: Zoom; LP-IPC-Banner

Papers

Webinar21

The ROSEN Group is proud to once again play an active role in the International Pipeline Conference from 28-30 September 2020. The event will be organized in a virtual only format for the first time and brings together members of the pipeline industry from all around the world to discuss the latest developments and share knowledge.

The pipeline network comprises of various systems with their own sets of vital assets and unique threats. Determining the integrity of these assets is a crucial element to ensure sustainable, safe, efficient, and reliable operation. Therefore, we have identified the unique integrity challenges associated with each of these systems and developed innovative solutions to help operators achieve their goal of zero incidents.

Discover how we have focused on each aspect of the pipeline network and get to know our latest innovations by listening to our papers, visiting our virtual exhibition booth and attending live chats with our experts.

Pipeline Construction

Verifying Quality

Prior to the commissioning of a pipeline, the newly-constructed asset must fulfil certain requirements to prove that its integrity is intact and that the construction quality was high. Hydro testing, dewatering, caliper inspections, and verification digs, which can be required after construction, prove to be both expensive and time consuming for the construction contractor and operator.

Through custom cleaning programs, geometry verification, mapping and caliper units, our solutions are available on a standby basis and provide efficient, API and ISO compliant results. Our aim is to get newly-constructed pipelines up and running without the unnecessary need for expensive digs and time-consuming reports.

Learn more:
Geometry and Mapping
Pre-Commissioning Solutions

Gathering Pipelines

Efficient Flexibility

Operating at low flows and pressures, gathering lines transport product from the commodity’s source to a processing or storage facility. These lines can be as small as 3” in diameter, consisting of tight bends and often containing multiphase medium. Managing the primary threats of internal and external corrosion proves challenging when downtime must be at a minimum.

Our extensive portfolio consists of a wireline-equipped fleet of bidirectional tools to serve your quick turnaround requirements. Detecting and sizing anomalies and optimizing flow, our solutions for gathering pipelines can overcome difficult conditions and design both efficiently and comprehensively, thereby minimizing interruptions while gathering high-quality results.

Learn more:
Bidirectional Solutions

Feeder Pipelines

Unique Versatility

The primary role of these pipelines is to feed product from a processing or storage facility to the long-distance transmission pipelines. The role of being a point of transition either within a facility or outside the controlled area means that these systems can have varying states of integrity and can present obstacles which may inhibit traditional inspection methods.

Our vast portfolio of complementing units, such as technologies, methods, and market knowledge, enables our experts to optimally address each individual challenge of your unique asset. This tailored solution not only produces the means to have the pipeline inspected, but also, when required, provides a comprehensive integrity assessment.

Learn more:
Challenging Pipeline Diagnostics

Transmission Pipelines

Ensuring Reliability

As the major conduit of the pipeline network, transmission pipelines are responsible for the transportation of large volumes of product from production regions to distribution centers, storage tanks or refineries. These long-distance pipelines are exposed to a wide range of threats, which can result in various anomalies, minimized throughput, or failure.

As this infrastructure ages, the accuracy of each inspection and the predicted behavior of identified features becomes more crucial. With high-resolution technologies such as RoCorr MFL-A Ultra, operators gain a comprehensive and accurate understanding of the pipeline's structure and tap into the full potential of the asset, leaving nothing to chance. Additional technologies can also be combined for increased accuracy, ensuring that even the smallest threat is not only detected, but also analyzed, and its future behavior predicted.

Learn more:
RoCorr MFL-A Ultra

Distribution Pipelines

Optimizing Uptime

Distribution pipelines are responsible for delivering natural gas to the end user. These can be lower pressure pipelines and often operate within close proximity to homes and businesses. This means that as the infrastructure grows around them, maintenance and replacement costs increase as well.

Maintaining the integrity of these pipelines is key to prolonging the life of the asset in a safe and secure way. Our low-ﬂow multi-diameter solutions for gas pipelines, one of many solutions available for this asset, has no impact on operation and does not require a compromise regarding the quality of the inspection data. This ensures optimal throughput in an efficient manner.

Learn more:
Multi Diameter Technology

Processing & Storage

Always Operational

Remaining in operation is key for processing and storage facilities. During scheduled shutdowns, there is usually a limited window for inspection, however an unexpected shutdown due to leakage could be disastrous for the facility overall. Critical features of these components are often either a hidden threat, undetected by even the most experienced inspector during visual examination, or they may be visible but cannot be quantified.

Based on customer-specific requirements and local regulations, an on-site support team is rapidly assembled to conduct a comprehensive and efficient inspection. When accessibility is limited, technology is applied to fill in the data gaps for these critical assets. Non-destructive testing solutions for inaccessible areas allows for a comprehensive, full coverage, high-resolution inspection with accurate data collection and minimal impact on operation. Thus, the operator obtains the information required to achieve safe and compliant operation well into the future.

Learn more:
Piping Inspection Services

ROSEN invests significantly in further refining products and services and developing groundbreaking new technologies and products. Research and development is fundamental to ROSEN’s continued success. The Group employs more than 330 engineers and scientists worldwide. These professionals focus on developing solutions that help decreasing operating costs, increasing production efficiency, lower the environmental impact of production and, of course, improve the performance of products.

Since the introduction of in-line inspection tools (ILI) more than 50 years ago, there have always been pipelines that were considered unpiggable. Typically, it is a combination of various circumstances relating to pipeline design, operating conditions, and/or characteristics of the medium that prevents a successful in-line inspection using traditional methods. At ROSEN, however, we refuse to accept this as a fact. This is why we have dedicated an entire diagnostics division to apply our unique “Toolbox Method” to create ILI solutions for what we refer to as challenging pipelines. The ROSEN Toolbox is further diversified with the addition of KTN’s specialized self-propelled tethered tool technology.

To view the papers please register for the conference.

Papers

Paper 1

How do I ensure ‘Staff Competency’ in my Pipeline Safety Management System?

Karen Collins, Michelle Unger (ROSEN Group)

Abstract

Standards and regulations are clear: all staff who work on pipelines need to be both competent and qualified. Standards such as API 1173 are clear about competence within a safety management system...

Paper 1

Standards and regulations are clear: all staff who work on pipelines need to be both “competent” and “qualified.” Standards such as API 1173 are clear about competence within a safety management system: “The pipeline operator shall ensure that personnel whose responsibilities fall within the scope of the PSMS [Pipeline Safety Management System] have an appropriate level of competence in terms of education, training, knowledge, and experience.” The burden of defining and specifying competence falls on pipeline operators, but they have little guidance regarding the required skills, knowledge and levels of competency. Additionally, we are all biased – different operators will have different ideas and emphases on competencies, which will affect their decision-making. The only way to avoid these cognitive biases is to use consensus standards supported by rigorous surveys that capture the required competencies.

This paper explores some of the more common biases that can affect decisions and presents the results of a controlled survey aimed at both specifying and quantifying the necessary competencies needed by a specific engineer working within a PSMS: a pipeline integrity engineer. The survey’s objective was to investigate the key skills and knowledge requirements needed in a junior engineering position, i.e. a pipeline engineer with less than three years of relevant experience working under supervision to be “competent.” It listed eight core competencies (identified by subject-matter experts) considered essential for a pipeline integrity engineer. Each competency contained a set of skills. Respondents were first asked to rank the eight core competences, then rank the skills within the competency.

An analysis of the data provides insights into how 100 pipeline integrity engineers from 25 different countries view key skills required to be “competent.” The results of the survey can assist pipeline companies in setting objective competency requirements for their engineering personnel, developing learning programs to address any gaps and improve the overall safety of their pipeline system.

Paper 2

Judge Me By My Size Do You? Or How Reliable Are Dent Assessments Based on ILI Data?

Rhett Dotson, Ryan Sager (ROSEN Group)

Abstract

Paper 2

Pipeline dents have historically been regulated and assessed using dent depth as the primary metric. Consequently, ILI caliper tool capabilities are stated in terms of dent depth. However, the best modern dent assessments, including both strain and fatigue assessments, are based on dent shape. The utilization of advanced dent assessments is expected to grow in the future as the methods are incorporated into API Recommended Practices and US regulations. Unfortunately, there is virtually no information available on the reliability of these assessment methods when they are based on ILI data. The reliability of the methods is critical when choosing safety factors or reinspection intervals.

This study presents a first look at the repeatability of strain and remaining life assessments based on two separate caliper runs. The study examines dent strain according to ASME B31.8 and remaining life calculated using shape factors and finite element methods calculated for over three hundred dents. The paper examines the variation in each of the methods and provides guidance on how users should understand the results when they are based on a single inspection.

Paper 3

Pipeline Depth of Cover – Can you demonstrate compliance?

Daniel Finley, Simon Daniels (ROSEN Group)

Abstract

Third-party interference is widely documented as being a major cause of damage to buried pipelines. In addition to routine surveillance, maintaining a minimum depth of cover is recognized as a...

Paper 3

Third-party interference is widely documented as being a major cause of damage to buried pipelines. In addition to routine surveillance, maintaining a minimum depth of cover is recognized as a key means of mitigation against third-party interference. We know that the depth of cover over pipelines can change with time. Changes in depth of cover can also be an indication of thermal upheaval, frost heave or ground movement. Current techniques available for measuring depth of cover on buried pipes require significant effort to produce a high-resolution survey for an entire pipeline.

A UK Innovation project completed for National Grid Gas Transmission in 2017 successfully demonstrated a methodology for calculating pipeline depth of cover by combining ground elevation data with high-resolution inertial measurement unit (IMU) data collected during in-line inspection.

Since then, ROSEN has completed an additional nine depth of cover inspections, exceeding a total of 380 kilometers. This paper presents the findings of the additional inspections, explores the variations in depth of cover seen, and highlights how the information can be used to demonstrate compliance with relevant pipeline design and operation regulations and standards.

Paper 4

Leak Rate Testing of a Natural Pipeline Defect

Bob Andrews, Joe Short (ROSEN Group)

Abstract

Paper 4

If a stable through-wall defect (leak) occurs in a pipeline, the leak rate is an important factor for both safety and environmental assessments as well as for determining the performance requirements for a leak detection system. For a “large” leak, an assessment can be based on simple idealization as an orifice, but for crack-like defects this is not appropriate. The flow through a crack is dependent on factors such as the surface roughness and the crack opening. These issues have been extensively studied for nuclear pipework where the fluid is either pressurized water, steam or CO2, and guidance is given in Annex F of BS 7910. However, there is little published work for pipeline geometries and single-phase liquids such as refined hydrocarbons.

This paper presents the results of experiments measuring the leak rates through a tight axial through-wall crack in an NPS 8 refined-products pipeline. Leak-rate measurements were made using water (for safety reasons) over a range of pressures. The data was fitted to a model for leakage through a tight crack that takes account of the interaction of asperities in surface roughness. The fitted equation was then adjusted to take account of the different densities and viscosities of the pipeline products. It was concluded that the model was able to give a good prediction of the measured leak rates and that the adjustments for the product properties were small.

Paper 5

Preventing girth weld failure in large diameter pipelines: measurement of loads and application of assessment methods

Bob Andrews, Andy Young (ROSEN Group)

Abstract

Paper 5

Pipeline failures from circumferential cracking at girth welds continues to affect large diameter oil and gas transmission lines, even for modern lines constructed this century. The key factors that contribute to the failure at girth welds are the dimensions of defects present, the material properties of the pipe and weldments, and the presence of loading that drives crack growth. The mechanisms of failure are well understood, but identifying and measuring the contributing factors can be a challenge. Locating girth welds that are subject to elevated loads will enable operators to focus on sections with an increased threat of failure.

In this paper, we consider each of the key factors, how these are identified and defined, and the uncertainties in the measurement process. Specific attention is applied to the presence and quantification of loads and how these influence the potential for failure. This includes sources of active external loading due to ground movement, for example, or loads generated in the pipeline from the construction process. Loads can also be quantified by measuring bending strain from in-line inspection inertial measurement units. A more complete picture of pipeline loading can be established by integrating a structural analysis that accounts for the direction of pipeline movement and the presence of axial loads. The relationship between assessing pipeline integrity from ground movement – typically with strain-based methods – and establishing whether the defect can survive the load is explored. The relative contribution of bending and axial loads in the failure of defects is considered.

Paper 6

Now You SCC Me, Now You Don’t – Using Machine Learning to Find Stress Corrosion Cracking

Michael Smith, Aidan Blenkinsop, Matthew Capewell, Brian Kerrigan (ROSEN Group)

Abstract

Paper 6

Electromagnetic Acoustic Transducer (EMAT) is a non destructive inspection technology that uses guided acoustic waves to detect planar flaws in a metal structure. When deployed via in-line inspection (ILI), it is an effective way to detect cracks in a pipeline. EMAT has thus become a staple of crack management programs throughout the world since its introduction to the market over a decade ago.

As with all technologies, challenges remain with the inspection process. One such challenge with EMAT is classification. While it is possible to determine that an anomaly is “crack-like” (a property determined by its tendency to reflect incident waves), it is difficult to determine the nature of the anomaly from the EMAT measurement alone. Indeed, similar reflections are obtained for many different types of anomalies, from relatively benign manufacturing and construction abnormalities to more concerning defects such as stress corrosion cracking (SCC).

To compensate for the difficulties in classification, it is good practice to follow up an EMAT inspection with a number of in field verifications. These investigations allow for a more direct observation of classification and size and provide valuable information about the nature of cracks. They are, however, expensive – meaning that avoiding unnecessary digs is a top priority.

In this paper, we document a developing approach to post ILI crack management where the results of an EMAT run are combined with those from field verifications to maximize the amount of information gained from costly field work. This approach – which relies on supervised machine learning – leads to a marked improvement in the classification of crack like indications from EMAT and allows future investigations to be prioritized according to the likelihood of finding a concerning defect.

The method was trialed on a pipeline system with extensive SCC, leading to an improved success rate in finding SCC and a more cost effective crack management plan.

Paper 7

In-line MFL Inspection in Low Pressure Gas Distribution Networks

Johannes Becker, Corey Richards, Guenter Sundag (ROSEN Group)

Abstract

Paper 7

A large majority of local gas distribution pipelines are designed to accommodate future inspection surveys with in-line inspections tools. While this remains true, even with typical inspection design parameters considered, many pipelines remain on the “difficult-to-inspect” list and fall into a “gray” zone. Much of this can be due to operational parameters, which results in stop-start behaviors and speed excursions of the inspection tool during the in-line inspection. Although technically piggable, vintage design practices such as numerous 1.5D bends and multiple heavy wall transitions have continually shown to be an ongoing issue when running ILI tools in gas distribution lines. The first assessment characteristically indicates that standard inspection tools can be used for this type of pipeline, but due to the aforementioned reasons, new technologies and methodologies are required to reduce the incidents of stationary tools and improve data quality.

In the end, operators consider these lines a critically important component of their entire system and are keen to gain a clear picture of the assets’ integrity. Suitable in-line inspection solutions are therefore in demand.

This paper outlines various elements that can be overlooked when attempting to apply inspection and cleaning technologies to these gray-zone pipelines. These elements, both procedural and mechanical, allow for the inspection tool to traverse various obstacles and often debris while still providing a high-resolution data set.

Supporting the content will be a detailed case study of one of Enbridge Gas Distribution’s NPS 08 pipelines, which did not provide the required operational parameters to gather acceptable data when utilizing standard ILI technologies.

This NPS 08 line contained various challenges, such as:

Unknown or unreliable pipeline information, specifically bend radii and wall thicknesses.
No previous cleaning and inspection records.
Low operational pressures of 1000 to 2100 kPa.
Pipeline length over 100 km.
MOP restrictions did not allow for higher pressures.
Flow rate only available in limited windows.
Cleanliness is unknown, assumed to be a concern.

Many technical issues initially affected the project, one of which resulted in a stationary cleaning tool. The lessons learned will also be outlined to better support the understanding of the approach. In the end, tailored geometry and low-friction MFL technologies capable of safely traversing the pipeline and gathering high-quality data were utilized for the inspection. This case study will provide other operators some insights into how to inspect similar assets while also outlining specialized technologies suited to support the inspection.

Paper 8

A Cross-Sectional Study on the Prevalence of Corrosion in Pipelines

Erika Santana, Matthew Capewell, Jonathan Martin, Konstantinos Pesinis, Michael Smith (ROSEN Group)

Abstract

Paper 8

Over the past few decades, a vast amount of in-line inspection (ILI) data has been collected and used to understand the condition and fitness for service of individual pipelines all around the world. Little attempt has been made, however, to use this wealth of information to study the incidence and prevalence of damage mechanisms across the global population. This field of study – originating in the medical profession for the analysis of disease – is known as epidemiology. This paper presents the results of an epidemiological study on the “disease” of corrosion.

At present, the work is based on a pilot data warehouse containing ILI data for over 5,000 pipelines. For those pipelines that had been inspected multiple times, hundreds of millions of corrosion records were extracted from the data warehouse and processed using a series of Python algorithms. The result was a set of condition metrics describing damage accumulation and progression within the assets of interest. Next, the asset “metadata” (such as construction and operational characteristics) was extracted and hosted in a digital environment alongside the condition metrics.

Using machine learning techniques in combination with expert corrosion knowledge, the influence of asset metadata on damage accumulation was systematically investigated. The final output was a set of characteristic distributions describing the initiation and propagation behavior of corrosion according to key mechanisms. These conclusions can be used to support best-practice corrosion management in both inspected and uninspected pipelines.

Paper 9

Concerted, computing intense novel MFL approach ensuring reliability and reducing the need of dig verification

Johannes Palmer, Andrey Danilov (ROSEN Group)

Abstract

Paper 9

Magnetic Flux Leakage (MFL) is a robust technology with high data coverage. Decades of continuous sizing improvement allowed for industry-accepted sizing reliability. The continuous optimization of sizing processes ensures useful results in categorizing metal-loss features. However, the identified selection of critical anomalies is not always optimal; sometimes containing anomalies are dug up too early or unnecessarily and, in rare cases, false under-calls can take place.

Today, complex empirical formulas together with multifaceted lookup tables, fed by pull tests, synthetic data and dig verifications, machine learning, artificial intelligence, and, not least, human expertise are translating MFL signals into metal-loss assessments with high levels of success. Nevertheless, two important principal elements are limiting the possible MFL sizing optimization. One is the empirical character of the signal interpretation. The other is the implicitly induced data and result simplification.

The reason to go this principal route for many years is simple: it is methodologically impossible to directly calculate the metal-source geometry from the signals. In addition, the pure number of possible relevant geometries is so large that simplification is necessary and inevitable. Moreover, the second methodological reason is the ambiguity of the signal, defining the metal-loss-sizing target as the most probable solution. However, even under the best conditions, the most probable one is not necessarily the correct one.

The paper describes a novel, fundamentally different approach as a basic alternative to the common MFL analysis approach described above. A calculation process is presented, which overcomes the empirical nature of traditional approaches by using a result optimization method that relies on intense computing and avoids any simplification. Additionally, the strategy to overcome MFL ambiguity will be shown. Together with the operator, detailed blind-test examples demonstrate the enormous level of detail, repeatability and accuracy of this groundbreaking technological method with the potential to reduce the need for field verification of ILI-identified corrosion anomalies.

Paper 10

Managing the Threat of Selective Seam Weld Corrosion using a State of the Art ILI System

Simon Slater, Chris Davies and Christopher De Leon (ROSEN Group), Carlos Gauna and Antonio Silva (Valero)

Abstract

Paper 10

For many years, pipeline safety regulations in the US have defined prescriptive minimum requirements for integrity management combined with a clear expectation that operators should do more than the minimum where appropriate. The regulations have also provided operators with the flexibility to take a performance based integrity management approach leveraging as much information available to manage threats effectively. One the threats that must be managed is Selective Seam Weld Corrosion (SSWC). SSWC is an environmentally assisted mechanism in which there is increased degree of metal loss in the longitudinal weld in comparison to the surrounding pipe body. An appropriate definition is linear corrosion that is deeper in the longitudinal weld zone than the surrounding pipe body. In some cases, the surrounding pipe body may have limited or no corrosion present, and in other cases the pipe body corrosion may have occurred but at a slower rate than the local corrosion in the longitudinal weld zone. Conventional responses to potential or identified threats focus on in-situ investigations, often resulting in expensive and un-planned repairs for features reported by In-line Inspection (ILI) that when assessed properly demonstrate a remnant life well into the next inspection interval. When ILI identifies metal loss indications co-located with the longitudinal seam weld, the current prescribed response is often a blanket call for remediation. Such a response may not be appropriate if an ILI system is deployed to discriminate feature types and integrity assessment is exercised leveraging a sound understanding of the pipe’s material properties. This paper describes the approach taken by a North American Liquid Pipeline operator to manage the threat of SSWC. The foundation of the approach was deployment of an appropriate ILI system incorporating an effective ILI technology, an optimized evaluation process considering the specific threat morphology, material testing and a structured dig program. The evaluation process uses the ILI data and data from the field in combination material properties data and a susceptibility analysis to classify anomalies as “Likely”, “Possible” and “Unlikely” SSWC. This is aligned with the guidance in API RP 1176 “Assessment and Management of Cracking in Pipelines” [9] for defining an appropriate response to ILI calls. Approaching the management of SSWC in this way allows operators to define a structured response for excavation activities to verify the process and remediate features as required. By using likelihood classification the risk to pipeline integrity can be reduced by acting on the most likely SSWC features as a priority, whilst collecting the data needed to make informed decisions on where to focus resources and efforts on what is a very complicated and difficult to manage threat. The output form this work, including a future plan for managing the remaining metal loss features, was documented in a procedure that was incorporated into the existing Integrity Management Plan.

Paper 11

MAOP reconfirmation for a 20 inch Gas Pipeline using the ECA Approach and Enhanced ILI

Simon Slater, Ollie Burkinshaw and Christopher Davies (ROSEN Group), Peter Clyde (Louisville Gas and Electric)

Abstract

Paper 11

In light of the revised Federal Pipeline Safety Regulations, active from 1 July 2020, operators of gas transmission pipelines are faced with the task of reconfirming the pipeline MAOP in a prescriptive set of circumstances. This requirement is defined in section 192.624 of 49 CFR 192. Louisville Gas and Electric (LGE) currently operates a pipeline using an MAOP established using a combination of TVC records and the so-called ‘grandfathering’ clause and has developed a plan and embarked with the process of reconfirming the MAOP using Method 3 – Engineering Critical Assessment. The pipeline is 20 inch diameter and predominately 0.25 inch wall thickness. It was originally constructed from vintage ERW pipe circa. 1960 to 1970 and is 29.86 miles long. There have been no reportable incidents on the line. There are various HCAs, MCAs, Class 3 and Class 4 locations along the line. The approach taken by LGE is to reconfirm the MAOP along the full pipeline length to cover the possibility of class location changes in the future. MAOP Reconfirmation method 3 is covered in clause 192.632 of 49 CFR 192. A critical aspect of this project was the implementation of various ILI technologies to detect, identify and size anomalies. ROSEN provided a program of enhanced ILI including technologies to assess crack-like and metal-loss features. Such a large ILI program is a significant undertaking with associated operational and engineering issues that have to be considered. A critical aspect of method 3 is the use of appropriate material properties in the ECA. LGE used the RoMat PGS ILI service as the foundation for material property verification in line with clause 192.607 of 49 CFR 192. This paper describes the comprehensive work performed by LGE and ROSEN to establish the MAOP reconfirmation process. This paper presents the methodologies used for each stage of the process and how the ILI results and material verification were used in feature assessments to determine predicted failure pressures and remaining life. By satisfying the regulations, LGE has established a process to manage the pipeline integrity effectively and reduce risk.

Paper 12

Getting To Know Your Bends to Support SCC Management

Chris Wood, Fernando Merotto, Brian Kerrigan (ROSEN Group)

Abstract

Paper 12

Nova Transportadora do Sudeste (NTS) own and operate a gas transmission system in Brazil constructed in 1996. One of the confirmed primary integrity threats to this system is axial stress corrosion cracking. The pipelines vary in diameter, weld type, manufacturer and age. One of the pipelines failed in 2015 due to an axial stress corrosion crack. Since the failure, NTS have executed an intense inspection campaign to detect and size axial cracking within their network.

The 2015 failure occurred on a field bend. The inspection campaign and following dig campaign has confirmed that cracking (both axial and circumferential) within field bends is the primary integrity threat. Brazil has a challenging terrain and approximately 40% of joints within the network were subject to cold field bending. The influences of the pipeline geometry within these areas have resulted in localised elevated stresses where the axial stress corrosion cracking colonies are initiating and growing. To date, no cracking (axial or circumferential) has been verified within their straight pipe joints.

NTS initially took a conservative baseline assessment approach using API 579 Part 9, due to the limited information regarding the pipe material and complex stress state. In addition to the hoop stress from internal pressure, the baseline assessment also considered weld residual stress and bending stress due to ovalization to determine immediate and future integrity.

An intensive dig campaign is underway following a crack detection in-line inspection campaign using electromagnetic acoustic transducer technology. A large number of deep cracks were reported by the in-line inspection system, these were verified to be deep and repaired with a type B sleeve. However, at one site an entire joint was removed for further analysis, to investigate the crack morphology, confirm material properties and refine the predictive failure pressure modelling.

This paper outlines how NTS have combined a burst test, mechanical testing, FEA modelling, fractography and metallographic examination to further understand the feature morphology and stresses within these areas and how they have been able to reduce conservatism from their baseline assessment with confidence and adopt a plastic collapse approach to accurately predict failure.

Paper 13

The North Saskatchewan River Valley Landslide - Slope and Pipeline Condition Monitoring

Chris Holliday, Terri Funk

Abstract

Paper 13

This paper details a case study of an engineering assessment on a pipeline where robust monitoring of continued ground movement and repeat in-line inspection (ILI) supported integrity management decisions and remediation activities. Following a loss of containment incident on a 16-inch diameter pipeline on the south slope of the North Saskatchewan River in July 2016, Husky has undertaken intensive studies to understand and learn from the failure. The cause of the incident was ground movement resulting from a landslide complex on the slope involving two deep-seated compound basal shear slides as well as a near surface translational slide in heavily over consolidated marine clays of the Upper Cretaceous Lea Park Formation.

One aspect of the studies has been to undertake structural analysis of the pipeline response to the loading imposed from the ground movement in order to prevent a similar occurrence from happening in the future and determine the integrity of the pipeline at the time of the assessment. Given the scale and complexity of the landslide, slope stabilization measures were not practical to implement, so repeat ILI using caliper and gyro technology, in addition to a robust monitoring program was implemented. Real-time monitoring of ground movements, pipe strain and precipitation levels provided a monitoring and early-detection system combined with documented risk thresholds that identified when to proactively shut-in the pipeline.

This paper presents the methodology and findings of the structural analysis that was undertaken to examine the robustness of the pipeline to withstand future landslide movement. The work involved simulation of the pipeline history on the slope including loads that had accumulated in the original pipeline sections based on historical ILI results and slope monitoring. The pipeline orientation was parallel with the ground movement in the landslide complex, so the development of axial strain in the pipeline was the dominant load component which are particularly damaging in the compression zone. The work provided recommendations to ensure the integrity of the pipeline with consideration of continuing ground movement and assisted Husky with decisions over the long-term strategy for pipelines in the south slope of the North Saskatchewan River. The companion paper presents the findings of the geotechnical monitoring.

Papers

International Pipeline Conference 2020

You are here:

Pipeline Construction

Gathering Pipelines

Feeder Pipelines

Transmission Pipelines

Distribution Pipelines

Processing & Storage

Papers

Paper 1

How do I ensure ‘Staff Competency’ in my Pipeline Safety Management System?

Abstract

Paper 1

Paper 2

Judge Me By My Size Do You? Or How Reliable Are Dent Assessments Based on ILI Data?

Abstract

Paper 2

Paper 3

Pipeline Depth of Cover – Can you demonstrate compliance?

Abstract

Paper 3

Paper 4

Leak Rate Testing of a Natural Pipeline Defect

Abstract

Paper 4

Paper 5

Preventing girth weld failure in large diameter pipelines: measurement of loads and application of assessment methods

Abstract

Paper 5

Paper 6

Now You SCC Me, Now You Don’t – Using Machine Learning to Find Stress Corrosion Cracking

Abstract

Paper 6

Paper 7

In-line MFL Inspection in Low Pressure Gas Distribution Networks

Abstract

Paper 7

Paper 8

A Cross-Sectional Study on the Prevalence of Corrosion in Pipelines

Abstract

Paper 8

Paper 9

Concerted, computing intense novel MFL approach ensuring reliability and reducing the need of dig verification

Abstract

Paper 9

Paper 10

Managing the Threat of Selective Seam Weld Corrosion using a State of the Art ILI System

Abstract

Paper 10

Paper 11

MAOP reconfirmation for a 20 inch Gas Pipeline using the ECA Approach and Enhanced ILI

Abstract

Paper 11

Paper 12

Getting To Know Your Bends to Support SCC Management

Abstract

Paper 12

Paper 13

The North Saskatchewan River Valley Landslide - Slope and Pipeline Condition Monitoring

Abstract

Paper 13