1/2025 Pipeline Technology Journal Inspection & Integrity MFL Data Fusion: Enhancing Pipeline Integrity by Reducing Conservatism and Increasing Certainty Effective Risk Management through Precise Culvert Surveying using CMI The Rising Share of LNG in the European Market, a Gradual Shift from the Gas- eous State to the Liquid State Innovative Solutions for Decarbonization of a Subsea Pipeline Network CSE – PreFerenceE: A PIMS tool for assessing the Threat by Third-Party Damage Nonmetallic Pipelines in Coarse Slurry Services: Challenges and Lessons Learned www.pipeline-journal.net e-ISSN 2196-4300 / p-ISSN 2751-1189

Pipeline Technology Journal - 1/2025 editorial Adrian Lim Independent Consultant Member of the ptj Editorial Board Inspection & Integrity Welcome to the first edition of the Pipeline Technology Journal (ptj) for 2025. As we begin this new year, our focus is on a core aspect of our industry: safety. Safety is both the foundation and driver for inspection and integrity man- agement in our pipeline industry which aims to mitigate loss of containment (LOC) events. History is peppered with incidents, both catastrophic and minor, across various assets and industries where neglecting integrity manage- ment and risk-based inspection (RBI) has led to severe consequences, in- cluding loss of life and environmental damage. These consequences are also relevant to the energy transition. In this preface, I want to highlight the 'not so catastrophic' incidents. An accumulation of these incidents throughout an asset's life may indicate poor integrity management and inspection practices, inadequate design, deficient organizational safety culture, poor ‘housekeeping’ or all of the above! Akin to the concept of fatigue life, continued neglect may increase the risk of a LOC event. Often, the details of such incidents reveal corporate lessons that should be promptly addressed. As the saying goes - 'we should not tempt fate,' especially when consist- ent 'bad actors' like human factors or similar failure modes regularly appear for any given pipeline (or company!). The integrity and inspec- tion engineering industry has many tools at its disposal to mitigate LOC events. At ptj, we aim to provide insights into how some existing and emerging tools can be used to offer fresh perspectives on pipeline health with the aim to prevent LOC events. This edition explores some of these tools, including wear monitor- ing technology for slurry pipelines and reducing the carbon footprint of integrity management efforts. Additionally, recent case studies in culvert inspection using Current Magnetometry Inspection (CMI), are featured. Trust you’ll find this edition enjoyable and informative, offering a glimpse into the latest technology and trends in inspection and integrity management. Sincerely Yours, Adrian Lim Independent Consultant Member of the ptj Editorial Board

Pipeline Technology Journal - 1/2025  www.pipeline-journal.net  Pipeline Technology Journal - ptj 42 CSE – PreFerenceE: A PIMS tool for assessing the Threat by Third-Party Damage T. Bastek, J. Schmidt 46 Nonmetallic Pipelines in Coarse Slurry Services: Chal- lenges and Lessons Learned S. W. Moon, S. Chiovelli 56 64 75 Empowering Women: The Path to Leadership & Success Stories with a Focus on Men as Mentors G. Brandin, J. Ruppert, U. Berbuir Leveraging Destructive Test- ing to Enhance Detection and Identification of Complex Cracking in LF-ERW; Case Study Phase II J. Aymerich, S. Pipatpan, T. Haro, S. Urrea, A. Hensley, C. Newton Future-Proofing Pipeline Operations: Advancing Vibro- acoustic Technology Through Innovative Digitalization and Enhanced Detection of Multiple Phenomena I. Gargione, F. Chiappa, A. Gomes FEATURE PAPER OF THE GLOBAL WOMEN FORUM (GWF) THE J.N.H. TIRATSOO COMMEMORATIVE WHITEPAPER Young Pipeliner

Pipeline Technology Journal - 1/2025 9 20th Pipeline Technology Conference Unveils Expanded Technical Program and New Highlights The Pipeline Technology Conference (ptc) is set to mark its 20th anniversary with a milestone edition that promises an enlarged technical program and dynamic new features. Taking place from 5-8 May 2025 at the Estrel Congress Center in Berlin, ptc 2025 will present 150+ technical presentations arranged into 48 dedicated sessions, positioning itself as global pipeline event where pipe- line operators and experts from around the world convene to ex- change ideas, solutions, and visions for the future. A broader range of topics will ensure that delegates gain deeper insights into cutting-edge developments. From hydrogen inte- gration, inline inspection, offshore infrastructure, CO₂ transpor- tation, leak detection, and control room management to climate adaptation and methane reduction strategies, ptc 2025 covers the entire spectrum of challenges and opportunities shaping the global pipeline landscape. With digitalization and artificial intelligence taking center stage, participants can expect for- ward-looking discussions on how advanced technologies are re- defining safety standards, enhancing operational efficiency, and ensuring regulatory compliance. Read the full article here: https://www.pipeline-journal.net/news/20th-pipe- line-technology-conference-unveils-expand- ed-technical-program-and-new-highlights Read more pipeline news: https://www.pipeline-journal.net/news

Pipeline Technology Journal - 1/2025 PTJ Insights 11 1. Introduction Millions of kilometers of high-pressure pipelines span the globe transporting energy in the form of fluids such as oil, refined products and gas, and are a global critical infrastructure. Transport must be reliable, safe and effi- cient, and ideally without interruption at any time. Pipelines are the arteries of the global energy infra- structure and as such are extremely valuable because: • large amounts of funds are required to plan, de- sign, build operate and maintain them, • they are essential in the security of energy supply, • they constitute the safest means to transport very large quantities of fossil fuels today and in addi- tion future fuels in the years to come and, • in many cases they cannot be replaced. Pipelines are pressurized systems and the internal and external loads they experience induce mechani- cal stresses in the pipe wall. Accordingly, pipelines are designed to specifications, and safety factors are ap- plied during calculating design pressures and required wall thicknesses. Throughout its operational life a pipeline is subject to a variety of threats. Some are time-independent, such as third-party mechanical interference where a pipeline is inadvertently impacted and damaged. Others are time-dependent threats such as corrosion. The most common material used for line pipe is steel and over time degradation processes (e.g., internal and exter- nal corrosion) can create defects that threaten the me- chanical integrity of a pipeline. Pipelines are typically protected by an external coating often supported by a second layer of defense, namely ca- thodic protection (CP). But coatings deteriorate, and CP may sometimes be faulty, which means that defects af- fecting the integrity of the pipeline can occur and grow. The dangerous thing about defects in the steel wall, is that they can lead to local stress peaks exceeding the load bearing capabilities of the pipe material. This can in the worst-case lead to failure. Consequently, we need to find these defects and assess if the pipeline is still ‘fit for purpose’. Table 1 provides a high-level overview of typical poten- tial pipeline defects. The table refers to defects affect- ing the pipe wall, defects in the coating which either prevent the coating from protecting the pipe or defects which impact the effectiveness of the cathodic protec- tion (CP). In the case of CP the table refers to the system not running with correct parameters to prevent corro- sion from taking place. Table 1: High Level Overview of Potential Defects in Pipelines

Pipeline Technology Journal - 1/2025 PTJ Insights 13 So, let us remember: In order to complete a defect as- sessment, we need input relating to all three corners of the integrity triangle: defect geometry, acting loads and material characteristics. 4. Looking for defects As mentioned, the initial ILI tools commercially avail- able were designed to identify defects in the pipe wall and collect accurate data regarding their geometries and location. Different physical principles or rather different non-destructive testing techniques were in- vestigated and then used in ILI tools. The following table provides an overview of the most widely used techniques. Table 2 only refers to defect identification. Non- destructive testing techniques are also being applied for material characterization and loading identifica- tion mentioned later in the paper. The term ID/OD used in the table refers to distinguish- ing internal and external defects. Each of the physical principles utilized in those tech- niques comes with its own particular strength and weakness. Basically, we need to understand that there is no one physical principle which excels over all the others in detecting and sizing a given defect. That is one of the reasons why different techniques are used. But there are more reasons. More information on the physical principles and inspection techniques utilized in ILI tools can be found in [3]. ILI tools are “mechatronical” systems (a combination of mechanical and electrical engineering). They con- sist of sensors making use of a chosen physical princi- ple in order to identify and size defects. They require electronics to control the sensors, more electronics to handle the inspection data, storage devises for that data to be recorded safely, an energy supply and finally a means of propulsion. The sensors must somehow get to the point of interest in the pipeline and take the measurements they are supposed to take. Let me use the following tables to introduce some important as- pects of tool design. The choice of sensor technology is influenced by the following parameters, see Table 3. Table 2: Different Non-Destructive Techniques utilized in ILI tools for identifying defects.

Pipeline Technology Journal - 1/2025 PTJ Insights 15 Figure 2: Schematic of a Free Swimming Tool flow of the fluid being pumped through the pipeline and does not require its own drive. It was not long however, that the need arose to also in- spect pipelines which could not be inspected with these available “free swimming” tools, at least not without significantly modifying the pipeline or the tool. Some of these more challenging pipelines (e.g. no launchers or receivers, significant internal diameter changes, very tight bends etc.) were also in the onshore sector, but off- shore pipelines come with their own set of challenges. This was the time when the expressions “piggable” and “non-piggable” were started to being used. Explaining all the details of piggable versus un-piggable would go a bit far in this article, further information can be found in [4]. One important element is tool propulsion: • • ILI technology has developed and today we have ILI tools for the piggable pipelines which the industry calls traditional pipelines; and, also those ILI tools which can still inspect the pipe- line from within, although formerly considered un-piggable. Figure 3: Piggable versus Unpiggable These latter lines are today referred to as Challenging Pipelines or Difficult to Inspect Pipelines. Figure 3 shows an overview regarding this segmentation. Figure 4 shows the various forms of propulsion we have available today, where crawler tools, also referred to as robotic tools and tethered tools are specially designed for the inspection of Challenging Pipelines.

Pipeline Technology Journal - 1/2025 PTJ Insights 17 Table 5: Types of ILI tools commercially available today. the pipeline is elongated or compressed. There are two types of tools that can help here. Bending strains can be identified by using tools which were originally de- signed to measure the centerline of the pipeline. These tools are often referred to as Mapping tools. There are different generations of these tools, the first of which were developed in Canada over 30 years ago. They uti- lize Inertial Measurement Units (IMU´s). Depending on the resolutions required and the bias accept- able modern versions of these tools make use of mi- cro-electromechanical systems (MEMS) or fibre-optic gyroscopes (FOG). But there is also a need to identify axial strains, especially regarding their effect on girth welds. Today there is a special range of tools, also using specially adapted electro-magnetic sensors to identify such axial strains. True local stresses, especially when additional residual stresses come into play can be com- plex and being able to identify them is something the ILI industry is working on. 6. Conclusions Well, from the initial goal of detecting and sizing defects in the pipe wall, ILI tools have come a long way provid- ing inspection capabilities for all three corners of the in- tegrity triangle. Table 5 provides an overview of the vari- ous types of ILI tools commercially available today. And the future has only just begun. The ILI industry is busy developing new technologies and tools which will find their way into new inspection services being offered.I hope that I could share a little of my enthusiasm for the ILI industry and provide an introduction into how these exciting tools help to manage pipeline threats. Further information on the developments in ILI technology and the experience gained with these tools can be obtained through papers presented at the various pipeline con- ferences around the globe, papers published in techni- cal journals, such as the Pipeline Technology Journal or a variety of books related to pipelines, pipeline inspec- tion and defect assessment. Further sources of informa- tion are included in the references [5]. References 1. P. Hopkins, “Defects in Pipelines and their Assessment”, PTJ Insights, Pipeline Technology Journal 1 (2024) 2. M. Kirkwood, “Bats, Bees, Snakes, Octupuses, and Pigs!”, PTJ Insights, Pipeline Technology Journal 3 (2024) 3. Managing Pipeline Threats, Edited by John Tiratsoo, Clarion and John Tiratsoo Technical, 2019 4. Beller, M., Steinvoorte, T., Vages, S., Mastering the Inspection of Challenging Pipelines, Part 1 and 2, Pipeline & Gas Journal, Oildom Publishing, October and November, 2015 5. Oil and Gas Pipelines, Integrity and Safety Handbook, Edited by Winston Revie, John Wiley & Sons, 2015 6. Pipeline Integrity Assurance – A Practical Approach, edited by M. Mohitpour, A. Murray, M. McManus, I. Colqhoun, ASME-Press, 2010 7. Pipeline Pigging and Integrity Technology, 4th. edi- tion, ed. John Tiratsoo, Tiratsoo Technical Author Dr. Michael Beller ROSEN Group Director Global Market Strategy mbeller@rosen-group.com

Pipeline Technology Journal - 1/2025 RESEARCH • DEVELOPMENT • TECHNOLOGY 19 1. Introduction Pipeline operators have traditionally relied on MFL-A and MFL-C tools for corrosion detection. While these technologies are effective, their unidirectional mag- netic fields limit their ability to detect anomalies aligned with the direction of the applied field. For ex- ample, MFL-A struggles to accurately identify axial metal loss, while MFL-C faces challenges in detecting circumferential anomalies. These limitations often lead to incomplete or conflicting data, complicating in- tegrity assessments and increasing operational costs. profile. This approach improves anomaly characteri- zation, reduces conservatism in reporting, and enables more informed integrity management decisions. 2. MFL Data Fusion: A Technological Breakthrough Data fusion maximizes the value of MFL datasets by miti- gating the physical and procedural limitations of traditional methods. Integrating MFL-A and MFL-C data delivers a de- tailed 3D depth profile of the pipeline surface, offering un- precedented insights into corrosion morphology. To address these issues, operators frequently inspect pipelines using both MFL-A and MFL-C tools. However, analyzing these datasets separately introduces subjec- tivity and ambiguity, often requiring additional testing to resolve conflicting results. This approach increases costs and delays decision-making. MFL Data Fusion provides a solution by integrating MFL-A and MFL-C datasets into a unified 3D depth 2.1 The Technology The fusion process begins with collecting and qualifying MFL-A and MFL-C datasets. These datasets are then re- fined to remove noise and signal aberrations, ensuring high-quality input for the fusion process. A pre-trained Convolutional Neural Network (CNN) aligns and merges the datasets using specialized U-Net architecture algo- rithms. The result is a high-resolution 3D depth profile that rivals the accuracy of in-ditch UT scans (e.g., laser scans). Figure 1: Training data set example – MFL-A and MFL-C signals are simulated from the laser scan Figure 2: Example of fusion data (prediction) vs. Laser scan data

Pipeline Technology Journal - 1/2025 RESEARCH • DEVELOPMENT • TECHNOLOGY 21 digs. The fusion system's improved depth accu- racy reduces this conservatism, minimizing the number of digs while ensuring high-risk anoma- lies are identified. 2. Increase First-Run Success: The system's ability to enhance each recorded MFL-A and MFL-C data during fusing and accurately characterize anoma- lies reduces the likelihood of missed or misclassi- fied features. This increases the probability of first- run success during inspections, reducing the need for repeat runs and associated costs. 3. Optimize Dig Programs: The fusion system pro- vides detailed 3D depth profiles, enabling oper- ators to prioritize digs based on accurate risk as- sessments. This optimizes resource allocation and reduces operational costs. 4. Leverage Complementary Data: Integrating MFL-A and MFL-C datasets ensures that no anomalies are missed due to their orientation or morphology. This dual-data approach provides a more compre- hensive understanding of pipeline integrity, en- hancing the reliability of inspection results. 8. Conclusion MFL Data Fusion represents a significant advancement in pipeline inspection technology. By combining the strengths of MFL-A and MFL-C datasets, the system addresses the limitations of traditional unidirectional MFL tools, providing more accurate and comprehensive anomaly characterization. The system's ability to reduce digging costs, increase first-run success, and optimize dig programs makes it a practical solution for pipeline operators. Its validation using API STD 1163 Level 3 methods ensures high relia- bility, while its integration of advanced neural networks and big-data management sets a new standard for pipe- line integrity management. Future developments will focus on expanding the sys- tem's capabilities to address a broader range of pipeline threats, further enhancing its value to the industry. Figure 4: River bottom profiles of Laser, Data Fusion and Box data (Source: ROSEN Group) 6. Integrity Applications The MFL Data Fusion system offers several advantages for pipeline integrity management: • Accuracy: Improved depth accuracy reduces un- necessary digs and enhances safety. • Certainty: The system's high confidence levels minimize the risk of mischaracterizing anomalies. • Consistency: Automation reduces reliance on human judgment, ensuring objective and con- sistent results. • Reliability: Dual data collection from MFL-A and MFL-C ensures no anomalies are missed due to orientation. 7. Operational Benefits The primary advantage of MFL Data Fusion lies in its ability to reduce digging costs and increase the effi- ciency of integrity management programs. By provid- ing more accurate and comprehensive anomaly char- acterization, the system enables operators to: 1. Reduce Unnecessary Digs: Traditional MFL meth- ods often require conservative depth margins to account for uncertainty, leading to unnecessary

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Pipeline Technology Journal - 1/2025 RESEARCH • DEVELOPMENT • TECHNOLOGY 25 1. Background In the past century, thousands of kilometers of pipe- line networks for transporting gases and liquids have been laid worldwide. Culverts, which enable crossings of roads, railways, cables, or other pipeline routes, as well as water bodies, are an essential component of these pipeline networks. The special location of cul- verts often leads to enormous effort and costs in the event of pipeline failure, for example, at busy roads or to increased environmental risks near bodies of water. In flowing water bodies, scouring of the riverbed and banks can occur over time. If the pipeline is displaced, e.g., due to uplift, there is also a risk that the overly- ing material will be washed away. Both effects lead to a reduction in the DoC, even potentially exposing the pipeline. Water bodies with active shipping represent a particular risk. Here, external factors such as protec- tion against anchors or chains must be accounted for with sufficient coverage. When it comes to pipeline exposure, the risk for un- stable positioning increases, alongside with the risk of sediment collisions. Furthermore, local dynamic stresses caused by currents or shipping traffic increase the risk of deformation. This can lead to changes in the fracture mechanics of pipelines, increasing the risk of pipeline failure. The effort requiered for restoring the necessary mini- mum DoC varies depending on the required measures. Simple backfilling with suitable material can provide short-term remedy but is often not permanently effec- tive due to erosion and currents. Further erosion pro- tection measures, such as stone or concrete mats, or re- inforcement of pipelines, require construction below the water surface and involve high costs and planning effort. If these measures are insufficient, relocating the pipeline may be necessary, which is the most ex- pensive and labor-intensive solution. Especially for pipelines under water bodies, failure can have severe ecological consequences depending on the transported medium. Therefore, the technical regulations of the DVGW [1,2] recommend regular in- spections of the DoC at intervals of 2–10 years, depend- ing on external conditions. 2. Current status to determine the DoC of pipelines crossing water bodies Common methods for locating buried pipelines in- clude ground-penetrating radar (GPR), acoustic, or seismic methods. These methods are based on a sim- ilar principle: a signal (acoustic or electromagnetic waves) is emitted into the ground and reflected by ge- ological layers and objects. The reflected signals are then used to determine the position and coverage of pipelines. However, the effectiveness of these inspec- tion methods and the penetration depth of the signals are highly dependent on the nature of the subsurface. For example, with GPR, penetration depths of only up to 1 meter can be expected in wet clay, which is often found at the bottoms of water bodies [3,4]. The interac- tion of different soil layers, such as at riverbanks, can also lead to significant uncertainties in determining the correct location and DoC [3,5]. As a result, making reliable statements about the precise location of bur- ied pipelines and their DoC are often not possible. Another method involves detecting ferromagnetic pipelines through magnetometry in the Earth's mag- netic field. Under favorable conditions, it is possible to locate pipelines buried several meters deep and deter- mine their coverage. However, the magnetic fields are not applied under controlled conditions during the in- spection, which makes the measurement dependent on external factors such as the global orientation of the pipeline and the associated pre-magnetization or inter- ference from external influences from the environment. Additionally, for pipelines at greater depths, the result- ing measurable magnetic field is correspondingly small (Figure 1), requiring measurements in grid fields. The influence of external factors and the challenging han- dling of the large datasets produced make the evalua- tion of these measurements demanding. This contrib- utes to the fact that classic magnetometry has not yet been used as a common method for locating pipelines. To balance the risk posed by insufficient cover against the massive expense of a remedial measure, accurate and reliable inspection data is essential. However, the methods described above often fail to provide such re- liable information for water crossings or are burdened with significant uncertainties.

Pipeline Technology Journal - 1/2025 RESEARCH • DEVELOPMENT • TECHNOLOGY 27 Figure 2: Exemplary representation of a pipeline in XY view with the magnetic field vectors; in addition, the depth of cover of the pipeline and the absolute height profile of the waterbed are indicated by the color scaling Figure 3: Schematic diagram of the inspection setup with the CMI boat as the inspection unit the distance of the pipeline from the inspection system at any given moment. Additionally, during the inspection, the distance of the measuring systems to the terrain surface is recorded using lidar, sonar, or radar systems, as well as the sys- tem's orientation (e.g., inclination). This makes CMI the most precise inspection system globally for 3-di- mensional position determination, even for com- plex geometries. This level of precision also allows for seamless and reliable DoC assessments of buried pipe- lines, regardless of the terrain. For the inspection, a combination of at least four fre- quencies in the range of 2 to 2,000 Hz is applied to the pipeline. These frequency ranges are virtually unaf- fected by soil layers, unlike the frequencies used in GPR, for example. Moreover, using multiple frequen- cies allows to distinguish the pipeline from external structures, which is a major advantage over magnetic field measurements in the DC field. Furthermore, the use of alternating current enables inspections to be conducted without interrupting the pipeline opera- tion. Cathodic protection (CP) systems can also con- tinue to operate normally during the measurements. In general, the CMI measurement equipment consists of three components: the signal generator (SG), the in- spection system, and an intelligently connected data system. The setup during the inspection is schemati- cally illustrated in Figure 3. The signal generator (SG) is connected to the pipeline via galvanically connected elements (e.g., CP measure- ment posts, valves, or rectifier systems) and is respon- sible for the safe and reliable provision of the inspec- tion current. Intelligent optimization processes are used to match the inspection current to the local elec- tromagnetic and geometric conditions. This makes the inspection independent of external AC and DC in- fluences, enabling the inspection of pipelines heavily influenced by external currents.

Pipeline Technology Journal - 1/2025 RESEARCH • DEVELOPMENT • TECHNOLOGY 29 Figure 5: Left: Crossing of the pipeline route with the canal; the coloring of the pipeline correlates to the indicated DoC at the respective position. Right top: Terrain, water surface and pipeline profile over the length; the dashed line indicates a theoretical DoC of 2 m, which was specified as the minimum cover for a GPR inspection. Below: Course of the DoC over the length of the pipeline; colored are areas with inadequate DoC (<0.8 m or <0.6 m) reaching up to approximately 3 m. The situation is dif- ferent in the section where the pipeline crosses the canal. Here, the DoC falls well below 2 m. In the yellow-colored area (approximately 5 m wide), the DoC is less than 80 cm, while in the red-colored area (approximately 1 meter wide), it is less than 60 cm. These results of insufficient coverage align with the controls performed by the opera- tor. Accordingly, the CMI enabled a precise culvert survey, met expectations, and provided essential information for the operator's risk management. 4.2 Case 2: Verification of DoC in an actively navigated canal In the second case, the pipeline crosses a canal actively used for shipping. The canal is approximately 55 m wide, with a water depth exceeding 4 m at the time of inspection. The waterway accommodates large motor cargo vessels of up to 2,000 t and push convoys with lengths of 185 m, weights of 3,500 t, and drafts of 2.8 m. This poses an increased risk of damage to the pipe- line from external factors such as anchors or chains. Additionally, dynamic mechanical stresses caused by shipping, changes in water levels, currents, and asso- ciated sediment displacement can burden pipelines that are inadequately protected or have insufficient DoC. These risks necessitate precise location methods and regular monitoring to ensure the long-term safety and integrity of pipelines under water. Accordingly, the inspection focused on the middle of the waterway with shipping traffic. Despite a distance of up to 10 m between the pipeline and the inspection system, the pipeline was success- fully located, and the DoC was reliably determined. The pipeline route in the inspected area, along with the terrain cross-section over the pipeline length showing the ground surface, water surface, and riverbed, is il- lustrated in Figure 6. The DoC profile is represented by the color scale in the Figure. Inspection results show that, in the central part of the canal the pipeline had sufficient coverage exceeding 5 m in large areas. The pipeline rises towards the edges of the canal, but was also adequately protected by the soil here with a cover of >4 m. Additionally, Figure 6 shows pipeline bends greater than 2° as combined bends (combined vertical and horizontal components) and corresponding bend radii. In the inspected section, no major bends exceeding 10° were detected. The bend radii, all greater than 200 D, pose no restrictions for further condition assessments, such as those using in- line inspection technology. Overall, at the time of inspection, due to sufficient DoC, the risk of damage to the pipeline from external factors was deemed low, ensuring safe operation alongside ac- tive shipping.

expectations. In the cross-section, the pipeline main- tains a depth of cover between 1.7 and 2.2 m across a wide area of the river. Towards the eastern edge of the water body, the pipeline rises more steeply than the riverbed, resulting in a reduced DoC. However, as the pipeline approaches the riverbank, it levels out, en- suring a minimum DoC of 83 cm, with no sections fall- ing below the critical threshold of 80 cm (according to German regulations). Given the shallow water depth and limited shipping activity in this section of the river, no special regula- tions regarding DoC apply. Therefore, sufficient cover- age was ensured throughout the inspected area at the time of inspection. Overall, EMPIT GmbH was able to provide compre- hensive information about the pipelines in the rele- vant areas for all inspections conducted. Both the ab- solute position and the DoC, on land and under water, were determined in a single inspection run. The re- sults were digitized and partially validated through ex- posure and manual probing. The measurement speci- fications outlined above were fully complied with. As a result, introducing the the CMI technology has made it possible, for the first time, to obtain precise and re- liable results for culvert surveys. These results are in- dependent of external factors or soil conditions. The information obtained through CMI thus makes an es- sential contribution to effective risk management for pipeline operators. References 1. DVGW-Arbeitsblatt GW 304 „Rohrvortrieb und verwandte Verfahren“ (2008-12) 2. DVGW-Arbeitsblatt GW 315 „Maßnahmen zum Schutz von Versorgungsanlagen bei Bauarbeiten“ (2020-01) 3. K. Zajícová et al.Application of ground penetrating radar met- hods in soil studies: A review, Geoderma, Volume 343, S. 116- 129, 2019, https://doi. org/10.1016/j.geoderma.2019.02.024. 4. H. M. Jol: Ground Penetrating Radar Theory and Applications Elsevier Science, 2009, https://doi.org/10.1016/B978-0-444-53348-7.X0001-4 5. P. Kearey et al.: An introduction to geophysical explora- tion, Blackwell Science Ltd, 2002, ISBN 0-632-04929-4 Pipeline Technology Journal - 1/2025 RESEARCH • DEVELOPMENT • TECHNOLOGY 31 AuthorS Jakob Stumme EMPIT GmbH Research Associate jstumme@empit.com Mark Glinka EMPIT GmbH Managing Director glinka@empit.com Kay Peschke Avacon Netz GmbH Engineer Operations Management High Pressure Gas kay.peschke@avacon.de

Pipeline Technology Journal - 1/2025 RESEARCH • DEVELOPMENT • TECHNOLOGY 33 1. The rising share of LNG in the European market In 2021 the share of LNG in natural gas imports of Europe was only 20 %. Sufficient deliveries through pipelines were maintained and ensured, even with a very competitive prices. Russia was dominating the li- on’s share by 40% estimated at 137bcm. Things quickly changed and with a rapid pace the liquid chilly mol- ecules started to replace the gaseous ones. Gradually along weeks and months it spiked to 41% of the total European imports by 2023. This lead to the construction of several LNG infrastruc- tures, including the FSRUS, as Germany was leading this shift. Germany was hugely reliant on natural gas supplies especially through the Nord Stream pipe- lines and the shift required huge investments in a very short period of time. The US is ensuring a smooth transition phase through the delivery of LNG via ship. The amount of shipments is still rising every day and will intensify in the future as the flow of gas through Ukraine is interrupted. 2. The Role of the US to fill up the gap left by the piped Gas In the last few years the United States have emerged as the big player in the global natural gas production and became the largest producer with estimated 1080bcm in 2024. This allows it to hold 25% of the world’s share. These considerable volumes allowed the US to be the a save supplier for many European countries. Using a strong and active fleet of vessels crossing the Atlantic ocean to ramp up supplies to a thirsty market which is looking for sustainable alternatives and for 2 main reasons: 1. Diversify the suppliers with more trusted sources even with high prices. 2. High cost will encourage many governments to make renewable energy sources more competi- tive and will open the door for more investment. To be energetically independent, the share of energy produced using renewable sources is incredibly spik- ing in some European countries. In Germany the elec- tricity generated from renewables exceeded 62% by 2024. This is a record and obviously showing the re- sult of these investments. At the same time we have to highlight that natural gas is still playing a crucial role in many industry sectors, especially in petrochemistry and the production of fertilizers. As the volatility and jumping prices have impacted many firms it still is the backbone for many specific industries. Natural gas prices hovered 50 €/mwh over a period of time as the result of extreme weather conditions. Once again natural gas was the immediate energy provider, while wind energy was not delivering the expected outputs. It dropped by 25 % in a year in Germany. Taking this into account it becomes clear that renew- ables are vital for the future. Energy transition to re- newable sources has the advantage of low carbon emissions and sustainability. On the other hand natu- ral gas will remain the cleanest among the fossil fuels. Combining renewables and natural gas would hugely contribute to reach future targets and secure energy supplies. 3. The Economic impact of the shift from Piped gas to LNG Piped Natural gas is directly transported in its gaseous state through pipelines over long distances, especially between countries and continents (Africa-Asia). This only requires compression stations in order to push the gas from point A to point B and it will be directly consumed by the end user. LNG requires a different process which is more costly as it requires more energy. Making liquid natural gas needs specific equipment and requires complex meth- ods. The temperature has to be dropped to -162° Celsius which absorbs more energy and carbon emissions. These chilly substances have to be pumped to specially insolated vessels which transport the LNG of long dis- tances. At arrival the liquified gas is pumped to regas- ification units to return it to its natural gaseous state. Back in 2021 the share of natural gas entering to the European Union was bigger. The gas was transported over shorter distances and did not require regasifica- tion. As a result the use of natural gas was more eco- nomical. Now this share is narrowing as LNG is gradu- ally taking a bigger share of the market. As a result of

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Pipeline Technology Journal - 1/2025 RESEARCH • DEVELOPMENT • TECHNOLOGY 37 1. Introduction Subsea pipelines such as in-field flowlines, trunklines, test lines etc. are an integral part of all offshore field de- velopments. In line with the current efforts under the global focus area of decarbonization, the CO2 emission reduction from subsea pipelines is also an area of great interest. This paper presents innovative solutions for decarbonization of a subsea pipeline network which will ensure significant carbon footprint reduction from all phases of subsea pipeline entire life cycle i.e. design, construction and operation. The various decarboniza- tion measures required to achieve low carbon intensity from offshore oil and gas production pipelines are out- lined in Figure 1. 2. Lower Carbon Field Developments Lower carbon field developments are vital for decar- bonization and the heart of these developments are the innovative solutions which can lead to design op- timizations and thereby can significantly reduce off- shore works during the construction phase of the project. The identification and implementation of in- novative solutions for subsea pipelines has been pre- sented in previous publications [1-3]. The first case study for lower carbon field develop- ments is the optimization of cladding requirements for gas field trunklines. Sour service conditions as en- countered by production pipelines of gas fields require CRA clad pipe due to high risk of localized corrosion in- itiation and penetration rate in carbon steel. However, as cladding costs are very high especially for large di- ameter trunklines, therefore, any means to reduce the cladding requirements of subsea trunklines are eco- nomically attractive. This case study presents an inno- vative approach to optimize cladding requirements of subsea trunklines of an offshore gas field development. This approach involves removal of concrete coating from the in-field flowlines as well as from the cladded section of trunklines for enhancing the fluid cooling. As trunklines were required to be cladded only up to the length where fluid temperature was above 120 ºF (and internally FBE coated elsewhere), the cladding length of each subsea trunkline was significantly re- duced as compared to concrete coated case. The tem- perature limit of 120 ºF for internal FBE coating was established to ensure coating integrity under given sour service conditions. The impact of removal of con- crete coating on flow assurance, pipeline mechani- cal design, cathodic protection and field joint coating systems was also evaluated. Although some of these Figure 1: Decarbonization Measures for Subsea Pipelines

Pipeline Technology Journal - 1/2025 RESEARCH • DEVELOPMENT • TECHNOLOGY 39 Figure 2: Diverless Subsea Excavation and Concrete Removal (Courtesy of Scanmudring AS) In shallow waters, subsea pipeline repairs are typically performed by depressurizing the pipeline, mobilizing repair vessel/s and divers performing a number of ac- tivities including seabed excavation, concrete coating removal, surface preparation, UT measurements to locate/verify defect, installation of repair fitting and supports as required. To achieve decarbonization, di- vers can be replaced with ROVs/Robots. To perform diverless seabed excavation, advanced construction excavators converted into cutting-edge ROVs can be used. The Scanmachines can handle all types of sea- bed types ranging from loose sand and bedrock types (>200MPa) and water depths from 0-3.000 meters. These subsea excavators have effective functionality offering flexibility, power and precision subsea oper- ations. After excavation, diverless concrete removal tool can be used to remove concrete weight coating on the pipeline as shown in Figure 2. Concrete removal tools are also available with full electric option i.e. no emissions from the equipment. Other benefits of di- verless concrete removal tool include faster concrete removal rates, safer than divers and less vessel time and emissions. Another technology which can help to reduce carbon footprint during repair is digital robotic repair sys- tem which is launched from the vessel for the repair of subsea pipeline defects with minimal human interven- tion (Figure 3). This technology can remotely perform anti corrosion coating removal, defect sizing, surface cleaning/preparation, coating application, leak re- pair and carbon fiber application. This repair method does not require pipeline shutdown, requires mobili- zation of a low spec vessel which further decreases CO2 Figure 3: Digital Robotic Repair System (Courtesy of Kongsberg Ferrotech) emissions. Other benefits of robotic composite repair system include improved safety, reduced repair time and repair cost. The free spans along subsea pipelines are typically rec- tified using grout bags or stacked concrete mattresses. These rectification measures contribute to the green- house emissions and having a polymeric solution yields light weight maintenance free service life. Consequently, world’s first glass reinforced plastic (GRP) supports for subsea pipeline free span corrections (Figure 4) have been developed. The key benefits associated with the

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Pipeline Technology Journal - 1/2025 RESEARCH • DEVELOPMENT • TECHNOLOGY 43 1. Third-Party Interference Third-party interference—primarily construction-re- lated damages—remains a major challenge in gas pipe- line infrastructure [1]. Human errors often result in con- struction equipment operators being unaware of the exact pipeline location [2]. The forces exerted by such equipment frequently exceed the resistance capacity of standard pipelines. The risk is significantly elevated in densely populated areas due to the higher potential im- pact of released gas, increased construction activities, and a greater likelihood of ignition sources. To ensure the safe operation of pipelines, measures must be defined to prevent or mitigate third-party interference according to the risk level. These measures should be in- tegrated both during the planning phase and through- out the operational lifecycle within the Pipeline Integrity Management System (PIMS). CSE PreFerenceE serves as a specialized component within PIMS, offering the most precise GIS-based analysis of construction-related threats while simultaneously recommending appropri- ate mitigation strategies. data analysis, the probability of construction-related damages is quantified with maximum resolution. This provides a solid foundation for risk evaluation, allowing for the systematic implementation of conventional op- erational risk-reduction measures based on event prob- ability and potential consequences (Figure 1). The fol- lowing mitigation measures are incorporated into the program and applied based on the assessed risk: • • Inspection and aerial surveillance planning with defined frequencies Installation of underground warning tape along the pipeline corridor • Additional placement of warning and informational signs Technically more advanced and costly measures may be considered, including: • Installation of protective plates • Increase in pipeline wall thickness 2. Analysis based on Data-Driven Risk Assessment • Modification of soil cover This analysis is based on a comprehensive, data-driven risk assessment that considers the characteristics of high-pressure gas pipelines and the parameterized sur- rounding environment. By leveraging a sophisticated machine learning model combined with detailed GIS 3. High Accuracy of Threat Assessment The high accuracy of threat assessment is crucial for preventive maintenance and operational risk minimi- zation, as precise mitigation planning optimizes both Figure 1: Overview of the CSE-PreFerenceE process for determining operational gas pipeline risks in PIMS.

economic efficiency and safety, thereby enhancing pipeline integrity (Figure 2). The system integrates var- ious datasets, including road networks, land and build- ing usage, topography, protected areas, and internally generated data. By parametrizing the environment at every meter of the pipeline, CSE PreFerenceE ensures robust and precise TPD threat assessment (Figure 3). These data are processed using a highly detailed ma- chine learning model, and the output is employed within the developed Risk Assessment model to de- termine probability of pipeline failure. At CSE Center of Safety Excellence, our mission is to provide digital solutions for pipeline planning, ap- proval, and maintenance processes. CSE PreFerenceE is a specialized analytical tool that enables a data-driven, objective evaluation of third-party interference, mak- ing a significant contribution to the safe and sustaina- ble management of pipeline networks. As an essential component of PIMS, CSE PreFerenceE delivers the most resolved assessment of third-party influences on gas pipeline networks to date, reinforc- ing operational safety and reliability. References 1. EGIG, „Gas Pipeline Incidents - 12th Report of the European Gas Pipeline Incident Data Group“, EGIG Group, Netherland, 12, Sep. 2023. [Online]. Verfügbar unter: https://www.EGIG.eu 2. „DIRT Annual Report for 2021“, Common Ground Alliance, Alexandria, 2022. 3. „Geofabrik Download Server“. Zugegriffen: 7. Februar 2025. [Online]. Verfügbar unter: https://download.geofabrik.de/ Pipeline Technology Journal - 1/2025 RESEARCH • DEVELOPMENT • TECHNOLOGY 45 AuthorS Tim Bastek CSE Center of Safety Excellence Process Safety Engineer tim.bastek@cse-institut.de Jürgen Schmidt CSE Center of Safety Excellence Excecutive Director & Institute Leader juergen.schmidt@cse-institut.de Company Directory "The database for the pipeline industry" GROUP

Pipeline Technology Journal - 1/2025 RESEARCH • DEVELOPMENT • TECHNOLOGY 47 1. Introduction Canada's oil sands represent a vast reservoir of hydrocar- bons, ranked third globally behind Venezuela and Saudi Arabia, as reported by Worldometer as of November 14, 2024 [1]. Oil sands are an in-situ mixture of bitumen, sand, clay, and water. Because the highly viscous bitumen does not flow well, it must be mined (surface mining) or heated underground (in-situ production) before it can be processed. According to the Canadian Association of Petroleum Producers (CAPP) [2], approximately 20 per- cent of Canada's oil sands lie sufficiently close to the sur- face to warrant surface mining. A simplified surface min- ing process in oil sands is shown in Figure 1. After mining by large trucks and shovels, the oil sands are crushed and oversized solids (e.g., greater than 5 in.) are removed in screening unit. Alternatively, wet crushing process can be used to achieve zero rejects [3]. Then, oil sands are mixed with warm water and additives to make oil sands slurry, which is transported to an extraction plant through hydrotransport pipelines. Hydrocarbon por- tion called froth is extracted in cone-shaped gravity sep- aration vessels called Primary Separation Vessel (PSV), then become feed to an upgrader to produce a synthetic crude oil. The remaining slurry (mainly sands, clays and water) from PSV is transported to tailings ponds through tailings pipelines. These pipelines are fabricated with large-diameter piping (e.g., 28-32 in. diameter) and each system can be between 5 and 15 kilometers. Due to low material cost and availability, the majority of slurry pipelines are fabricated from carbon steels such as API 5L Grade X65. Steel pipes (typically 50 ft. or 60 ft. length) with plain ends are welded together in the field to make a long straight section. Components requiring frequent maintenance, such as elbows and fittings, are connected via flanged connections or me- chanical couplers. Unlike the conventional oil indus- tries, serious wear issues exist in slurry pipelines in oil sands. High concentration of silica sands (e.g., tar- geting specific gravity of 1.5-1.6) and large rock lumps (e.g., over 5 in. x 5 in.) with sharp edges travel through the pipelines. The target velocity in the slurry pipe- lines is designed to be above the deposition velocity to prevent settling of solids. Operating above the dep- osition velocity ensures a heterogeneous flow, where the denser material flows along the bottom of the pipelines and creates a characteristic wear pattern [4]. As the water in the slurry is warm (40-60°C) and usually saturated with dissolved oxygen, corrosion is also significant in carbon steel pipelines. Many researchers have tried to correlate different op- erating parameters with pipeline wear. Particle shape, particle size, flow velocity, impact angle, target ma- terial properties, and slurry characteristics played a significant role in pipeline wear [5]. Additionally, the aqueous medium used in generating oil sands slur- ries contains considerable amounts of chlorides (e.g., Figure 1. A brief surface mining process in oil sands.

experienced frequent component failures from wear and fatigue damage. Rubber hoses, by dampening vi- brational stress from pump operation, protected hard piping from fatigue damage. One of the most significant advantages of nonmetallic piping products lies in their intrinsic ability to resist cor- rosion. Given that nonmetallic materials act as electri- cal insulators, they can effectively impede electrochem- ical reactions responsible for corrosion. Nevertheless, chemical degradation pathways might still affect non- metallic components. Prolonged contact with process streams over time can lead to gradual degradation of nonmetallic materials. Thus, selecting materials capa- ble of withstanding environmental stressors assumes paramount importance. Additional advantage offered by nonmetallic piping products stems from their su- perior wear performance. Elastomer liners exhibit unique viscoelastic behavior and resilience, permit- ting deformation upon collision with abrasive parti- cles suspended in the slurry. In this material deforma- tion process, considerable amount of kinetic energy can be dissipated and impact particles can be bounced back without causing damage to the liner (Figure 3). Figure 3. Conceptual diagram showing viscoelastic behavior of elastomer liner during impact. Initially, abrasion testing methods used for metal- lic materials, such as dry sand abrasion tester [10] and rotary drum abrader [11], were employed to eval- uate the wear performance of nonmetallic materials. However, these approaches failed to replicate the ac- tual field conditions, yielding poor correlations with real-world outcomes. Recognizing this limitation, the National Research Council (NRC) established special- ized testing protocols tailored to nonmetallic mate- rials in the oil sands services [12]. Studies conducted by the NRC revealed that elastomer liners exhibited Pipeline Technology Journal - 1/2025 RESEARCH • DEVELOPMENT • TECHNOLOGY 49 outstanding wear resistance compared to carbon steel in both slurry jet erosion and Coriolis scouring erosion evaluations [13]. InnoTech Alberta Inc. developed a pi- lot-scale slurry loop system, where solid particles up to 2 in. could be included in the wear test. Findings from this investigation indicated that PU-lined and rub- ber-lined pipes surpassed carbon steel pipes in terms of wear performance [14]. Constructing extensive lengths of large-diameter (e.g., 28-32 in. diameter) carbon steel pipelines is relatively straightforward: this can be achieved by welding plain carbon steel pipes with beveled ends in the field. On the other hand, building lengthy sections of elastomer-lined carbon steel pipelines poses significant challenges, pri- marily because welding is deemed unfeasible. Excessive heat generated during the welding process compromises the adhesion system and liner integrity. Consequently, flanged connections and mechanical couplers have be- come common substitutes. Unfortunately, these alter- native joining methods introduce potential leak points and substantially escalate costs associated with pipeline capital projects. Moreover, the increased outer diameter at pipe joints makes them too large to fit in tight spaces, like inside culverts at road crossings or in crowded areas. Responding to these limitations, nonmetallic piping manufacturers pioneered innovative weldable joint tech- nologies. Their approach involves deploying a thermal barrier to safeguard the adhesion system and liner from excessive welding temperatures [15, 16]. Implementation of product & manufacturer qualification program, com- bined with these weldable joint technologies, enabled the successful upgrading of extended carbon steel pipe- lines with elastomer-lined pipes. The integration of nonmetallic piping products has notably expanded the operational runtime of slurry pipelines in the oil sands industry. Prolonged runtime translates to fewer outages, subsequently reducing maintenance expenses. In 2009, the application of non- metallic piping products was minimal, spanning less than 10 kilometers collectively. Now, several hundred kilometers of nonmetallic pipelines operate in oil sands. With the use of new materials, however, come new chal- lenges. In subsequent sections, we’ll describe key prob- lematic areas related to nonmetallic pipelines, discuss lessons learned, and highlight technological advance- ments aimed at addressing these emerging challenges.

Pipeline Technology Journal - 1/2025 RESEARCH • DEVELOPMENT • TECHNOLOGY 51 A pervasive issue plaguing elastomer-lined pipelines is "leading-edge wear" at pipe joints (Figure 5). This lo- calized liner wear strips away the entire liner, leaving bare carbon steel exposed to the slurry flow. This type of wear tends to concentrate near the leading edge of the downstream spool, usually within 1 ft. from the joint. Misalignment between connecting pipes often causes this issue. Two scenarios can happen as shown in Figure 6, leading to different outcomes: • Step-down scenario: When the interior of the downstream pipe sits lower than the upstream pipe's interior at the 6 o'clock position, an eddy cur- rent develops beyond the joint, accelerating liner wear in the downstream pipe. • Step-up scenario: When the downstream pipe's interior resides higher than the upstream pipe's at the 6 o'clock position, solid particles collide with the protruding portion of the downstream pipe, swiftly eroding the liner. Figure 5. Leading-edge wear in elastomer-lined pipes. Pipe misalignment can also occur when two different piping materials with different wear lives are joined to- gether. The following two scenarios illustrate this point: • Scenario 1: Initially, a carbon steel pipe connects to a downstream elastomer-lined pipe (Figure 7 a). The carbon steel pipe with short service life would be replaced while the elastomer-lined pipe remains for additional wear life. After replacing the carbon steel pipe, a step-down configuration emerges at the pipe joint (Figure 7 b). Figure 6. Misalignment at pipe joints during installation, a) step-down and b) step-up. Figure 7. Misalignment at pipe joints during operation, a) & b) upstream carbon steel pipe and downstream elastomer-lined pipe, c) & d) upstream elastomer-lined pipe and downstream carbon steel pipe.

Pipeline Technology Journal - 1/2025 RESEARCH • DEVELOPMENT • TECHNOLOGY 53 Figure 9. Field test of RFID wear monitoring technology. Implementing in-line inspection (ILI) can yield substan- tial maintenance benefits for nonmetallic pipelines. ILI can provide comprehensive data on pipeline conditions, so high-risk spools can be identified for focused main- tenance efforts. ILI has been widely used to detect metal loss and corrosion damage in carbon steel pipelines and good industry practices can be found [25]. On the other hand, ILI technology lags behind in nonmetallic pipelines. Traditional MFL or UT-based ILI tools, prevalent in carbon steel pipelines, were not successful for nonmetallic pipe- lines with thick elastomer liner. Alternatively, mechan- ical caliper-based ILI demonstrated some promising re- sults. Since slurry pipelines contain solid particles up to 5 inches in size, damage to the sensor would be a concern in case of on-line inspection. Therefore, off-line inspection (e.g. running a tool through empty pipelines during out- ages) was considered as a viable option for slurry pipelines. Long-term exposure to bitumen makes elastomer liners softer and increasingly susceptible to mechanical dam- age. Consequently, careful consideration must be devoted to avoid potential liner damage when running heavy ILI equipment through aging nonmetallic pipelines. To mitigate localized liner wear at pipe joints, re- placeable ring technology was developed [26]. This innovation features a sacrificial pup spool consist- ing of an elastomer liner and reinforcement compo- nent, designed to span approximately 1 ft. - sufficient to cover the region prone to the leading-edge wear. It can be pre-installed in the elastomer-lined pipe: the Figure 10. Shop demonstration of replaceable ring technology, a) before installation and b) after installation.

loss in carbon steel slurry pipelines over a rela- tively short period. • To increase the service life and improve the system reliability in slurry transportation system, nonme- tallic piping products such as elastomer-lined pipes and rubber hoses have been deployed. With imple- mentation of product & manufacturer qualification program and development of weldable joint tech- nologies, carbon steel pipelines could be success- fully upgraded with nonmetallic counterparts. References 1. www.worldometers.info/oil 2. www.capp.ca 3. Compact slurry preparation system for oil sand by Ron Cleminson et. al. US Patent 7431830 4. K. F. Adane, A. Fuhr, and M. Huard, “Modeling Abrasion- Corrosion in Horizontal Pipeline Slurry Flows”, presented at AMPP Conference, Nashville, TN, USA, March 24-28, 2019 5. V. Javaheria, D. Portera, and V. Kuokkalab, “Slurry erosion of steel-Re- view of tests, mechanisms and materials”, Wear 408–409 (2018) 248-273 6. ASTM G-119, Standard guide for determining sy- 7. nergism between wear and corrosion J. Jiang, Y. Xie, Md A. Islam, and M. M. Stack, “The effect of Dissolved Oxygen in Slurry on Erosion-Corrosion of En30B Steel”, J. Bio Tribo Corrosion (2017) 3:45 8. M. Anderson et al., “Improving reliability and producti- vity at Syncrude Canada Ltd. through materials research: Past, present, and future”, CIM Bulletin V97: 1083, 2004 9. J. Wolodko, B. Fotty, and T. Perras, “Application of Non- Metallic Materials in Oil Sands Operations”, presented at NACE Conference, Vancouver, BC, Canada, March 7-10, 2016 10. ASTM G65: Standard Testing Method for Measuring Abrasion Using the Dry Sand/Rubber Wheel Apparatus 11. ASTM D5963: Standard Test Method for Rubber Property- Abrasion resistance (Rotary Drum Abrader) 12. Y. Xie, J. Jiang, and Md A. Islam, “Applications of elas- tomers in slurry transport”, Wear 477 (2021) 1-7 13. Y. Xie, J. Jiang, and Md. A. Islam, “Elastomers and Plastics for Resisting Erosion Attack of Abrasive/ Erosive Slurries”, Wear, 426-427 (2019) 612-619 14. K. F. Adane, A. Fuhr and B. Forty, “Evaluating Polymer Based Materials Pipeline for Large Solids Particles Applications”, presen- ted at NACE Conference, Phoenix, AZ, USA, April 15-19, 2018 15. www.iracore.com 16. M. Magerstädt, T. Raeth, D. Plourde, L. Lai, S. Forster, R. Altmeppen, and A. Sarvi, “High-Performance Polyurethane Elastomer Coatings- Lessons Learned from 6 Years in Oil Sands Service”, presen- ted at NACE Conference, Phoenix, AZ, USA, April 15-19, 2018 17. M. Lomax, Permeation of Gases and Vapours through Polymer Films and Thin Sheet-Part 1, Polymer Testing 1 (1980) 105-147 18. J. Jelinek and C.J. Watkinson, “Cold Wall Effect Testing of an Internal Pipeline Coating for In-situ Application”, presented at NACE Conference, San Antonio, TX, USA, April 25-30, 1999 19. NACE TM 0174: Laboratory Methods for the Evaluation of Protective Coatings and Lining Materials on Metallic Substrates in Immersion Service 20. L. Gray, N. Varennes, B. A. Bloor, M. O’Donoghue, R. Garrett, R. Graham, V. Datta, and B. Franke, “Insights into Atlas Cell Testing for Selection of Linings for Oil and Gas Production Vessels and Tanks”, presen- ted at NACE Conference, New Orleans, LA, USA, June 5-8, 2008. 21. Pipe Assembly including an Anchor member for Resisting Delamination of a Liner from a Pipe Shell by Soon W. Moon. US Patent 11808397, CA Patent 3147504 22. https://pip360.com 23. Wear monitoring for conduits by Soon W. Moon et. al. CA Patent 2922137 24. S. Moon and M. Anderson, “RFID Technology for Wear Monitoring of Non-metallic Pipes”, MTI Connect Magazine, Issue 1, 29 (2021) 25. NACE SP0102: In-line Inspection of Pipeline 26. Polymer-lined pipes and fittings with replaceable components by Soon W. Moon et. al. US Patent 10139019, CA Patent 2906224 27. S. Moon, M. Schaffer, M. Syed, M. Romanow, and R. Rong, “Non-metallic Slurry Pipelines In Oil Sands-Challenges and Potential Solutions”, pre- sented at AMPP Conference, Denver, CO, USA, March 19-23, 2023 Pipeline Technology Journal - 1/2025 RESEARCH • DEVELOPMENT • TECHNOLOGY 55 • Despite initial successes, unexpected failures in nonmetallic pipelines caused challenges in relia- ble operation of slurry pipelines. Catastrophic de- lamination incidents in elastomer-lined pipelines resulted in unplanned outages and operational interruptions. Leading-edge wear at pipe joints caused accelerated degradation in adhesion, con- tributing to delamination. • To ensure reliable operation of nonmetallic pipe- lines, advanced condition monitoring technol- ogies, including RFID-based wear monitoring system, have been developed. Additionally, re- placeable insert ring and advanced repair technol- ogy using anchors were developed to address the leading-edge wear issue at pipe joints. AuthorS Dr. Soon Won Moon Saudi Aramco Research Science Specialist soon.moon@aramco.com Stefano Chiovelli Metallurgical Engineering Advisor (Retired) schiovelli@shaw.ca

Pipeline Technology Journal - 1/2025 RESEARCH • DEVELOPMENT • TECHNOLOGY 57 Feature Paper of the Global Women Forum (GWF) The Global Women Forum (GWF), an EITEP platform, is committed to equipping women and young talents with the skills needed for the future, particularly in emerging sectors such as energy, STEM, AI, and the digital world. As part of the global Pipeline Technology Conference (ptc), we organize the platform Global Women in Pipeline. This initiative provides a space for knowl- edge exchange, best practices, and innovative ideas to promote the participation of women in the pipeline and energy sectors. Women remain vastly underrepresented in the pipe- line industry, making up less than 20% of the energy workforce and only 10% in technical roles. Through targeted discussions and networking opportunities, we foster diversity, inclusion, and the next generation of leaders, ensuring that women play a pivotal role in shaping the future of energy and infrastructure. 1. Current Status: Women in Leadership Positions Despite progress in recent decades, the representation of women in leadership positions remains inadequate. While women now make up a significant portion of the working population, they are still underrepresented in top positions. In Germany, the proportion of women in leadership positions was only 30% in 2012, below the EU average of 34% (Schreus & Leis, 2014). Data from the Federal Statistical Office show that the proportion of women in leadership positions in 2023 was only around 29%, with no progress made over more than a decade (Statistisches Bundesamt, 2023). Germany thus remains in the lower third in the European com- parison, while countries such as Sweden (44%) and Latvia (43%) have significantly higher proportions of female leaders (Statistisches Bundesamt, 2023). A major factor in this disparity is the persistence of traditional leadership models. Leadership positions in Germany are predominantly full-time with long working hours, which poses a structural hurdle, es- pecially for women with family responsibilities and corresponding societal expectations (Schreurs & Leis, 2014; Ihsen, 2013). Female leaders (approx. 28%) work part-time more often than their male colleagues (ap- prox. 5%) (Who leads part-time?, n.d.). Furthermore, unconscious biases and stereotypical ex- pectations continue to exist in many organizations. In addition, women are less often integrated into infor- mal networks that are essential for career advancement (Budde & Doebert, 2017). All in all, it makes it difficult for women to access leadership positions. At the same time, studies show that companies with a higher pro- portion of women in leadership positions are more eco- nomically successful in the long term, as they benefit from diverse perspectives and improved decision-mak- ing (Schreurs & Leis, 2014; Daling et al., 2023). To overcome these structural hurdles, targeted support measures, including mentoring programs, flexible work- ing time models, and a conscious engagement with bi- as-free promotion processes, as well as a shift in societal thinking, are needed. The inclusion of male leaders as mentors could play a crucial role in the corporate con- text in actively supporting women on their career paths and breaking down structural barriers (Braun et al., 2017). 2. Special Challanges for Women in the STEM Workforce The minority status of women in scientific, technical, engineering, and mathematical (STEM) professions hinders their successful career development. This pe- culiar situation is characterized, on the one hand, by the low representation of women in STEM studies and

Pipeline Technology Journal - 1/2025 RESEARCH • DEVELOPMENT • TECHNOLOGY 59 Figure 2: Unpacking the Challanges for Women in STEM in mechanical and plant engineering described above (Schmitt et al., 2021; Daling et al., 2023). This phenomenon is not unique to Germany. With regard to women in STEM, the pipeline appears to be 'exception- ally leaky', particularly in Australia where it is reported that only 16% of the STEM-skilled workforce are women and that 90% of all qualified STEM women are employed in non-STEM related fields (Fairhurst et al., 2024) 3. The Role of Men as Mentors Mentoring plays a crucial role in career development. While women's support programs are often carried by female mentors, research shows that male men- tors can play an equally significant role. Since men continue to hold most leadership positions, they can act as mentors in opening career paths for women (Schreurs & Lies, 2014). Integrating male leaders into mentoring programs of- fers several advantages: 1. Expanding professional networks: Men still dom- inate key informal networks that are essential for career advancement. Women often have less ac- cess to these structures. A male mentor can ac- tively involve his mentee in these networks and increase their visibility (Hessenberger, 2021). 2. Reducing gender-specific biases: Direct mentor- ing relationships help to challenge unconscious biases. Many male leaders only realize through working with female mentees that women are less frequently promoted and/or given less responsi- bility despite equal qualifications (Haghanipour, 2013). 3. Promoting structural changes: Men in deci- sion-making positions can actively contribute to anchoring gender equality strategies in the com- pany. Through their advocacy in personnel deci- sions, they can dismantle structural barriers and shape gender-equitable career models (Schreurs & Leis, 2014). However, challenges should also be recognized, such as unconscious biases, where women may only be sug- gested for certain positions or tasks, while men are preferred for strategic or operational leadership roles (Wippermann, 2010). Open communication and clear guidelines for mentoring are also necessary to avoid misunderstandings and misinterpretations. A survey by the US Women's Dermatologic Society on the influence of gender on the success of mentors and mentees found no statistical difference in most cate- gories between female same-sex mentorships and gen- der-atypical relationships. Overall, respondents felt that the quality of the relationship was the most im- portant factor. Furthermore, the feedback suggested that spontaneous (informal) mentors may offer even greater benefits from a mentee's perspective than of- ficially appointed mentors. (Lin et al., 2021). It should be noted, however, that this could also correlate with the criterion of relationship quality, which is crucial.

by having experienced leaders – both men and women – act as mentors. A special feature is that mentors su- pervise a mentee from another department, promoting exchange and networking across departmental bound- aries. The mentors share their experiences, provide ca- reer tips, and facilitate access to professional networks. Since 2005, around 1600 mentors and mentees from all federal ministries and top bodies have participated in the program. Many mentors are engaged for sev- eral years and emphasize the value of passing on their own experiences and expanding their leadership skills (Cross Mentoring – Public Service, n.d.). 5.2 MentorMe Another example is the MentorMe program, which is considered the largest mentoring program for women in the German-speaking area. It offers women the op- portunity to find mentors – both men and women – who support them in their professional development. The program aims to improve women's career opportu- nities through targeted mentoring and facilitate their access to networks (MentorMe GmbH, 2025). 5.3 Women Promotion at OGE OGE is actively committed to the advancement of women. Through initiatives the company not only enhances ca- reer opportunities for women but also encourages shar- ing and networking within the company. OGE follows a multi-faceted approach that inspires both women in the workforce and young girls for technical professions. A central element of women's promotion is the OGE Women's Network, which offers women in the com- pany a platform for regular exchange. The OGE wom- en's network is an initiative of OGE employees and is supported by the company. The network meetings address various professional and technical topics, al- lowing participants to discuss challenges, career op- portunities, and internal company developments. In addition, regular exchanges with women's networks from other companies are also held, promoting net- working and knowledge exchange beyond the com- pany. A special feature of this network is the targeted integration of technical content: Experts from tech- nical departments present their activities and impart technical knowledge, which expands knowledge of the participants and also establishes contacts, which can be used for future questions or for building informal mentoring relationships. The OGE Women’s Network Pipeline Technology Journal - 1/2025 RESEARCH • DEVELOPMENT • TECHNOLOGY 61 thus serves not only for knowledge transfer but also for professional integration and networking within the company and beyond. Women are thereby given targeted access to internal structures that are crucial for their career development. Another significant support project is the EmpowerGirl internship program, which sensitizes young girls to technical professions. Since the proportion of women in technical professions remains low, OGE addresses this early on with this program to spark interest in STEM careers (science, technology, engineering, math- ematics). Girls are given the opportunity to immerse themselves in the world of technical professions and gain practical experience. In addition to these initiatives OGE also has a com- prehensive diversity program aimed at creating an inclusive work environment. This includes continu- ous analysis and monitoring of gender distribution within the company. To advance awareness of un- conscious biases, OGE held a diversity tour that ad- dressed the role of women in the company among other topics, making it visible. It is an explicit goal of OGE to have more women in man- agement positions. Achieving this goal requires - in ad- dition to concrete measures and flexible regulations - an awareness and acceptance of ‘subjective career success.’ This leads to empowerment in the sense of promoting the development of individual potential and provides a solid basis for further career steps, which can then also lead to formal management positions. Figure 5: Women's Career Advancement Initiatives

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Pipeline Technology Journal - 1/2025 RESEARCH • DEVELOPMENT • TECHNOLOGY 65 THE J.N.H. TIRATSOO COMMEMORATIVE WHITEPAPER For readers who may not be so familiar with that name: John Tiratsoo was an eminent member and pillar of our industry. He is perhaps best known as the former editor of Pipelines International maga- zine and the Journal of Pipeline Engineering. John was also co-founder and co-organizer of the Pipeline Pigging and Integrity Management conference and exhibition (PPIM). He made major contributions to our industry and has been a driving force in the pro- fessional sharing of information. The following paper by Jordi Aymerich, Tannia Haro, Sayan Pipatpan, Santiago Urrea & Alex Hensley was chosen by the PPIM organizer, Clarion, and made available for reprint in this edition of the PTJ as a commemorative tribute to John Tiratsoo. The paper was presented at the recent PPIM held in Houston February 01-29, 2025. Special thanks to BJ Lowe and Ben Stroman of Clarion for making this possible. 1. Introduction Pipeline operators employ various strategies to ensure the operational safety of their pipeline systems. A cru- cial element of this strategy involves In-Line inspec- tion (ILI), Non-Destructive Examination (NDE), and, if necessary, destructive testing in the laboratory. Axial cracking is the predominant form of cracking found in pipelines; detection and sizing of such pla- nar linear imperfections using Ultrasonic Pulse Echo technology has been a proven methodology for more than 25 years. Planar anomalies are imperfections that occur in a two-dimensional plane. However, the char- acterization and sizing of features that have a tilt from the radial direction or a skew from the axial orienta- tion could pose a challenge for this technology. Phillips 66 contracted NDT Global to run a high-resolu- tion axial crack inspection that resulted in a considera- ble number of reported anomalies in the longitudinal weld. Most of these anomalies showed data signals that indicated complex geometries. NDT Global, in collabo- ration with Phillips 66, developed a procedure through advanced signal analysis for applying pattern recogni- tion based on NDE to better understand the challenging anomalies present in the line. The research and execu- tion of the project were structured in 2 phases: • Phase 1 – ILI data signal pattern analysis based on NDE results. • Phase 2 – Validation of Phase 1 categorization methodology with appropriate field verification and destructive testing in the laboratory. This research not only enhances industry understand- ing of LF-ERW seam weld cracking but also highlights the role of Pitch & Catch technology in future inspec- tions. NDT Global's 6” Eclipse tool will mitigate past me- chanical constraints, improving Hook Crack Detection and Sizing Accuracy. 2. Background In December 2021, a high-resolution Axial Crack Inspection was conducted in a 6" vintage pipeline with a predominant wall thickness of 0.188". The pipeline was installed in 1951 with low-frequency electric re- sistance welded (LF-ERW) pipes. It is important to note that small diameter pipelines pose difficulties for both ILI and field verification NDE techniques. On the ILI

Pipeline Technology Journal - 1/2025 RESEARCH • DEVELOPMENT • TECHNOLOGY 67 Figure 2: Scheme at scale of a 'hook crack' detected by clockwise and counterclockwise sensors. Colour lines simulate the sound beam, and the stronger ones indicate reflections from the flaw back to the sensors. reflection from a crack from both sides of the weld be- have similarly, then the flaw is not tilted. When the amplitudes are significantly different or the signal patterns differ, the anomaly may be tilted or have a complex geometry. A bond line that is not purely per- pendicular to the surface can make the identification of an anomaly type more difficult because anomalies along the bond line are also tilted (Figure 2). Comparatively, the evaluation of a weld with NDE typi- cally involves visual testing and magnetic particle test- ing on the external pipe surface, followed by Ultrasonic Testing (UT) based on shear waves, i.e., shear wave UT or Phased Array UT (PAUT). A Shear Wave UT inspection requires manually scanning the weld from both sides. This is a pulse-echo measure- ment, like the In-Line Inspection technology discussed above. PAUT typically uses sectorial scans, where the angle is electronically modulated between a specific range. This works for ideal defects, but there are limita- tions regarding embedded cracks and planar, but tilted, anomalies with a directional reflectivity. As a result, the detection of tilted or embedded cracks can depend on the probe's angle for Shear Wave UT and the probe's posi- tion for PAUT sectorial scans. Note that the tilted reflector may be missed depending on the probe's angle (for UT) and the probe's position (for PAUT sectorial scans), as the reflections are guided away from the probe. 3.1 Phase 1 In-ditch NDE inspections using PAUT identified several Hook Cracks and one internal surface-connected crack. The corresponding ILI data was analyzed, revealing two distinct patterns: 1. Non-radial seam anomalies exhibited differing CW and CCW sensor signals in amplitude or pattern. 2. Some verified hook cracks displayed consistent ILI signals on both weld sides but followed a three-re- flection pattern, suggesting multiple reflectors. Applying this pattern recognition methodology to all non-repaired anomalies helped identify 22% as poten- tial hook cracks. To mitigate risk, Phillips 66 excavated all likely/possible hook cracks identified in Phase 1. Results from the dig campaign and destructive lab testing were then shared with NDT Global for Phase 2 validation. 3.2 Phase 2 The operator selected these potential Hook Crack Anomalies for Non-Destructive Examination. For this new dig campaign, the operator decided to change the NDE vendor (Vendor 2). The general setup for Vendor 2 NDE was using the Total Focusing Method (TFM), which differs from PAUT. For a TFM setup, there are no distinct angles. Instead, the setup uses Phased Array UT (PAUT) probes, gener- ating a high number of different sound paths between the individual PAUT elements. The inspected area (TFM zone) is represented by a grid, where the signals from all sound paths are merged based on the wave mode and theoretical travel times for each grid cell.

Pipeline Technology Journal - 1/2025 RESEARCH • DEVELOPMENT • TECHNOLOGY 69 Figure 3: Macro photograph of the transverse metallographic for an anomaly identified as surface lap. Scale divisions are 1/10 inch (left). & Macro photograph of the transverse metallographic for an anomaly identified as surface lap. Scale divisions are 1/10 inch (right). NDT Global performed a Below Reporting Criteria (BRC) analysis on more than 3,000 anomalies to determine which of them could potentially be Hook Crack or Surface Lap anomalies. BRC anomalies are those anom- alies that, despite being detected and sized, do not meet the depth and length required to be included in the stand- ard reporting list. After the complete review, the final call for possible Hook or Lap Anomalies was reduced to less than 20 anomalies that showed hints of complexity and were blocking the bond line-surface contact reflections. Phillips 66 will be reviewing the final listing provided by NDT Global and performing a risk-based assess- ment to decide which potential Hook Crack or Surface Lap anomalies need remediation and include them in their next dig program. The utilization of additional analysis methods results in a higher degree of confi- dence in the ILI results. In combination with destruc- tive testing validations, this in-depth analysis bet- ter informs decision-making, ultimately leading to a reduction in the number of assumptions and resulting in better management of the pipelines' integrity. 4.2 Ground truth enables performance analysis and sizing curves analysis The starting point of this investigation was the NDE result list from Vendor 1, where 33 anomalies were identified as Hook Crack in the field, and the depth sizing of these anomalies raised concerns about the performance of the ILI tool used for the inspection. As can be seen in Figure 4, the unity plot for ILI-reported depth compared to the Vendor 1 NDE depth shows a clear tendency for the ILI tool to underestimate the field-verified depths. It needs to be noted that Vendor 2 results were taken using TFM methodology after Phase 1 of this investigation was pub- lished. The dashed red lines in the following figures are the tool tolerances specified in the NDT Global perfor- mance specification at 80% confidence level, and each anomaly error bar is based on a field depth tolerance of ±25 mils at 80% confidence level. Figure 4: Unity plot for NDE Vendor 1 (left) and Vendor 2 (right) results compared to ILI results.

4.3 NDE and lab results validation Following the method described by API Standard 1163, the combined tolerances were determined from the con- tractual feature specification of the ILI tool and the toler- ances of the field measurements. For the High-Resolution UT tool used for the inspection, the depth sizing accuracy at a certainty of 80% depends on the feature depth. Table 1: ILI tool depth sizing accuracy For PAUT and TFM, measurement tolerances for crack depth were considered as ±20 mils, based on consider- ations in Table 1 of the Recommended Practice POF 310 Field Verification for ILI. Pipeline Technology Journal - 1/2025 RESEARCH • DEVELOPMENT • TECHNOLOGY 71 The findings are based on the regraded NDE results from Vendor 1 and 2, and on the laboratory results. Which add up a total of 80 anomalies. 72 of the 80 measurements were within tolerance, yielding pupper = 94.42% and plower = 82.96%. These results exceed the certainty of 80%, corresponding to Outcome 3 of the level 2 validation described in API Standard 1163:2021. The ILI performance specification is feasible. There are sufficient field results to proceed with a level 3 validation analysis. Level 3 validation analysis, as de- scribed in API Standard 1163:2021, seeks an estimation of the actual ILI performance as indicated by the avail- able validation measurements. The statistical evalua- tion concluded that the tolerance interval for a given ILI measurement is [-26 mils, 44 mils]. Therefore, the actual tool tolerance is ±35 mils with a certainty of 80%. Figure 7: Level 3 validation unity plot for lab results and NDE vendor 1 and 2 regraded results in front of the ILI results.

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Pipeline Technology Journal - 1/2025 PTJ YOUNG Pipeliner 75 Future-Proofing Pipeline Operations: Advancing Vibroacoustic Technology Through Innovative Digitalization and Enhanced Detection of Multiple Phenomena I. Gargione, F. Chiappa, A. Gomes > Enivibes Abstract Pipelines are crucial to daily life, requiring ongoing monitoring and protection. Vibroacoustic Technology (VT) offers reliable pipeline monitoring by detecting various phenomena through vibroacoustic waves. However, even the best field solutions and software lose effectiveness without a user-friendly interface. Timely detection and localization of pig runs, leaks [1], and third- party interferences (TPI) are critical and must be supported by ro- bust, well-designed software. Digitalization and modularization enhance this by ensuring fast, accessible information and seamless data processing for efficient decision-making. This discussion explores the challenges and benefits of digitali- zation and modular processing implementation on VT, which has proven instrumental in maintaining adaptability and ensuring future-proofing in pipeline monitoring systems.

interpretation and enabling rapid responses to po- tential issues. This promptness is vital in preventing minor problems from escalating into major incidents. Furthermore, the integration of alarms and notifica- tions via SMS or email significantly enhances the sys- tem's effectiveness. Real-time alerts keep operators in- formed of critical events like leaks or pressure drops, allowing them to take immediate action, even when they are away from the control room. Figure 4 shows a leak alarm notification displayed on the user interface, above the semaphore overview of all monitored pipe- lines. Alarms typically have a response time of 5-15 min- utes. The platform allows the operator to manage the alarm received and track all historic alarms. Figue 4: VT Leak Alarm shown in the UI 4. Conclusion and Future Directions Investing time and resources in modularizing VT has enabled quicker, seamless development, along with the efficient maintenance and updating of existing ones, without compromising system performance or availa- bility. The outcomes are presented through a user in- terface that is intuitive, user-friendly, and secure, lev- eraging built-in intranet and VPN measures, alongside user-controlled access protocols, to ensure safe and easy accessibility. Further refinement of the modular archi- tecture could focus on enhancing interoperability be- tween detection modules and the implementation of AI-driven analytics [2], providing deeper insights, and predictive capabilities, and pushing the boundaries of what VT can achieve. Improvements in UI design, par- ticularly in response to evolving user needs and indus- try standards, will be essential to keep the system's rel- evance and effectiveness in an increasingly complex technological landscape. References 1. Marino, M., Del Giudice, S., Chiappa, F., Giunta, G. 2022. Advanced Leak Detection Applications for Pipeline Integrity Management using VT. Paper presented at ADIPEC. 2. Biagini, M., Gomes, A.P., Chiappa, F. 2023. Toward AI Data-Driven Pipeline Monitoring Systems. Pipeline Technology Journal. Pipeline Technology Journal - 1/2025 PTJ YOUNG Pipeliner 77 Author Icaro Gargione Enivibes Software Engineer icaro.gargione@enivibes.com Fabio Chiappa Enivibes Technology Innovation Manager fabio.chiappa@enivibes.com Ana Paula Gomes Enivibes Business Development Manager ana.gomes@enivibes.com

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