,"ListUrlMain":null,"RegionNum":0,"RegionCategory":"","ArticlePicture":[],"TitleCN":null,"AbstractTextCN":null,"PMCID":"","EPubDate":null,"PubModel":null,"JCR":null,"JCRName":null,"Score":null,"Total":0}
In-Line inspection (ILI) tools consisting of combined sensor technologies provide a unique opportunity for operators to understand the conditions of pipelines. There is also an additional opportunity to contrast and validate individual sensing techniques against each other when their functionalities and purposes overlap. By using multi-technologies ILI measurements for strain, a pipeline operator can gain further insight into the pipeline strain behavior at any point along the length of the inspection. This paper establishes the relationship between ILI axial strain measurement tool data and conventional geometric strain data obtained from inertial measurement unit (IMU) based on data collected during in-service inspection of a 12″ liquid pipeline. Within any pipeline section, the tool configuration with circumferentially spaced strain sensors allows the use of appropriate analysis techniques to decompose the longitudinal strain into its primary components (axial, bending and out of roundness). The axial strain measurement tool sensing system provides an indirect measurement of bending strain that can be compared to the geometric measurement of bending strain determined from the pipeline trajectory as determined from the IMU analysis. Flexural bending strain resulting from horizontal directional drilling (HDD) is investigated in this paper. Convergences and divergences between the measurement techniques are presented. Data available from different strain technologies mounted on ILI tools offers an opportunity to conduct a comparative study and to provide a better understanding of a pipeline’s strain condition. This paper will present the framework for understanding the different strain measurement technologies and an investigation into the pipeline prior strain history (effects from fabrication, hydrostatic testing and external loads) and their corresponding impact on the material state at the time of inspection.
{"title":"Understanding Pipeline Strain Conditions: Case Studies Between ILI Axial and ILI Bending Measurement Techniques","authors":"J. Choquette, S. Cornu, M. ElSeify, Raymond Karé","doi":"10.1115/IPC2018-78577","DOIUrl":"https://doi.org/10.1115/IPC2018-78577","url":null,"abstract":"In-Line inspection (ILI) tools consisting of combined sensor technologies provide a unique opportunity for operators to understand the conditions of pipelines. There is also an additional opportunity to contrast and validate individual sensing techniques against each other when their functionalities and purposes overlap.\u0000 By using multi-technologies ILI measurements for strain, a pipeline operator can gain further insight into the pipeline strain behavior at any point along the length of the inspection. This paper establishes the relationship between ILI axial strain measurement tool data and conventional geometric strain data obtained from inertial measurement unit (IMU) based on data collected during in-service inspection of a 12″ liquid pipeline.\u0000 Within any pipeline section, the tool configuration with circumferentially spaced strain sensors allows the use of appropriate analysis techniques to decompose the longitudinal strain into its primary components (axial, bending and out of roundness).\u0000 The axial strain measurement tool sensing system provides an indirect measurement of bending strain that can be compared to the geometric measurement of bending strain determined from the pipeline trajectory as determined from the IMU analysis. Flexural bending strain resulting from horizontal directional drilling (HDD) is investigated in this paper. Convergences and divergences between the measurement techniques are presented.\u0000 Data available from different strain technologies mounted on ILI tools offers an opportunity to conduct a comparative study and to provide a better understanding of a pipeline’s strain condition. This paper will present the framework for understanding the different strain measurement technologies and an investigation into the pipeline prior strain history (effects from fabrication, hydrostatic testing and external loads) and their corresponding impact on the material state at the time of inspection.","PeriodicalId":273758,"journal":{"name":"Volume 1: Pipeline and Facilities Integrity","volume":"12 1","pages":"0"},"PeriodicalIF":0.0,"publicationDate":"2018-09-24","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"125214746","PeriodicalName":null,"FirstCategoryId":null,"ListUrlMain":null,"RegionNum":0,"RegionCategory":"","ArticlePicture":[],"TitleCN":null,"AbstractTextCN":null,"PMCID":"","EPubDate":null,"PubModel":null,"JCR":null,"JCRName":null,"Score":null,"Total":0}
Jidong Kang, D. Bibby, J. Gianetto, M. Gesing, M. Arafin
Near-neutral pH stress corrosion cracking (NNpHSCC) continues to be a concern for existing high pressure pipelines used to transport oil and gas in Canada. Although several studies have focused on the role of pipe steel microstructure on the initiation and growth of NNpHSCC, most used specimens machined from sub-surface locations that did not preserve the original pipe surface, which is the material that ultimately exposed. In the present work, a series of test specimens were designed to preserve the external pipe surface and allowed shallow 0.05 mm root radius surface notches with depths from 0.1, 0.2 and 0.3 mm to be machined and tested. All specimens were machined in the hoop (transverse) direction from a 1067 mm diameter, 12.5 mm thick X80 pipe. The specimens were subjected to a constant load of 95% of the specified minimum yield strength (SMYS) (equivalent to 80% of the actual pipe hoop yield strength) using proof rings for extended durations, e.g., 110, 220, 440 or 660 days. The results show that there was no apparent SCC developed on the smooth specimens with the original surface even after being tested for up to 660 days. In contrast, SCC were found to have initiated at the machined notches, irrespective of their depth after testing for 220 days. To provide further understanding of specimen design, the same SCC testing conditions were applied to smooth round-bar test specimens machined in the hoop direction of this same pipe close to the external surface and the mid-wall locations. While minor SCC initiation was found in the near surface specimens, significant SCC was observed in the specimens taken from the mid-wall location. This finding suggests that the heterogeneous or variable microstructure through the pipe wall thickness plays a critical role in SCC initiation for the X80 pipe investigated. It also suggests that careful attention must be paid to the design of test specimens as well as the location that they are removed from a test pipe in order to realistically assess the SCC susceptibility of pipe steels.
近中性pH应力腐蚀开裂(NNpHSCC)一直是加拿大现有高压油气管道的一大问题。虽然有几项研究集中在管材钢微观结构对NNpHSCC的产生和生长的作用，但大多数研究使用的试样都是从亚表面位置加工而来，这些位置没有保留原始的管材表面，而原始的管材表面是最终暴露的材料。在本工作中，设计了一系列试样，以保留管道外表面，并允许加工和测试深度为0.1,0.2和0.3 mm的根半径为0.05 mm的浅切口。所有试样均从直径为1067 mm, 12.5 mm厚的X80管材上沿环形(横向)方向加工。试件承受规定最小屈服强度(SMYS)的95%的恒定载荷(相当于实际管箍屈服强度的80%)，使用证明环延长持续时间，例如110、220、440或660天。结果表明，即使经过长达660天的试验，具有原始表面的光滑试件仍未出现明显的SCC发育。相比之下，经过220天的测试，发现SCC在机械切口处开始，无论其深度如何。为了进一步了解试件设计，将相同的SCC测试条件应用于同一管道靠近外表面和中壁位置的环向加工的光滑圆棒试件。虽然在近表面标本中发现了轻微的SCC起始，但在中壁位置的标本中观察到明显的SCC。这一发现表明，在所研究的X80管材中，管壁厚度的异质或可变微观结构在SCC的发生中起着关键作用。这也表明，必须仔细注意试件的设计以及从试验管道中取出试件的位置，以便真实地评估管钢的SCC敏感性。
{"title":"Some Factors Affecting Initiation of Stress Corrosion Cracking of an X80 Pipe Steel in Near-Neutral pH Environment","authors":"Jidong Kang, D. Bibby, J. Gianetto, M. Gesing, M. Arafin","doi":"10.1115/IPC2018-78540","DOIUrl":"https://doi.org/10.1115/IPC2018-78540","url":null,"abstract":"Near-neutral pH stress corrosion cracking (NNpHSCC) continues to be a concern for existing high pressure pipelines used to transport oil and gas in Canada. Although several studies have focused on the role of pipe steel microstructure on the initiation and growth of NNpHSCC, most used specimens machined from sub-surface locations that did not preserve the original pipe surface, which is the material that ultimately exposed.\u0000 In the present work, a series of test specimens were designed to preserve the external pipe surface and allowed shallow 0.05 mm root radius surface notches with depths from 0.1, 0.2 and 0.3 mm to be machined and tested. All specimens were machined in the hoop (transverse) direction from a 1067 mm diameter, 12.5 mm thick X80 pipe. The specimens were subjected to a constant load of 95% of the specified minimum yield strength (SMYS) (equivalent to 80% of the actual pipe hoop yield strength) using proof rings for extended durations, e.g., 110, 220, 440 or 660 days. The results show that there was no apparent SCC developed on the smooth specimens with the original surface even after being tested for up to 660 days. In contrast, SCC were found to have initiated at the machined notches, irrespective of their depth after testing for 220 days. To provide further understanding of specimen design, the same SCC testing conditions were applied to smooth round-bar test specimens machined in the hoop direction of this same pipe close to the external surface and the mid-wall locations. While minor SCC initiation was found in the near surface specimens, significant SCC was observed in the specimens taken from the mid-wall location. This finding suggests that the heterogeneous or variable microstructure through the pipe wall thickness plays a critical role in SCC initiation for the X80 pipe investigated. It also suggests that careful attention must be paid to the design of test specimens as well as the location that they are removed from a test pipe in order to realistically assess the SCC susceptibility of pipe steels.","PeriodicalId":273758,"journal":{"name":"Volume 1: Pipeline and Facilities Integrity","volume":"66 1","pages":"0"},"PeriodicalIF":0.0,"publicationDate":"2018-09-24","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"121826350","PeriodicalName":null,"FirstCategoryId":null,"ListUrlMain":null,"RegionNum":0,"RegionCategory":"","ArticlePicture":[],"TitleCN":null,"AbstractTextCN":null,"PMCID":"","EPubDate":null,"PubModel":null,"JCR":null,"JCRName":null,"Score":null,"Total":0}
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