Seminar Papers

An 18", North Sea, heavy wall, offshore wet gas flowline with known debris interference, had to be inspected. The total length is 286km with up to 27.3mm nominal wall thickness. Potential corrosion had been detected in a previous 3rd party in-line inspection. However, the POI was limited and no clear differentiation between corrosion and debris was possible. Hence, the previous inspections were not fully successful, and the data couldn’t be used for a full evaluation of the clients problems. 3P Services was asked to perform a metal loss inline inspection of the pipeline as soon as possible. Following on from a specific cleaning program, 3P proposed an 18" GEO/MFL/DMR combo tool. This tool combines a heavy wall magnetizer with a geometry measurement segment and special DMR sensors, wall guided as well as in a stand-off configuration. The combination of these different sensor technologies allows an optimized differentiation between debris, internal corrosion, or internal corrosion with debris. This information was used to improve the POI and anomaly sizing. The challenges and solutions of this outstanding project are explained in this paper.

This paper presents a case study of an offshore pipeline with pitting and long axial corrosion that had been continuously inspected by Magnetic Flux Leakage (MFL) and was recently inspected with an Ultrasonic Wall Thickness Measurement (UTWM) tool. An anonymized comparison of 3 MFL inspections and the recent UTWM inspection is presented. This analysis demonstrates the challenges associated with the two methods, and how UTWM can be used to acquire topography that describes the complete extent of metal loss. Further, the case study also shows a new and more customized approach to providing data that enables a better comparison of results between different ILI methods. Finally, direct measurement data enables advanced integrity methods, like DNV-RP-F101 Appendix D, which uses wall thickness and standoff data to calculate pipeline capacity and system effect considering the effects of long axial corrosion continuously spanning multiple pipe joints.

In 2019 the existing 16” pipeline from Gannet to Fulmar was rerouted to a new 24” subsea wye at the Judy platform location, in readiness for the Fulmar platform to be decommissioned in 2022. By performing this pipeline rerouting operation this meant that the pipeline from the 16” Gannet pig launcher now had three subsea diameter transitions from 16” to 24” to 34” over 477km before terminating at the 34” pig receiver at Teesside. This combined 16”, 24”, 34” pipeline system now posed an issue for Gannet oil production into the system as the 16” export pipeline requires regular cleaning to remove wax deposits. Pigtek were then tasked in developing a pig which could travel through all 3 pipeline diameters along with providing the cleaning of wax in 16” / removal of water in 24” and ultimately being received at the Teesside 34” pig receiver whilst the pipeline and respective platforms ran in normal operating conditions.

To ensure continuity of hydrocarbon supply, opportunities are sought by Exploration & Production companies in continually increasing water depths. A range of pipeline technologies and manufacture methods are generally employed to increase the technical feasibility of Deepwater developments. While a combination of pipeline design facilitates high pressure and high flow production, it also brings challenges for internal inspection techniques due to an amalgamation of demanding inspection criteria such as: heavy wall thickness, high temperature and pressure, flexible riser transit, trap constraints and internal diameter reductions.

To address these challenges, ROSEN is able to provide an holistic approach to inspection, whereby a portfolio of solutions can be considered, with an aim to deliver optimum integrity data while also mitigating risk. This paper will discuss ROSENs toolbox approach to Deepwater pipeline inspection through presentation of case studies.

For more than 5 years, TRAPIL has been researching, as a pipeline operator, an inspection tool that would allow, in a single run, the detection, location, identification and sizing of dents, metal losses and crack anomalies (axials and circumferentials) affecting liquid product pipelines.

The search for an “all-in-one” tool would indeed allow significant gains in terms of pipeline operation. The runs are indeed done at reduced speeds, an “all in one” tool would therefore make it possible to limit the runs number, and thus the flow reductions, and thus the operating losses.

Phased Array UT technology is a disruptive technology that allows for a wide range of adjustments. TRAPIL therefore turned to this technology to try to achieve this all-in-one run.

TRAPIL relied on its existing tool XTRASONIC NEO, its test bench based in Poissy, regulatory obligations, its experience, and its buried pipes in order to establish its specifications.

The objective of this presentation is to present how TRAPIL managed to develop this tool, the successes and points for improvement generated during this process, as well as the first encouraging results obtained.

National Gas Transmission (NGT), formerly National Grid, own and operate the National Transmission System (NTS), the backbone of British Energy. The NTS feeds homes and businesses the essential gas required for life today in the UK. This year, for the first time NGT has conducted an Isolation Joint replacement using the STATS Remote Tecno Plug (pipeline isolation pig), instead of costly traditional venting or recompression operations. The technology provided a fail-safe, leak tight double block and monitor isolation, keeping the 48” pipeline fully pressurized at 56bar for 56km to the nearest block valve upstream. Crucially, the Remote Tecno Plug has helped to reduce NGT’s emissions and will support the undertaking of critical repair activities more responsibly on the road to net zero.

In-Line Inspection (ILI) is a key tool in the assurance of pipeline integrity. Magnetic flux leakage (MFL) inspection has been used to identify and quantify corrosion and other metal loss defects. However, MFL remains an indirect measurement of such features and therefore requires truth data either from in-field measurement or machined defects to evaluate and improve tool performance.

The emergence and increasing adoption of laser scan technology in the measurement of in-field (dig) results has led to an exponential increase in the volume of valuable truth data from real corrosion features. Baker Hughes has long maintained performance databases of such in-field results.

Application of machine-learning algorithms to this database has allowed Baker Hughes to address the inherent conservatism and other shortcomings of the Pipeline Operators Forum (POF)-categorised performance specifications previously used to express the uncertainty associated with MFL measurements.

In utilising this approach, Baker Hughes has developed feature-specific tolerances allowing for a more accurate assessment of feature integrity enabling a more targeted, cost-effective, and ultimately safer prioritisation of repair and other pipeline integrity activities.

Processing pigging returns at a flowrate of 281m³ p/h with a 10000ppm OIW inlet event and providing a 15ppm OIW outlet. Without consumables.

On a recent project CETCO provided a rental separation package to enable the real-time overboarding of fluids from a line reinstatement project taking 17 pig runs at 281m³ p/h between 2 North Sea Assets.

Working closely with the Operator and their 3rd party engineering house the Project Team jointly developed a fit for purpose package for this project from CETCO’s Aberdeen equipment inventory.

The DNV skidded package uses CETCO’s field proven, proprietary oil in water separation technology Hi-Flow™, a fully regenerable, backwashable technology.

Hi-Flow™ processes variable inlet quality fluids without needing to break containment, batch treat or rely on consumable media.

Oil droplets from 6 micron can be coalesced with clean water for discharge and dry oil recovered.

This technology has also demonstrated an ability to reduce BTEX contamination from fluid stream via the oil reject.

The accurate and reliable tracking of pigs using radioisotopes is an established pipeline industry methodology. When there is misuse of nuclear elements, accidental or otherwise, it tends to make adverse headlines and create a negative perception toward using radioactivity. With over 65 years’ experience, Tracerco is the subject matter expert in the use of radioactive sources for industrial measurement and diagnostics. The safe use of pig tracking radioisotopes will be explored from a first principles approach of the science, to the practical implementation, logistics, environmental impact, health and safety. Examples of isotope tracking in the pre-comm and operational pigging markets will be explored through international case study and client feedback. The objective is to inform, provide perspective and de-bunk myths surrounding the safe use of radioisotope source for pig tracking.

In the world of hydrocarbon pipeline transportation, there are a variety of special fittings in pipeline designs that create challenges for proper in-line inspection (ILI). For example, there are a number of different pieces of equipment for connecting pipelines on the seabed such as end connectors - Hydrocouples and misaligning flanges (MisAligning Flange-MAF), which have a particular internal geometry and represent a challenging obstacle for ILI tools. In many cases these non-standard fittings are unknown to pipeline operators due to the age of the pipeline and/or lack of documentation during their design and construction. This paper describes a customized solution designed specifically for the operator of an offshore multiphase pipeline in the Gulf of Mexico, which allows such installations to be safely negotiated with an ILI tool. This solution makes it possible for pipeline operators to gather data from the entire length of the pipeline for their integrity management, even in the presence of hydrocouples and MAF flanges.

Pig tracking using electromagnetic (EM) transmitters is not a new concept, yet we are still uncovering ways to improve detection. As an example, the industry standard frequency for EM transmitters used in pigging applications is 22Hz however after extensive testing and by applying the science, it is now becoming evident 22Hz is not the optimal frequency for pig detection. We can now look at the actual performance of different frequencies in a variety of pig tracking applications and how this affects the task at hand. We have always known that signal strength can be affected by project specific factors such as pipeline diameter, material & wall thickness, pig design, pig velocity and if the pipeline is buried or subsea. However, in addition to frequency, we now know that the specification and configuration of the transmitter itself can also have a significant impact.

This paper will detail the factors that have previously been overlooked when trying to optimise pig detection and will provide recommendations on how to positively impact the effectiveness of this task. It will evidence this using a recent example whereby we carried out comprehensive “real life” testing prior to a project to ensure that the EM transmitters were configured to ensure the highest probability and greatest efficiency of detection while meeting the battery life constraints. It will also answer the question……..Is there any logic in specifying an EM transmitter’s performance by distance through air?

The self-propelled tool is driven by electricity. As for the dynamic drive system, its gradeablity is limited by the adhesion of electrically driven drive wheels and the transient discharge ability of high energy disposable lithium batteries. At present, in terms of its gradeability and downhill-slope force, the slope angle is not more than 45 degrees and the slope length is not more than 50 meters. A pneumatic drive would be needed as a supplement when there is insufficient electrical drive. The case described in this paper adopts such a method that uses blank pipe airflow to form driving differential pressure to supplement electrical drive in the case of having no back pressure on the pipe and under the discharge condition of the detector.

Adding a leather cup structure on the tool with some lift-off space to the pipe, namely: that the cup is not in contact with the pipe wall, will form a 5% discharge flow, with no frictional drag. The spreading of the cup will form a thrust force on the detector to make it run smoothly, which uses mass flow, equivalent air volume air compressor to generate pneumatic thrust force. Electric drive will supplement pneumatic drive when passing bends and pipe sections with increasing wall thickness and unbalanced resistance, and pneumatic drive will supplement electric drive when climbing. Electric drive and pneumatic drive help maintain balanced running resistance of the detector, so as to achieve smooth running. The above-mentioned dynamic balancing process has been verified on trial. To date, Φ711, Φ1067, Φ1219, , pneumatic-electric hybrid self-propelled tools have been used in real project.

Weekly pigging of a pipeline is a typical regime employed on many pipelines around the world. However this simple activity becomes costly when at one particular asset, every-time a pig is launched the emergency shutdown valve has to be activated resulting in a days lost production.

Development of a Multiple Pig Launching system that could be retrofitted to existing pig launchers with no / minimal invasive activities could reduce the number of times in a year that the ESD valve would need to be operated.

Inpipe ProductsTM designed, manufactured and tested a multiple pig launching system that allows a number of pigs to be launched individually without the need to open the closure door in-between launches.

This paper describes the key stages of development engineering and testing to create a successful conclusion to the original scope.

A routine sphering operation to control liquid hold up on a 30-inch trunk pipeline transporting wet gas was interrupted when a sphere became damaged and stalled in the pipeline following interaction with a subsea valve inadvertently stuck in the partially closed position. Rectifying the valve to the fully open position followed by rescue pigging was selected as the remediation strategy. The offshore platform topsides facilities however were only designed to launch spheres through a side branch of a tee and included a 30” to 36” reducer and 1.5D bend. The rescue pig required careful selection and sufficiently representative onshore pigging trials were then undertaken resulting in identifying numerous issues requiring extensive modifications to the rescue pig design and set up to before it was finally demonstrated the rescue pig could successfully traverse all the features in the topsides pipework. Following a successful subsea intervention campaign to fully open the subsea valve, the rescue pig was deployed and successfully recovered the damaged sphere from the pipeline. This paper and associated presentation describes the details of the various challenges and solutions that enabled an outcome of a safe and successful rescue pigging operation.

In-line inspection (ILI) is a pipeline assessment method used by operators to receive a comprehensive integrity assessment of their pipeline. However, ILI may become unfeasible due to factors such as insufficient flow/pressure parameters for propulsion, pipeline features such as valves, back-to-back elbows and unbarred tees, as well as the lack of infrastructure such as launcher and receiver for tool entry and exit. These pipelines are deemed as difficult to inspect, or “unpiggable,” and are often limited to other integrity assessment methods such as Direct Assessment or hydrostatic testing.

The fleet of robotic inline inspection robots, known as the Pipe Explorer, from Intero Integrity Services, is powered by rechargeable batteries and can travel up to 600 meters under live gas conditions before returning to the size-on-size hot-tap fitting or point to point with the use of an exit hot-tap fitting. The inspection distance may also be extended by cascading in-line-charge (ILC) stations until the desired inspection length is obtained. With Intero’s in-line charge system, Pipe Explorer is charged in-line and subsequently may continue the inspection to the next ILC station or receiver hot tap fitting.

This paper reviews the process, execution, and data from the use of robotic inline inspection for inspections that are several kilometres in length by examining a 3.5 km, two day inspection. This inspection utilized two hot tap fittings for entry and exit, as well as three charge points. The comprehensive magnetic flux leakage (MFL), deformation, and video data provided the operator with the integrity information required for continual undisrupted operation of an otherwise unpiggable pipeline.

Equinor performed decommissioning of the Veslefrikk field in the North sea Q1 2022. One of the first task after Cease Of Production was to decommission two export pipelines, one 10¨ Gas export pipeline and one 16¨ Oil export pipeline. This paper will focus on cleaning of the 16¨ Oil export pipeline. This pipeline is connected to a wye with Oseberg C export pipeline after 25 Km and total length is approx. 37 Km. The task was to clean, cut and isolate the pipeline up stream wye while there was production from Oseberg C.

This paper will cover the following topics: Government requirements, precleaning, wax, planning of the decommissioning pig train and the cleaning result.

The Pipeline Operators Forum (POF) maintains a number of standards and recommended practices related to ILI.

The recommended practice for ILI Field Verification (POF 310) was first published in 2012 and concentrated on issues including location of pipe joints in the field and verification measurements of metal loss features.

During 2022, a POF working group, with input from member operating companies and ILI & NDT contractors, has revised the document to reflect advances in the ILI & NDT industry, including recommendations for verification of a wider range of anomaly types (e.g. cracks) and high level guidance for verification of ILI findings in subsea pipelines.

The paper summarises the contents of the POF recommended practice with particular emphasis on crack detection.

Equinor, a North Sea operator, required an inline inspection of a subsea pipeline used for transporting gas and gas condensate from a subsea template to a platform that was essential to the company’s ongoing operations. To assess the conditions of the critical parts of this asset, which had never been inspected, 720 m of 10" diameter flexible riser and end fittings needed to be examined.

This paper will explore the practical application of NDT Global's, bi-directional, free-swimming, ILI ultrasonic (UT) tool, to provide unique insights into the condition of the flexible riser - including stretching of the inner carcass and the end fitting position status.

In-line inspection (ILI) has been widely adopted as a key source of data for the integrity management of traditional rigid steel pipelines. In the case of flexible pipelines however the deployment of ILI technologies remains an unfulfilled aspiration.

After some early investigations within ROSEN into the development of an ILI tool that can inspect multi-layer unbonded flexible pipes, a more focused R&D project was kicked off in 2019. This initiative resulted in significant progress in understanding the key inspection challenges and also resulted in the adaptation and development of existing technologies to be able to provide a base level of inspection in flexible pipes.

Since this time, ROSEN has also significantly enhanced capabilities in the deployment of different inspection technologies in a number of challenging offshore applications.

This paper provides an overview of the challenges faced by operators in managing flexible pipe integrity, the current state of development in ROSEN’s flexible pipe ILI capabilities and then explores some of the potential [and perhaps novel] solutions for deployment of such inspection systems.

Strain-based assessment is an important part of integrity management of pipelines located in areas with unstable ground conditions. Strain-based integrity assessment is conducted by comparing pipeline strain capacity with strain demand (the level of elongation or compression produced in the pipe wall as a result of external and internal factors). While the bending component of the longitudinal strain is well understood and can be derived from routine IMU (Inertial Measurement Unit) in-line inspections, the pure axial part of the longitudinal strain has been a recognised gap in the knowledge of the strain condition of a pipeline. Now, the inline axial strain inspection tool (AXISS™) can be used to measure the pure axial strain component. The measured axial strain can originate from many sources, such as geotechnical hazards, temperature effects as well as from the combination of soil restraint conditions and internal pressure effects.

This paper describes an approach to combining bending strain, measured by IMU tool, with axial strain, measured by the AXISS™ tool, in order to determine total longitudinal strain demand. The total strain demand can be determined at the girth welds in the pipeline, and at anomalies, such as metal loss, dents, etc, reported by magnetic, ultrasound and deformation inspections. The strain demand is compared with the strain capacity to determine whether remedial action is required. The tensile and compressive strain capacity will not be constant along the length of a pipeline and is influenced by several factors including material properties and imperfections in the girth welds, corrosion and geometric anomalies such as dents, buckles, wrinkles. A case study is included in the paper showing how the axial and bending strain components are combined to determine the longitudinal strain demand and an approach for evaluating the strain capacity to assess the integrity of the pipeline.

The advancing global energy transition faces many challenges when it comes to ensuring a sustainable, reliable and affordable energy supply. An emphasis on decarbonizing the existing infrastructure will lead to greater penetration of greener fuels, such as hydrogen, ultimately produced from renewable energy. This paper will review the challenges associated with transporting these green fuels through pipelines, and outline an Integrity Framework approach as part of the decarbonisation value chain.

Many operators are currently in the initial stages of investigating possibilities to build dedicated hydrogen pipelines or convert existing natural gas pipelines to hydrogen. With its innovative inspection technologies, supported by world class Integrity Engineering, ROSEN is well on its way supporting the industry with these challenges. This will be highlighted by a use case containing multiple ROSEN inspections performed in 100% hydrogen under operational conditions.

In parallel with the need for hydrogen pipelines, there is a re-emergence for the requirement to transport CO₂. This time, the requirement is related to (Blue) hydrogen production as a clean energy source. The transportation of carbon dioxide (CO₂) within carbon steel pipelines for the purposes of carbon capture, usage and storage (CCUS) has been a topic of interest for a number of years, but it is fair to say that it has not taken off to the extent anticipated ten years ago. This paper reviews the re-emergence of the requirement for CO₂ transportation in carbon steel pipelines and looks at the related integrity challenges associated with CO₂ in a hydrogen production environment. We will identify threats related to downhole pipework for CO₂ storage, transportation of CO₂ and hydrogen as input for a holistic Integrity Framework.

A new live pig tracking methodology is proposed with field proven operational data. The new proposed method allows tracking from end of pipeline. Sensors are not required along the route and a transmitter system is not required on the pig. The method can be applied to any object in a pipeline or wellbore.

Tracking is based on analysis of induced pressure waves within the conduit. Data such as pig position, velocity and estimated time of arrival can be calculated. The method discussed has recently been successfully used to track pipeline pig location on a large diameter pipeline project in the middle east. The pipeline had a stuck pig from recent commissioning activities. The location of the pig was unknown. It was also unknown if the pig was stuck or still moving slowly.

Pressure wave technology was mobilised to the site. An initial analysis confirmed the location of the pig. A further analysis a short time later confirmed the pig was not moving. A remediation plan was put in place to retrieve the pig and pressure wave technology was used to track the location of the pig during its recovery.

Through successive testing, the live pig velocity was calculated and from this an estimated time of pig arrival. The pig arrived in the pig receiver within minutes of the predicted arrival time. Live tracking provided confidence to the pipeline operator that the remediation methods were going to be successful and allowed optimisation of subsequent commissioning activities.

Case study on the successful deployment of a series of next generation Above Ground Markers (AGM’s) complete with EM detectors and geophones.

Enabling a pipeline pig passage to be recorded (even without functioning transmitters) and the data stored internally as well as confirmation of the movement being disseminated via text and email without any human intervention.

AGM’s are placed in pre-agreed locations prior to pig launch where they lay idle until remotely confirming passage. This reduces costs, increases safety of people and gives better locational information of the pig in the line in case of any hang up in the line.

These movements are automatically added to a web app showing the progress of the tool to, from and in-between markers. Calculating real time ETA and speed.

Before the new pipeline was put into operation, because there was no medium in the pipeline, the inspection tool had no forward driving force. At present, the detection of pipelines before commissioning mainly relies on air or water as power, which has a huge cost. Moreover, due to the compressibility of air, the operation of the inspection tool is unstable, so that the accuracy of the detection result cannot be guaranteed.

Our company has successfully developed an in-line inspection tool that does not need to be driven by the medium in the pipeline and can realize autonomous crawling. The self-crawling detector adds a driving section based on traditional in-line inspection tools. The electric drive section carries different sensor modules to realize multifunctional detection of newly-built pipelines. For example, it can realize deformation detection, crack detection, centerline mapping, stress detection, etc. The cumulative inspection mileage of 762mm, 813mm, 1016mm pipelines has been over 1,000 kilometers, which has a good inspection application effect.

The self-crawling new pipeline detector provides a new detection method for pipeline inspection before commissioning.

Subsea pig launchers are a feature of multi-phase production tie-backs and gas export pipelines from FPSOs for example. Their design is critical to their operability. In general, pig launch from such a unit is expensive and it is very important to ensure that the launcher is fit for purpose. This paper discusses the basic launcher layout and Functional Requirements in order that they have the necessary features to allow them to be used effectively for the life of the pipeline. Operational pigs, inspection tools and possible intervention tools such as plugs need to be considered. The launching method is discussed with a focus on the use of hydrocarbon gas to kick the pigs off in comparison with the use of a nitrogen or MEG downline for instance. Pig loading, deployment and storage is set out along with the ability to safely launch pigs into the pipeline and the pros and cons of each launch method are presented. A comparison between launching with a downline or with hydrocarbon gas is made and the guide to how this could be decided is provided.

Regular attendees of the PPSA seminar in Aberdeen will recall the initial introduction of Acoustic Resonance Technology (ART) back in 2017 – which at the time included many theoretical applications for the technology.

This paper will develop upon that paper and explore a selection of interesting, practical applications of ART with a specific focus on the evergreen topic of challenging/unpiggable pipelines.

The inherent characteristics of ART permit inspection of pipelines that may have proven unpiggable with conventional techniques. Specific challenges this paper will cover include multi-diameter pipelines; Bi-Di requirements and pipelines susceptible to wax. NDT Global will explore the challenges, solutions, and outcomes of a variety of actual projects to cover these specific challenges.

Pipeline pigging projects are streamlined and made more transparent at all phases and to all stakeholders through the use of cloud-based virtualization and mapping of pigging operations.

Cloud-based software platforms which send and receive data and images from ground-based AGMs, signallers, tracking equipment and personnel can provide near-real-time pig positions and status during pigging operations to users.

Pipeline pigging operations created in such online platforms have a high degree of reusability – permanently capturing man-hour investments in all aspects of the survey and run process providing strong ROI.

Safety is enhanced as the number of personnel required to be present on a pipeline is reduced. Pig passage events are automatically transmitted to the cloud 24 hours a day and pigging activity can be monitored and commented on from anywhere.

Managers can coordinate and monitor multiple jobs simultaneously, further reducing the number of man-hours consumed by a single run.

Safety is increased as stakeholders can receive instant notification of changes to a project as well as potentially hazardous developments such as inclement weather, nearby lightning strikes, heat/cold/UV alerts and more.

Run virtualization and recording provide unique techniques unavailable to traditional pigging operations. One example: should a pig become stuck, operators have the unique ability to “rewind” a run’s state to the precise moment when pressures spiked, getting a snapshot of the pipeline at that instant.

Permanent database storage of completed runs allows for easy reference to work done previously, and also provides for rapid comparisons of multiple runs year-over-year and can lead operators to identify developing problems on their lines.

The inability to access existing pig launching and receiving facilities due to inadequate isolation capability is a common access constraint for pipelines. The lack of adequate isolation valves or pipelines where launchers or receivers are absent can result in essential pigging activities being delayed or conducted less frequently than required.

This paper will explain how the appropriate application of temporary double block and bleed pipeline isolation tools, and if required hot tapping intervention techniques, can be used to create or restore safe access to pipelines for pig loading and removal operations.

The explanation will be supported with industry examples and case studies demonstrating how safe access for pigging operations can be provided cost effectively, and without affecting production or depressurising the pipeline.

Determining how to inspect pipelines can be challenging when information often deemed critical by ILI vendors is not known.

Older pipelines with no previous ILI history may lack documentation: perhaps there have been undocumented repairs, records have been lost over time (especially when an asset changed ownership), or knowledge has been lost when key personnel retired.

Equally challenging is inconclusive information, for instance, a damaged gauge plate. It indicates a restriction, but does not provide information on where or what. These ‘unknowns’ are what defines these pipelines as unpiggable.

Two case studies will be presented, both involving offshore pipelines.

1. The first case study involves a shallow water offshore 10x12” dual-diameter pipeline. Previous experience with pipelines in the same field indicated a possibility that 8” valves had been used.
2. The second case study considers a 14” pipeline, where a prior gauge pig run indicated a restriction to 262mm. The suspicion by the client was that there was a reduced bore valve in the system.

In both cases, the pipelines were inspected using an ILI tool with a wide operating envelope. The large operating envelope compensates for the lack of information, while minimizing the risk of a damaged ILI tool or a stalled pig scenario and sheds light on those unknowns.

Pigging is often a non-routine operation and managing the risks is a significant challenge to operators / pigging vendors who do not have an intimate knowledge of the pipeline. The typical industry practice is to address the primary pigging challenges with progressive cleaning, pig tracking and stuck pig contingency planning. When these considerations are made with an in-depth understanding of the pipeline system behavior these risks can be managed better. Conventional pipeline systems do not allow this insight to eliminate these pigging risks.

A new approach to digital pipeline integrity management has been developed using spirally wound optical fibre embedded in the pipe structure. This provides a very intimate connection to pipe behaviour making real time monitoring of pressure temperature, stress / strain, vibrations, etc., possible for every 0.2m of the pipe. MASiP is designed intuitively to track pigs, locate stuck pigs and optimise pig cleaning schedules.

The base measurements provide an accurate alerting system for third party interference, ground movement, illegal tapping, leaks, etc. Integrity management then becomes proactive pipe health management and not time-based inspection. The paper will also describe the pipe structure with the integrated fibre optic sensor and recent trials.

Hydrogen is the smallest, lightest, most abundant element. Hydrogen gas is also extremely flammable with a lower explosive limit of 4% concentration and an upper explosive limit of 75% concentration. There is a growing network of hydrogen pipelines owned by merchant hydrogen producers operating in the United States: 1,600 miles (2,575 km) are already in place and one marketer of industrial chemicals and gases has already announced plans to add about 100 miles (161 km) of hydrogen pipelines in the next few years. It is mostly used in refining gasoline, but is also used in fertilizer, and food processing transportation. Throughout their lifecycle, hydrogen gas pipeline assets need to be inspected periodically for safety and integrity material. Magnetic flux leakage (MFL) is a robust and trusted technology for in-line inspection (ILI). MFL is very useful for detecting and sizing both internal and external corrosion in gas and liquid pipelines. MFL tool design has relied on well-established materials susceptible to hydrogen embrittlement, which occurs when a material is mechanically stressed while being exposed to hydrogen. This reduces material tensile strength and ductility, affecting the performance of traditional tools.

Successfully inspecting hydrogen-carrying pipelines while reducing the risk of hydrogen embrittlement requires the use of alternate materials and methods to develop a capable ILI tool. This white paper and presentation will discuss challenges of this unique inspection environment, which were addressed through innovative ILI tool design resulting in a successful pipeline assessment.

Five fields produce oil and gas through commingling manifolds to an FPSO using two main production pipelines. Both lines have exceeded their design life and are known to suffer from a level of corrosion. Inline inspections performed in 2013 and 2019 provided the basis to allow extending their operational life.

Before 2013, the 12” pipeline loop was un-inspectable. Obstacles are present that prevented passage of standard ILI tools:

• Tool launch & receive at rotating turret with limited trap length and working area
• Connection to the FPSO via flexible piping with reduced 10” diameter and sensitive internal carcass
• 12” flexible piping with larger internal diameter between the manifolds (installed after 2013 ILI)
• Heavy walled topsides and pipe-in-pipe subsea
• Known presence of debris

Duplex pipe material affects inspection measurements

GEO+, MFL & UT inspection tools were designed and built to negotiate the existing pipeline configuration. A special test loop was constructed to simulate the obstacles. Tool passage and performance were verified and demonstrated in factory acceptance pump tests before being applied in the target pipeline offshore. Cleanliness assessment and metal loss integrity status of the pipeline were provided to the operator. Comparison of the results was used to prepare a corrosion growth assessment.

Pipeline cleaning is often undertaken to manage flow assurance issues such as slugging, corrosion, wax, sand accumulation etc., and for internal inspection. In addition, pigging offshore pipeline assets is, in many cases, becoming increasingly challenging with the development of more deep water applications, the use of exotic materials and increasingly demanding operating conditions. 

This paper will demonstrate how ROSEN has successfully applied advance flow assurance service by combining flow analysis along with pigging feasibility studies in order to optimise pigging operations in very challenging onshore and offshore pigging applications. This integrated approach has shown significant benefit in: quantifying risks, evaluating mitigation strategies, confirming pigging feasibility and optimized pigging campaigns. Advanced flow assurance analysis has helped operators to achieve project goals safely, effectively and within budget.

This paper will demonstrate where integrating flow assurance tools with pigging feasibility expertise can support operators with the execution of complex offshore pigging operations, and provide a few case study examples to illustrate this.

Often the main focus of inline inspection (ILI) is the inspection vehicle itself; however, the ultimate goal of any ILI operation is reliable and accurate data. This end goal can be challenged by the operational variables that many inspection companies are faced with, for example: line conditions; geographical complexities; changes in pipeline construction.

This paper explores the main factors that contribute to delivering the reliable and accurate inspection reports which pipeline operators demand whilst overcoming complex challenges and several coexisting, non-standard conditions.

A case study will be used in collaboration with IKM (EPC) and Var Energi (Operator) to focus on a unique project, running an inspection vehicle from a subsea pipeline launcher/receiver (PLR) to the Goliat Platform which is the Northern-most oil and gas production platform in the world.

This review is particularly valuable for operators of remote offshore pipelines with subsea launch and receive traps, where utilising ILI technology may not have previously been considered possible.

Geohazards in the form of earthquakes, landslides, mining subsidence, etc., will typically result in ground movement and where a pipeline crosses such areas, it will be subjected to additional distress that may lead to its failure. The geohazard related pipeline failures often drive operators to include rigorous geohazard mitigation strategies in their pipeline integrity management programs. Ensuring and managing the integrity of the pipeline in such cases requires frequent monitoring of the pipeline either by In-Line Inspection (ILI) or above ground surveys (e.g. line walking); however, these can be costly and ineffective to identify all geohazard threats if not performed at the required frequencies.

This paper describes the use of satellite borne synthetic aperture radar (SAR) technology in the monitoring of ground movement in the vicinity of a pipeline as a complimentary alternative to support geohazard mitigation. Differential Interferometric SAR (DInSAR) processing allows for accurate measurements of changes in terrain conditions, which can be in the level of millimetres in terms of accuracy. In addition, we will be looking at how the integrity of the pipeline can be monitored and efficiently managed using the DInSAR system in combination with pipeline strain measurements obtained by running an IMU (Inertial Mapping Unit).

Inline inspection campaigns can cost many hundreds of thousands of pounds to perform, whilst an unsuccessful pig run can cost an Operator significantly more. This is especially true for subsea pipelines where access is restricted, and remediation is complex. In order to help reduce this risk, many Operators chose to use pig tracking systems as a standard component in any pig run.

Tracerco’s proven pig tracking system has recently been involved in a successful inspection campaign on an extensive pipeline system. The pipeline was known to have a history of deposits and bore restrictions which had the potential to impede the inspection run. By using Tracerco’s pig tracking system, the Operator was able to accurately monitor the pig passage even through changes in the pipeline’s design.

This paper will outline the challenges facing the Operator which led to them choosing Tracerco for their pig tracking services, through the project process to the conclusion of the project, including NORM services.

Part of integrity management, pigging is performed as a standard, regular operational activity throughout the pipeline network’s lifecycle. Pipeline operators have been running pigs successfully for years. However, every so often, a problem occurs and a pig becomes stuck, stalled or damaged in the pipeline.

When another service provider’s bi-directional pig became caught up in a production tee during routine operational pigging, the operator of a 240-km, 28-inch gas export pipeline in southeast Asia contracted T.D. Williamson (TDW) to recover it.

Fortunately, the pig had stopped half way into the tee and was not blocking production flow entirely. However, the concern was that the pig could move further into the line and completely obstruct production flow, leading to shutdown of production gas.

After considering multiple options for recovering the bi-directional pig, the operator, together with TDW decided to use mechanical means. TDW designed, manufactured a bespoke recovery tool then tested it in a mock-up of the launcher and tee that replicated the stuck pig scenario. This enabled a successful pig recovery operation offshore.

This paper describes the steps taken to execute the pig recovery, including planning, site visit, engineering, tool manufacturing, testing and execution.

Pipeline blockages caused by scale, wax build-up or hydrates can sometimes be removed by non-invasive techniques, such as chemical treatment or pulsed blockage removal technology. Some pipeline blockages may have been caused by normal operational pigging or more likely due to cleaning operations prior to inline inspection (ILI). Recently we have become aware of several ILI tools causing partial or complete blockage of the pipeline.

When non-invasive techniques have proved unsuccessful or unsuitable then a more invasive blockage removal intervention may be required. The less invasive method of blockage removal would be to inject and flush locally, via small bore hot taps through a dual seal, self-energised, lightweight strap clamp.

If the blockage cannot be removed by local flushing / chemical injection, then the blocked pipeline section may need to be completely removed and replaced. If a temporary bypass is installed, production can be resumed while the blockage removal operations are executed. This short presentation will explain how type approved double block and bleed hot tap installed isolation tools enable the safe removal of the blocked section while the pipeline is at operating pressure.

Animations and footage of recent subsea pipeline intervention projects will be used to highlight the applications of these techniques.

There have been significant advances in magnetic flux leakage (MFL) in-line inspection (ILI) technologies in recent years. These have led to improvements in Probability of Detection (POD), Probability of Identification (POI) and Probability of Sizing (POS).

Whilst often the main focus of these advancements is the inspection vehicle itself, the end product of an inline inspection service is reliable and accurate data. This end product is influenced by various technological factors which include: recognition and detection algorithms; complex sizing models; robust and rigorous processes and highly trained and skilled data analysts.

This paper explores all the main factors that contribute to delivering the reliable and accurate inspection reports that pipeline operators demand today. This review will be supported by extensive comparison of ‘as reported’ data vs ‘in ditch’ findings. This is particularly valuable for operators of offshore pipelines, where proving ILI performance is at least challenging, and often not possible.

Data from cleaning pig runs with data logger has been combined with operational data i.e. flow rate and pipeline information e.g. joint length. Main parameters from the data logger are acceleration in three directions, differential pressure and temperature. From the data wax deposition zones can be estimated and pig speed for each pipe joint can be calculated. By comparing the calculated joint speed with calculated speed based on bypass, it is possible to conclude if the bypass set up has been fully open during the run. This information is a useful input to the wax cleaning program. The analysis is performed in MATLAB partly with MATLAB software partly with in-house written software.

Cracks and linear anomalies are common threats in the pipelines. The origin of these features can be caused by manufacturing related processes or they can appear during operation.

ILI inspections use techniques such as EMAT or Ultrasonic Shear Wave following the principle of Pulse-Echo to detect and size these anomalies. However, such techniques have limitations in detection and sizing when the features are not radially oriented. Features that do not fulfil this condition can be considered complex, hook cracks are one example of such features.

The latest development from NDT Global, Evo Eclipse, is the result of an extensive research and testing program. This development is designed to overcome limitations from current status quo ILI techniques and provide an alternative to accurately size tilted (i.e. hook cracks) and skewed (sloping) features.

In-line inspection of offshore pipelines using conventional tools and procedures is not always possible, due to a combination of various challenges. This paper discusses a recent example of such a case: the in-line inspection of an 8” fuel gas line feeding a platform located in the North Sea.

The pipeline was found to have a leaking Sub Sea Isolation Valve (SSIV). The SSIV is about 755 ft. (230 meters) away from the platform and riser. In addition, the topside Emergency Shut Down Valve (ESDV) had failed in the open position. Due to a combination of the ESDV being in an open position and the SSIV slowly leaking it was determined that the riser could not safely import the gas to power the platform. The SSIV was closed but since it was slowly leaking the riser was regularly bled to ambient pressure with the gas being sent to the flare.

In order to provide critical safety isolation of the fuel gas pipeline, the ESDV needed to be replaced. The integrity of the riser then needed to be confirmed by performing an in-line inspection. However, for the inspection to successfully take place, several challenges had to be overcome, including:

• Single access point
• No pig trap installed
• No flow and line filled with fuel gas
• 8˝ rigid steel riser connects to 10˝ flexible, the SSIV is located after the flexible

The ROSEN team, together with the operator, settled on a free-swimming, bi-directional, UT inspection solution. In order to provide a couplant for the UT, a liquid batch was proposed to be used. To overcome the fact that there was no flow possible, the team agreed to use external pumps to propel the bidi UT tool in a liquid batch into the riser, while, at the same time, compressing nitrogen against the SSIV. Once the tool had reached the desired location, the compressed nitrogen was used to push the pig train back to the launcher.

This paper will discuss why this solution was selected and how the collaboration between ROSEN and the operator successfully tackled the challenges to develop and apply the free-swimming UT-based solution and safely inspect the pipeline.

A combination of complex economic conditions and diminishing production in mature fields continues to drive growth in the oil and gas decommissioning market. Whilst industry attention tends to focus on well plug and abandonment or topside removal and dismantling, subsea infrastructure poses its own challenges. When a pipeline system reaches the end of its operational life multiple options may exist for cleaning and decommissioning. Pipeline configuration, condition, contents and available disposal routes will all have a bearing on the chosen methodology. A five-year decommissioning programme of over 1,800 km of multiple subsea infield and export flowlines of varying diameter, has offered a unique opportunity to utilise experiential learning to apply best practice to pipeline end of life.

The Pathfinder foam geometry tool was originally developed as a low risk, cost effective soft bodied tool for measuring pipeline geometry. In recent years through continuous improvement the Pathfinder has developed into a recognised, well established technology with an extensive track record for pipeline proving, internal diameter profiling, bend measurement reduced bore location, debris mapping and assessment.

Pathfinder is currently being used by service companies and operators a like on a regular basis to support a wide range of pipeline construction, commissioning and operational workscopes around the world.

This paper sets out to demonstrate the functionality of the Pathfinder and the extent of its operational capability through several high level case studies.

Innovative design developments and current trials on further improving minimum bore negotiation capabilities are also introduced.

Pipeline Innovations’ changing approach to pipeline pigging data acquisition has led to further development of the Pathfinder electronics operating platform to provide a range of standalone pipeline data loggers. The specifications and operational benefits of which are also discussed as part of the technical paper.

When planning a pipeline cleaning campaign, an operator often has limited knowledge of the actual conditions within the pipeline and therefore uses a conservative approach based on assumption and experience to design a pigging program for a pipeline. This therefore limits the ability to plan pigging operations optimally, cost effectively, and safely.

Using currently available pressure wave analysis technology, pipeline operators can non-intrusively survey their assets to obtain a clear understanding of the pipeline’s deposit profile in a safe and cost-effective manner, without having to stop production or risk inserting tools into the pipeline. This information can then be used to identify the best approach forward for cleaning the pipeline based on the analysis results. The pressure wave analysis provides the internal pipeline bore and key data points to consider, such as whether the pipeline is in a piggable condition, requires chemical treatment, or a more direct intervention is recommended. Whichever method is necessary, the knowledge achieved by performing a non-intrusive survey upfront helps ensure pigging or maintenance is executed effectively, economically, and with minimal risk. This technique can be further implemented throughout any pigging campaign to track and optimize the program as it progresses and confirm the efficiency of the pigging methodology.

The paper discusses how using this latest pipeline deposit surveying technique allows operators to plan a pigging campaign in a safe, timely, and cost-effective manner.

This paper presents a novel approach to flexible riser life extension through FlexIQ which combines inspection data with a fully simulation-based irregular wave approach to provide life extension assessments.

FlexIQ combines the two proprietary technologies: MEC-FIT™ inspection technique from Innospection and FLEXAS™ numerical solver from Intecsea which allows high-resolution stochastic fatigue life to be captured based on realistic conditions. Reducing uncertainty in the design calculations enables operators to continue operating their assets safely and with improved confidence.

FlexIQ has established a step change for industry technology and has been recently successfully deployed on two offloading risers in West Africa with a total inspection length of 2.5km.

Field experience on how FlexIQ has been used to re-evaluate the design life and determine the suitability for life extension of the risers will be presented.

The analysis predicted safe and reliable operation of the assets well beyond the original design life, provided the asset management recommendations made within the study are adhered to.

Oil is exported from the Gannet platform to the 3^rd party operated Fulmar platform via a 16” 107km pipeline.

An alternative export route is required as the Fulmar platform will cease production prior to the Gannet field. A project is underway to bypass the Fulmar platform and tie directly into the Judy 24” pipeline and subsequently into the 34” Norpipe system terminating at Teesside.

Operational pigging for the existing 16” pipeline from Gannet to Fulmar is currently completed on a 2-weekly frequency to remove wax and water drop-out using bi-directional pigs.

The new routing will require the use of pigs that can traverse the complex geometry of the new Gannet oil export routing with changes in diameter from 16” to 24” and 34”.

A series of optimisation trials with a pigging vendor have been completed with the purpose of designing and testing a pig that can clean the 16” and 24” pipeline sections and remain neutrally buoyant in the 34” Norpipe system.

The paper will share the details of these trials, collaboration with the pigging vendor to optimise the pig design and share the findings and benefits of the technology to the wider oil and gas industry.

In-line inspection of offshore aging pipelines can become an increasingly challenging task, for example because of wax build up or depleting production and consequently low flows.

This paper discusses a recent example of such a case: the in-line inspection of PL120; an offshore 18”-20” pipeline that transports stabilized crude oil from Beryl B to Beryl A platform in the North Sea.

The challenges to inspecting PL120 can be summarized as:

• Pipeline operates at low pressure and with low flow
• Is known to produce wax and is difficult to clean
• Has complex geometry (short traps, 1.5D b2b bends, large ID variation)

Despite comprehensive pre-inspection cleaning campaigns, attempts to inspect the line using UT technology failed because of excessive wax on the internal surface of the pipeline. Although MFL technology is generally better able to deal with waxy debris, the magnetic forces make it significantly more difficult to negotiate a geometrically complex line with unfavorable operating conditions. This paper will discuss how the Apache – ROSEN team tackled these challenges and successfully developed and applied an MFL based solution that could safely inspect PL120.

State of the art and future assessment methodologies for geometrical defect types in pipelines benefit from superior inline inspection data. Post-inspection assessment of deformations such as strain, fatigue life, or finite element modelling require the most detailed, accurate and high-resolution data of the pipeline available.

Therefore, NDT Global has developed and validated a fleet with a new, reliable, and robust technology for pipeline geometry measurement, based on the ultrasonic measurement principle with inherent advantages such as bidirectional capabilities and wall thickness data acquisition in one pass.

Since the first successful commercial inspection in March 2016, the Atlas UG tool fleet has successfully conducted more than 3,100 km worldwide, achieving a 100% first run success rate and received positive feedback from operators.

Extensive testing and field verifications prove the accuracy and reliability of the ultrasonic technology.

This paper is a case study on development and implementation of pipeline integrity management system (PIMS) for a medium enterprise operator in the Middle East. It explains the collaborative and stepwise learn-do approach adopted by the operator’s focus group that helped in showing the value proposition of the system to higher management at each phase of the project.

PIMS must address elements such as people (organised team of various disciplines contributing to the overall objective i.e. pipeline integrity management), process (standards, procedures and policies on how to achieve the objective) and tools (resources to achieve the objective) to manage pipeline integrity. This paper describes the way BHGE and operator have worked collaboratively and adopted a stepwise approach to address all these elements to setup a PIMS within a limited budget. The process consists of PIMS gap analysis, development of procedures and excel based comprehensive semi-quantitative risk assessment, and contracting strategy resulting in utilising the PIMS contractor as a trusted partner.

The paper highlights the challenges that arise while implementing a management system how these were resolved through knowledge transfer, technical workshop, astute contracting strategy and utilising contractor as a trusted partner. It explains how the subject matter experts from the contractor are utilised to manage the pipeline network through a risk ased approach before investing on in-house software tools and personnel. It further describes the practical steps adopted in setting up risk based PIMS within limited budget and could be used as a road map for other medium enterprise operators.

Even very slight temperature variations can cause a disruptive “suck and blow effect” effect within pipelines, which can prove problematic during welding activities. In 2016 Aubin provided elastomeric plugs designed to resist the pressure differential, to temporarily plug the pipe. Once the plugs were in place, welding operations would commence, then the pig train would be extruded through a subsea discharge port.

The client provided design constraints, causing Aubin’s in-house engineering team to design a specialised pig launcher. The constraints were:

• Removable
• Easy to use
• Doesn’t require a flanged connection
• Mechanical pig launch
• No contact between duplex pipe and any metal.

The designed pig launcher used a nylon disk to push the elastomeric plug into the duplex pipeline, and was operated using a battery powered drill, which was supplied with the pig launcher.

Feedback from the client was that the launcher and pigs performed perfectly, as well as they had during testing. The pigs were inserted into three different dry lines, approximately 30Km long. The pigs were left in the lines for seven months, before being extruded through a 1” port subsea. The client is now planning to use these plugs in other welding and plugging operations.

Making infrastructure modifications to install launchers and receivers on gas gathering lines will typically cost 5-6 figures per line. The ability to pig gas gathering lines without making such modifications could offer flow assurance and corrosion prevention without the associated cost and downtime.

In this paper we describe the successful use of an elastomeric pig to dewater a gas gathering pipe in Colorado with no launcher or receiver, resulting in the complete restoration of flow in a pipe that had suffered from a differential due to water accumulation in low spots. The pig was inserted at a temporarily dropped spool and removed through a blowdown valve making use of its ability to be extruded through reduced bore piping.

Subsequent to risk based inspection (RBI) and corrosion assessment, it was highlighted that several operator pipelines in the North Sea required internal inspection to verify line conditions and to ensure that the pipelines were fit for purpose. It was recognised that some of these pipelines were not readily equipped for pigging operations and challenges existed to enable inspection of the lines. The most feasible means of obtaining detailed inspection data was to perform intelligent pigging (IP) operations, requiring the installation of temporary subsea launch/receive facilities, which were also used to allow pipeline cleaning using a combination of chemical applications, progressive pigging, and pipeline gauging before the IP tools were run.

Crack inspection of pipelines using conventional ultrasonic technology has become a standard application for in-line inspection (ILI) of liquid pipelines. Crack inspection tools have proven very successful for the detection of various types of cracks (e.g. SCC) or crack-like anomalies present in many pipelines worldwide. The first inspection tools were developed for axial crack inspection (UC), as most cracks or crack-like defects in pipelines are axially orientated. In some cases, however, circumferential cracking can occur prompting the development of tools for circumferential crack inspection (UCc). Standard crack inspection tools can be applied in most liquid pipelines transporting typical crude oils or products (e.g. diesel).

Over the years, specific inspection requirements came up that were not covered by the first tool generations. These requirements are related to different aspects of the inspection process ranging from tool-related characteristics to inspection-related challenges such as crack inspection in liquid gas. Consequently, those challenges are addressed by the latest tool developments allowing an inspection performance not possible before with regard to inspection speed and measuring resolution. In the paper, the achieved progress including enhanced depth sizing is described and illustrated by examples from inspection runs.

In-line inspection of offshore pipelines is a challenging task for several reasons, including:

• Many pipelines that were not designed to be piggable, now require inspection
• Change in operating conditions resulting in ultra-low flows and pipelines with bore restrictions
• Presence of in-line components including non-return valves, hot tap tees, etc.
• Demand for reduced operational impact as a result of pigging operations

Offshore pipelines distinguish themselves from onshore lines because external reference measurements and local repairs are often complex and challenging. Furthermore, inspecting offshore pipelines is often more demanding because of logistics, accessibility, and cost.

Consequently, tool performance, first run success, risk mitigation and operational impact are key factors to be considered when selecting an inspection solution. Additionally, in order to successfully execute these inspections, expertise from both the operator and inspection contractor, need to be combined in a multidisciplinary team that operates as ‘one team’ and establishes the confidence and trust in each other to make the correct decisions.

This paper will discuss a recent example of such a challenge: the successful inspection of a key Shell U.K. Limited (Shell) pipeline in the North Sea, which required a bespoke solution to overcome the pigging challenges associated with this pipeline.

The inspection of subsea pipelines, in particular - flowlines and gathering lines – has recently moved into the focus of offshore engineers. Contrary to most long-distance export pipelines many of these lines are unpiggable. While some of these lines can be inspected with tethered internal inspection tools the only inspection options until recently for the majority of the lines were visual testing, CP-surveys and local defect monitoring. With the MEC™-Combi Crawler system and the PECT inspection system it is now possible to gather integrity information to a level of accuracy that can be compared to in-line inspection, but is obtained by external scanning. This level of accuracy permits carrying out defect assessment based on inspection data. Case studies are presented for each inspection technique – Magnetic Eddy Current (MEC) and the Pulsed Eddy Current Technique (PECT) to show how the subsea inspection tools are adapted to fit the specific inspection task.

Traditionally, pipeline pigging has 2 extremes. At one end of the spectrum are cleaning pigs and at the other end are In-Line Inspection (ILI) tools or “intelligent pigs” and there is little that sits between. Cleaning pigs are basic tools that are frequently and easily deployed and carry little operational risk of lodging in the line, however, they gather little or no data. ILI tools are far more complex by design as the industry demands higher specification, greater accuracy and the ability to detect more types of pipeline defects. The consequence of this is larger tools needing specialist technicians, never mind the increased support and handling equipment as well as tight operating parameters and run scheduling. Operators have identified a need for tools in this middle ground of the 2 extremes and have encouraged the development of simple, easy to use and deploy inspection technology that uses advanced electromagnetic sensors integrated on to cleaning tools – or making the simple, smart.

Managing the long term integrity of a critical 10” subsea crude oil pipeline is dependent on being able to use the correct inspection technologies, however, the current structure of the pipeline does not allow for any in-line inspections. Consequently managing the short term integrity of the pipeline becomes a priority until the pipeline is made piggable. This paper describes where and how to investigate along the pipeline to determine the current internal condition of the pipeline.

A desktop feasibility study was completed in order to determine the locations and the confidence in the use of an external ultrasonic scanning survey (auto-UT) to determine the short term integrity of the pipeline. This comprised the following:

• Review of product composition and assessment of potential corrosion threats.
• Technical identification of the points along the length of the pipeline that is most susceptible to internal corrosion.
• Confidence in evaluating condition of pipeline based on auto-UT

In addition a review of the current sacrificial anode protection of the pipeline was completed to ensure that any investigative works completed would not result in any external corrosion issues.

Remote controlled, tethered isolation plugs and hot tap installed line-stop isolation tools are regularly used to provide fully proved double block isolations, enabling valve replacement or repairs without having to depressurise the entire pipeline. This type of isolation work scope could be described as conventional. Although, due to the safety criticality of any pipeline isolation, each application is engineered, tested and risk assessed against project specific parameters.

Isolation plugs are also used in unconventional, innovative ways throughout the pipeline life-cycle – from cradle to grave. This paper will describe case studies where isolation plugs have been used in non-standard ways to solve pipeline problems during the various phases of a pipeline’s life.

During the construction phase, isolation plugs are used to facilitate pipeline recovery in the event of a wet buckle. To enable recovery of large diameter or deep-water pipelines, the catenary section of pipeline to be recovered off the seabed usually requires to be dewatered. To dewater the catenary section, isolation plugs are deployed subsea, either via a diverless subsea launcher or via a pipeline retrieval tool with a cassette sleeve that contains the isolation plug.

During the operational phase, midline sectional replacement and repair may be required. In the case of an unpiggable defect, isolation plugs have been developed that can be pigged from either end of a pipeline towards each other, allowing the isolated section to be vented, cut out and replaced. To facilitate leak-testing following the repair an additional leak-test module is utilised and high-integrity pressure equalisation is used to safely unset the plugs.

Finally, for pipeline abandonment and decommissioning, isolation plugs are used to permanently plug and abandon pipelines. These isolation plugs can also be used to install a subsea bypass allowing platforms to be removed.

Pipeline pigging is a standard regular operational activity performed throughout the pipeline lifecycle and forms part of the Integrity Management System of a pipeline network. Typical examples of pigging applications include pre-commissioning, line-proving, cleaning, liquid removal, batching, inline inspection, inline isolation, and decommissioning. Key to all these activities is the ability to track the pigs in the pipeline, locate the pigs when necessary, and identify each pig when multiple pigs are in use at one time. More complex capabilities required are the ability to communicate, interrogate, and activate the pigs through the pipeline wall and induce sleep modes on transmitters, enabling battery life conservation during long operations.

Pig tracking can be performed by various methods—with devices fitted to the pig such as transmitters (electromagnetic or acoustic signal) or radioactive sources. External devices such as pipeline-fitted pig signaling devices, acoustic listening devices, or pressure pulse monitoring systems can also be used. The operational requirements and limitations of pigging activity will determine the best solution for tracking and monitoring.

Tracking of pigs in an offshore pipeline is challenging due to the environmental conditions. The pipelines tend to be constructed of thicker wall material (>15 mm) and are surrounded by large steel structures (platforms) as well as cyclic oscillating systems (pumps, turbines, etc.). Subsea sections may be covered for protection by rock dump, steel structures or buried below the seabed. These conditions provide challenges to transmitter tracking systems.

In the 1990s, T.D. Williamson designed and developed its proprietary inline isolation SmartPlug® tool, for isolation of a pressurized pipeline. The design requirements of this tool were that it could be pigged to an exact location, and once at the location, it could be remotely activated to effect the isolation. Once activated, it was essential that the system be remotely tested and monitored throughout the duration of the isolation, providing a safe controlled environment for the required works to be carried out. Communication capability at 100% was to be maintained throughout the operation. Due to the criticality of these design requirements, standard off-the-shelf transmitter systems were not found suitable for tracking the SmartPlug isolation tool.

Therefore, T.D. Williamson developed its own purpose-built system to support the SmartPlug tool, which was branded as the SmartTrack™ system.

In line inspections are commonly used to ensure safe operation of oil and gas pipelines. These inspections provide reliable information on the status of the pipeline’s integrity. Traditionally, gas pipelines are inspected using magnetic flux leakage (MFL) technology, and liquid pipelines are inspected using either MFL or ultrasonic wall measurement (UTWM) technology.

Recently, an additional technology has been introduced to the market, based on acoustic resonance technology (ART). This ART technology allows for the inspection of both liquid and gas pipelines with acoustic testing. The ART technology overcomes typical limitations of the prior state of art, such as limited wall thickness capability and speed (for MFL) and cleanliness criteria (for UTWM).

The authors will present the theoretical background of Acoustic Resonance Technology, and practical applications at a product level.

Furthermore, practical applications will be presented where the technology was applied in-field, in the North Sea area. Specifically; 2 occasions will be discussed of crude oil pipelines in the North Sea, which experience wax deposition to such a level that sufficient cleaning for UTWM inspections was not possible or cost-inhibitive.

Ice Pigging is a cleaning technique, mature in the water / wastewater industries, which is being developed for the Oil and Gas industry.

A high-solids ice slurry is pumped under pressure to deliver a wall shear stress on the pipe, cleaning it through physical abrasion. Made of just water and salt, ice pigs do their cleaning, unblocking, debris entraining and transport before melting back into their original components (commonly salt and water); offering a physical clean thousands of times more effective than flushing, without chemicals or risk of getting stuck.

The trails, which are the subject of this paper were commissioned by Royal Dutch Shell plc, using funding from their Gamechanger innovation program.

3D LASER SCANS are becoming increasingly popular for field verifications, and pipeline operators are demanding a corresponding ultra-high-resolution inline inspection technology capable of producing refined integrity calculations.

Ultimately, such an ultra-high-resolution inline inspection technology would lead to improved pipeline safety while simultaneously reducing the need for costly field verifications.

Hence, an ultra-high-resolution MFL technology with sensor spacing similar to that of a 3D laser scan has been developed.

In order to provide reliable inspection results using a ultra-high resolution MFL measurement system, a series of challenges had to be overcome:

• The extremely tight track spacing requires continuous data recording without any gaps in circumferential direction. This calls for accurate mechanical design to ensure each sensor stays exactly in its track, especially when passing welds.
• There can be a significant impact on the recorded data quality due to sensor placement on the yoke in relation to the magnetic field. Specific normalization efforts are required to ensure a uniform appearance of data for subsequent evaluation.
• The sheer amount of inspection data generated warrants the use of machine-based learning algorithms in data evaluation, reducing the ‘human factor’ impact.

In addition to presenting solutions for the above listed technical challenges, this paper will also provide insight into how pipeline integrity management will benefit from ultra-high-resolution MFL inline inspection results.

A 28" sub-sea pipeline supplying gas to Hong Kong was damaged by an anchor drag 278km from Hong Kong in 90m of water. The damage involved two subsea Pipeline End Manifolds (PLEM) and also dented the pipeline adjacent to the North PLEM. This paper details the repair of the damage using a combination of non-piggable and piggable isolation tools.

A model to examine pigging and inspection of gas networks with multiple pipelines, connections and customers is presented in this paper. A case study of a typical gas system with multiple lines, connections and off-takes is presented to demonstrate the use of such a model for planning and executing real life operations. A gas flow rate is provided into the network to the various users of the network or grid. Each customer has a requirement for both a minimum pressure and a minimum flow that cannot be disrupted without agreement or penalty to the operating company. Additionally, inspection or ILI tools must be run within certain velocity constraints to allow reliable data to be achieved. Due to the complexity of the system, there is a risk that the pig could stall in the line as flow is diverted as a result of the pigs own differential pressure. Manipulation of valves and flows must be planned and performed carefully so as not to disrupt the demands of the various customers in the network. Excessive pressure drop across closed valves is undesirable if they are to be opened during the operation. Pigging the system is onerous due to the need to balance the requirements of the pigs and the demands of the customers. The pig run time or expected arrival time with transient events such as valves opening, changes in flows, disruption to customers and other transient events is calculated. The paper presents the model and its use to optimise pigging programs in gas networks.

Pipelines manufactured from corrosion-resistant alloys (CRA) are becoming more common in special applications, in particular with offshore pipelines which are in many cases exposed to a harsh and highly corrosive environment. For many years the inspection of CRA pipelines (solid CRA, clad and lined pipe) was not a high priority. Due to the special composition of these types of line pipe it also posed specific challenges to in-line inspection methods as compared to the inspection of common line pipe.

In this article, the different types of CRA line pipe and the relevant characteristics regarding in-line inspection (metal loss inspection, crack inspection) are described. Typical damage mechanisms (e.g. pitting corrosion) that may develop during operation are illustrated and the specific capabilities that are available for ultrasonic in-line inspection as well as the limitations are explained. Several examples from inspection runs in CRA pipelines are presented demonstrating that reliable in-line inspections with good data quality are feasible to a wide extent.

The Congo River crossing (CRX) pipeline system was built to bring associated gases from various fields to a liquefied natural gas (LNG) processing plant in Soyo, Angola. The pipeline system runs a distance of approximately 140 km from the processing plant to the South Nemba platform located offshore Cabinda via two satellite pigging platforms [north pigging platform (NPP) and south pigging platform (SPP)], which provide the location for a drilled conduit that crosses the Congo River.

The pipeline system comprises four segments (A, B, C, and W), running from the South Nemba platform to the Angola LNG (ALNG) terminal in Soyo.

A service company was contracted to perform pre-commissioning services on each segment independently (flood, clean, gauge, caliper survey, hydrotest) before the close-in spools and subsea structures were installed.

Once all segments were completed and tied in, a global leak test was conducted before commencing dewatering operations. Each segment was bulk dewatered followed by final dewatering and vacuum drying before being packed with nitrogen in preparation for first gas.

During the various campaigns, each segment experienced incidents/problems, ranging from stuck centraliser tools, leaking hot stabs, vessel delays, etc., resulting in major delays to the overall project. The pre-commissioning work was successfully completed in early 2016.

Pipeline Engineering opened a Service Centre within the city of Aberdeen, Scotland in 2008 to offer a pigging tool management and tool refurbishment service to the North Sea Pipeline Operators for their routine pigging tools.

Routine pigging tools are used by the pipeline operators to carry out cleaning operations within the production pipelines without impacting on production flow or revenues.

The Aberdeen Service Centre receipts the pigging tools from the customer post run, and then conducts a full service which comprises of cleaning, stripping, inspection, spares replacement, refurbishment, and final testing. The pigging tools are then ready to be utilised on another routine cleaning run.

Once the pigging tool has been fully serviced, a detailed refurbishment report is submitted to the customer, providing visibility on the pigging tools condition and information of the service work carried out by Pipeline Engineering. This pigging tool management and tool refurbishment service has helped customers make large savings on their annual pigging tool costs, whilst also receiving the required engineering expertise to optimise their pigging operations.

The Aberdeen Service Centre has a pigging tool tracking system in place for each customer which highlights their full pigging tool fleet location, condition, configuration, last test date, run details and GA details. This information was previously submitted to the customer on a weekly basis, along with a summary report of all activities. The customers used this system on a regular basis to monitor their pigging tool logistics, and to advise the platform personnel on what the next pigging requirement were to be.

In Q3 of 2016, Pipeline Engineering has upgraded their pigging tool management service to their customers by introducing an Online Pigging Tool Management System. This online management system, with a personalised customer log in, helps each customer improve visibility of their pigging tool fleet whilst providing the option to remotely access the data via a mobile phone or tablet app. Having such up to date data at hand reduces the customers and/or platforms time spent sourcing the required information via the previous method of emails or saved folders.

As the Oil and Gas industry operates 24/7, Pipeline Engineering has created an excellent solution to provide continual all year support to the pigging industry.

This paper describes the optimisation process for cleaning tool maintenance via some customer case studies, demonstrates the software functionality and describes the benefits of having the data at your fingertips.

FlexIQ™ is a complete offering in the arena of flexible riser integrity management from the strategic alliance of INTECSEA and Innospection. This partnership looks to redefine the approach to flexible riser integrity management by offering the best in inspection and computational simulation techniques as part of an Integrity Management Framework. This, in turn, leads to a significant improvement in understanding operational risk and enables a fully integrated service for inspection, analysis and data management. An overview and benefits of the offering will be presented:

• Risk-based integrity management and inspection planning
• State-of-the-art annulus testing of flexible risers
• Visual and MEC-FIT™ Inspection
• Dynamic riser simulation using detailed, multi-layered finite element models with FLEXAS™
• Intervention planning and construction management
• Life of field riser analysis and model updates

Safe operation of pipelines carrying corrosive products or in a corrosive environment requires (i) an understanding of the corrosion threats, (ii) the ability to estimate corrosion growth rates (CGR) of features; and (iii) the ability to apply these rates to plan future inspections, repairs and replacements. Reducing uncertainties in corrosion behaviour will therefore result in safer, more cost efficient operation.

This paper provides:

• An overview of methods used in the industry for estimating CGRs (e.g. coupons, corrosion modelling, box matching and signal matching).
• A discussion of the challenges involved with Magnetic Flux Leakage (MFL) signal matching; and how advances in pattern recognition and data pre-processing, now allow full automated matching of signal data from repeat inspections.
• A comparison of different ways of using CGRs (e.g. feature specific rates, maxima, upper bounds, segmented rates) and a methodology for selecting the best method, to ensure safety while minimising repair and re-inspection requirements.
• Case studies demonstrating the efficacy of using signal matching and a tailored CGR application method.

It is now widely acknowledged within the oil and gas industry that operational (production) pigging is a key frontline O&M activity for controlling internal corrosion in upstream production pipelines. Within MACAW we are at the forefront of this battle, helping operators with the development of corrosion management strategies and in the implementation of effective corrosion control schemes.

In this technical paper we provide a Corrosion Engineer’s perspective on developing corrosion management systems for oil and gas pipeline assets, highlighting organisational and technical challenges and the importance of operational pigging (i.e. utilisation of production pigs and ILI tools) and how this fits within an overall corrosion management strategy. More specifically, for the most common internal corrosion threats, we discuss possible mitigation strategies and their implementation (e.g. the identification of correct pigging tools and treatment frequencies for the application of biocides to control microbiologically influenced corrosion).

Based on actual results obtained through assessments and investigations conducted on a wide range of pipelines, the impact and effectiveness of typical current operating practices are critically reviewed. Suggestions and recommendations are then put forward for discussion with regard to improvements and/or alternative pigging strategies which may be beneficial in combating a range of different internal pipeline corrosion threats.

Intelligent inline inspections (ILI) are widely used to guarantee a safe operation of pipelines. The inline inspection provides reliable data in an economic way. Ultrasonic (UT) is currently the most accurate and reliable In-Line Inspection technology available in the market. These UT ILI Tools record data while travelling through the entire pipeline from Launcher to Receiver. In most cases, the Pipeline Operator does not need to make major adjustments to their pipeline. Nevertheless, pipeline operators may have to adjust medium flow rates to accommodate optimum inline inspection conditions, e.g. down to 1m/s.

NDT Global recently introduced the latest generation of UT tools - EVO SERIES 1.0. This generation offers highest inspection velocities of up to 4m/s. This high speed tools overcome reduction of flow rates for intelligent inspection runs. In addition, highest axial resolution available at the market (0.75mm) and circumferential resolution of 4mm provide excellent input for accurate pressure calculations, e.g. based on Riverbottom and crack depth profiles or even 3D Finite element modeling.

The authors will present basic background information about ultrasound inspection technologies. Theoretical aspects of EVO Series 1.0 tools are discussed for crack and wall thickness inspections followed by a case study performed in a real pipeline. Furthermore, EVO generation offers capabilities of combining different technologies in one tool. One single inspection tool with corrosion and crack transducers enables pipeline operators to operate their system safe with a minimized impact while inspection.

Nearly half of the world`s oil or gas pipelines have until recently been considered “un-piggable”.

This term is used when a pipeline cannot be inspected with a free-swimming in-line inspection tool without a need to modify the tool or the line to be inspected. Typical examples are for instance missing launching and receiving facilities, diameter variations, tight bends, low pressure and flow conditions or high pressure and high temperature environments, onshore or offshore.

In this paper the typical issues regarding the inspection of challenging pipelines will be discussed. A new concept will be introduced, the so-called “toolbox approach”. The driving idea behind the concept is based on having a large variety of services with all the required technologies, including magnetic flux leakage (MFL), eddy current or ultrasound, enabling tailor made solutions to be packaged utilizing exactly the right technical resources for a specific inspection and integrity challenge.

But it is not limited to a technology perspective. It also uses market information to identify mid- and long term market needs as well as special operational procedures.

In addition it must be stated that this type of work relies heavily on the expertise and experience of the crew involved, because of the often extremely complex boundary conditions and operational parameters encountered during the job performance.

Several case studies will be presented to illustrate this approach and address the major issues of successfully inspecting pipelines previously considered “unpiggable”, with a special focus on accessibility, negotiability and propulsion.

To effectively and regularly pig pipelines, a versatile technology is required that could be seamlessly implemented with the ability to navigate variable geometry all whilst being both operationally and cost effective.

Pipelines are the carriers of high value materials, critical to the success of the operation. Pipelines and pipe networks new and old, multi-bore and straight require care and maintenance to ensure that they are kept in good condition for fulfilling the aforementioned purposes. Collections of unwelcome bodies and /or restrictions to flow can prove to be very dangerous to the surrounding environment.

Aubin has developed EVO-Pig which alongside Pipeline Gels help remove unwanted bodies and debris from pipelines, ensuring flow conditions are optimised, maintaining production and pipeline integrity. EVO-Pig is a low cost option when compared to traditional mechanical pigging operations. Combined with the simplicity of the design premise and ease of operation, the technology offers a low risk option to pipeline pigging. Shape memory technology, enables the hydraulically or pneumatically driven flexible pig to easily move through changes in pipeline diameter and bends in the pipeline with the added benefit of not needing to be received.

After many years in development, Discovery™ subsea pipeline CT (computed tomography) technology is now fully operational and field proven, having successfully completed hundreds of subsea pipeline inspection scans.

Discovery™ is externally deployed and can scan through any type of pipeline, including flexibles and pipe-in-pipe systems, and through any type of coating. The scan results provide high resolution tomographic images of the pipeline walls to 1mm resolution, as well as characterizing pipeline contents to determine the amount and type of deposits present.

The inspection is carried out online with no disruption to normal pipeline operations.

This paper will describe how Discovery™ is used to help in mapping a pipelines contents to assist with operational pigging, and also how it is used to verify and accurately size defects picked up during ILI campaigns.

Pigging tools for pipelines are typically dominated by cleaning pigs at one end of the spectrum and intelligent pigs at the other. The cleaning pigs are simple, low cost tools that are deployed by onsite technicians and pose little operational risk to the pipeline Operator. Their simple design and construction, especially with foam pigs, mean there is little risk of them getting stuck in the line, mobilisation costs are low and they can be deployment & retrieved with standard facilities. Intelligent pigs on the other hand are complex tools that need to carry the NDT sensors and electronics / power modules in a configuration that allows for optimum inspection capability while maintaining good Piggability. The use of Intelligent pigs require significantly more planning in terms of logistics and operations, the use of specialist personnel for deployment and the processing of data.

The impact to production and the cost of inline inspection is significant and subsequently ILI tools are only deployed in a pipeline ever few years so data can be infrequent.

I2i Pipelines have pioneered the development and integration of advanced electromagnetic inspection sensors onto conventional cleaning tools for the regular inspection of pipelines. The innovative pigs bring together the best capabilities of both types of tools, the ease of use, the low risk and the low cost of a cleaning tool design coupled with the advanced NDT sensors normally associated with more expensive ILI tools. The result is a fully capable range of inspection tool that can be deployed regularly by onsite engineers to inspect pipelines for corrosion and cracking, trend inspection data and capture any changing conditions within the pipeline.

This paper will look into the technical challenges, applications and operational advantages of deploying inspection technology with routine cleaning operations.

As older fields become uneconomic, technology improves, business models change, and offshore assets, such as platforms, cease to be productive and are decommissioned.

In many cases, the existing pipeline network around these platforms is repurposed or reconfigured to suit current needs. Productive wells can be tied in to the existing network, and unproductive assets can be bypassed. Although the platforms are most often specific in purpose, the pipelines are generalists by nature. And prolonging the life of this type of asset is almost always profitable.

This paper explores the consequences of decommissioning – as part of pipeline repurposing – through a series of North Sea projects involving pipeline isolation conducted over the last seven years.

The ILI industry still lacks a suitable inspection technology for CRA-lined pipelines, i.e. pipes with a mechanically bonded inner pipe of a corrosion resistant alloy inside of a ferritic steel pipe carrying the hoop stress. Neither the existing UT technology is able to inspect through the interface of a CRA and a ferritic steel component, nor is the current MFL technology able to sufficiently magnetise the ferritic steel pipe in order to inspect this type of pipe.

The current contribution investigates the possibility of Magnetic Eddy Current (MEC) to carry out such an inspection. A prototype internal inspection tool has been devised. Several types of sample defects have been produced into the ferritic steel carrier pipe as well as into the CRA-inner pipe. The defect types anticipate the integrity issues that an internal inspection tool would need to address. Several pull tests under controlled speeds have been carried out. The results are presented. Influences of tool speed, magnetisation level and eddy current parameter are investigated. Special attention is drawn to the distinction of different defect types.

The MEC technology was found to be a suitable inspection technique for CRA-lines pipes. This is achieved through several adaptations for this particular task. The particular challenges for the internal inspection of CRA-lines pipes are underlined. The technology may also fill other existing inspection gaps, like the inspection of heavy walled small diameter gas pipelines.

The use of high-bypass de-sanding pigs, either in isolation or in conjunction with traditional brush pigs, has been proven as an effective new method for mobilising and removing both waxy and particulate debris.

This case study will discuss the execution and findings of an operational cleaning campaign targeted at the removal of both waxy and particulate debris from an ultra-deepwater oil production pipeline in West Africa. The campaign utilised traditional brush pigs as well as high-bypass de-sanding pigs to remove debris for the purpose of reducing the risk of under-deposit corrosion.

The focus of the paper will be on the high-bypass de-sanding pig; its design, function and operation, and how it complemented the capabilities of more traditional brush tools.

The paper will describe the cleaning requirements and the tool types engineered for the operation, including the difficulties of design for the pipeline geometry and operating conditions.

The global market conditions influence the extraction of resources onshore as well as offshore, whereby particularly offshore exploration pipelines need to cope with high temperatures and pressures as well as products containing corrosive elements. This leads to potentially higher corrosion rates in a high temperature environment. Pipelines made of ferritic steels are susceptible to corrosion attack, especially if specific types of medium are transported in the line or the pipe is situated in a critical environment.

The industry is addressing this issue through various means, also including the development of new materials and pipe types. More and more corrosion resistant materials like stainless steel are used, e.g. duplex steels or different types of corrosion resistant alloy (CRA) pipes. Over the past 30 years thousands of kilometers of CRA pipelines are laid and there is still a growing demand.

However, in the carbon steel but also in the CRA layer different types of defects and/or features can appear, whereby the ILI technologies so far focus on carbon steel pipes.

This paper will give an overview of state-of-the-art ILI technologies to inspect mechanically and metallurgically bonded CRA pipes. The challenges for inspection of the carbon steel and the CRA layer, for different ILI technologies will be presented.

Verification of inspection results is a challenge to the industry. This is notable in situations of offshore pipelines which are a challenge to access and repair. It is essential that operators have accurate and reliable information on their pipeline condition to enable informed decisions with regards to maintaining and ensuring the ongoing integrity of their assets.

The case study presented in this paper is based on data collected on the condition of a large diameter crude oil pipeline which has undergone several in-line inspections, corrosion investigations and integrity assessments.

In order to verify the results of these in-line inspections and subsequent assessments, automated ultrasonic infield inspection results were utilised. A combined technology review and assessment was then completed to determine the accuracy of the measured metal loss features and corrosion rates identified by in-line inspection surveys.

This paper aims to highlight the results of this investigation and the subsequent benefits of utilising in-line inspection tools as part of an ongoing integrity management strategy.

There can be many flow assurance challenges that may result in reduced production through a production system such as paraffin wax, asphaltenes, salts & scales, sand, hydrates and corrosion products. The presence of deposits in a pipeline can lead to accelerated corrosion as well as restricting flow resulting in production rates that are less than the capacity of the system. In order to successfully inspect a pipeline using in-line inspection tools thorough cleaning of the line is required to avoid data loss during the inspection. In addition to the presence of deposits causing issues while the system is in production the presence of deposits can be problematic during decommissioning.

The first step in any cleaning operation is to gain an understanding where the deposits / restrictions are located in the pipeline along with the chemistry of the deposit. Once the amount and location of deposits are known a custom cleaning program can be developed to clean the pipeline.

The oil and gas industry worldwide is reliant on the long term reliability of pipelines, predominantly rigid pipelines as the safest and most efficient means for the transportation of hydrocarbons.

Pipeline operators need peace of mind that should a pipeline fail their processes and contingency plans are fully qualified and ready to respond to an emergency scenario.

There are two distinct damage scenarios that need to be considered, the first is operational damage caused by corrosion or erosion. This damage tends to occur slowly over a long timescale so regular inspection of the pipeline can monitor the condition and ensure planned maintenance is carried out.

The second damage scenario is through external impact, caused by an anchor drag, dropped object or landslide. With this scenario there will be no warning and the damage could breach the pipeline, introducing an unpiggable bore restriction at minimum or stopping pipeline flow completely.

This presentation will discuss recent advancements in isolation technology which have been developed to enable the installation of safety critical double block and bleed isolations when an unpiggable midline defect exists.

Significant savings can be achieved by having the required equipment ready for deployment in the event of a pipeline failure. The primary objective of an Emergency Pipeline Repair System is to facilitate a rapid and safe repair ensuring pipeline production can be resumed as soon as possible, minimising environmental and commercial impact.

The presentation will include a case study featuring STATS supply of emergency response isolation plugs from 32" to 38" developed for Qatargas. These fully engineered isolation systems were designed and manufactured to meet the clients specification and are now maintained in a state of readiness close to the operator’s asset, to ensure rapid response to an emergency repair.

Internal long axial corrosion is the most common corrosion type in offshore crude oil and water injection pipelines. It has frequently a complex shape that ranges from a smooth uniform wall thickness reduction to a rugged surface with varying depths.

Long axial corrosion anomalies can be reliably detected and sized by means of ultrasonic in-line inspection (UT ILI). The rough surface of the corrosion can lead to outliers in the gathered ILI data. Accordingly, an elaborated filtering and re-processing of the inspection data is crucial for a consistent data assessment.

The inspection report usually provides maximum anomaly dimensions (total length, peak depth, etc.) and does not sufficiently describe the complex shape of corrosion anomalies. Therefore, methods based on corrosion depth profile (river-bottom profile, RBP) have to be applied for pressure capacity assessment. In addition, corrosion growth rates are ideally obtained by comparing RBPs of consecutive inspections.

This paper outlines the main results of a recent joint industry project that provides guidance to the assessment of long axial corrosion based on UT ILI results. It involves the determination of RBPs, the calculation of the safe operating pressure, the determination of corrosion growth rates and the extrapolation of the future pressure capacity. Compared to other assessment methods which are also based on RBP, the presented assessment approach accounts for a higher probability of failure associated with a higher number of corroded sections in a pipeline.

Chevron North Sea Limited (CNSL) operates more than 25 pipelines across three operated assets in the UK North Sea – Alba, Captain and Erskine.

Processes adopted by CNSL for effective management of pipeline integrity and reliability include a combination of online data collection, fluids sampling, corrosion risk assessment, remnant life modelling, and physical inspection techniques for the measurement of pipeline condition.

This paper discusses the input that in-line inspection (ILI) can have into an overall pipeline integrity management strategy. The following key points will be discussed: The importance of combining knowledge relating to active corrosion mechanisms together with an understanding of the capabilities and limitations of available in-line inspection technology. How ILI results can be used to review the effectiveness of corrosion management strategies and support remaining life assessment. How to select an appropriate re-inspection interval.

Case studies will be used to provide a practical insight into how this is achieved within CNSL.

Pigging operations often present monitoring challenges that are difficult to predict prior to launch. These include confirming launch, monitoring pig progress at strategic locations and confirmation of the pig’s arrival, often under adverse conditions. Accurately locating a stuck pig as well as quantifying the associated debris transported into the receiver can also be problematic.

Using a combination of different non-intrusive pig monitoring, signalling and data communications equipment, an operator can mitigate against these risks for even the most difficult or lengthy pigging operations.

Drawing on experiences gained throughout a diverse project history, this paper provides insights into reliable and novel monitoring methods available to an operator engaged in pigging operations. Descriptions of real life projects utilising using a variety of non-intrusive technologies will be discussed.

This paper focuses on the technology and logistical challenges for a long-distance, deepwater pipeline precommissioning and inspection project.

Weatherford Pipeline and Specialty Services (P&SS) performed this work on behalf of Noble Energy Inc., a major oil and gas exploration and production company. Its subsidiary, Noble Energy Mediterranean Ltd., contracted directly with Weatherford P&SS as part of their development of a subsea gas production and transportation system connecting the deepwater Tamar Gas Field to an offshore receiving and processing platform linked to the existing Mari-B Platform in the Mediterranean sea.

Gas production from the Tamar Reservoir is designed to occur through five high flow rate subsea wells into the subsea gathering system, which consists of an infield flowline from each well to a subsea manifold. From the subsea manifold, dual subsea pipelines will transport Tamar production approximately 149km to the Tamar Offshore Receiving and Processing Platform where the gas will be processed. The processed gas will then be delivered to the existing Ashdod Onshore Terminal (AOT) for gas sales into the Israel Natural Gas Line (INGL) system.

The inspection of pipelines through high levels of coating remains a challenging task. In particular offshore pipelines often require a thick coating for various purposes. Usually it is a combination of mechanical impact and corrosion protection. Hence the configurations can be quite different. The external inspection of subsea pipelines and risers often complement or substitute an internal inspection by pigging.

An overview of available technologies is presented. The limitation of the technologies and their physical origins are discussed. A systematic investigation in improving the capabilities was done. Most of the principles are based on some kind of eddy current technique. Several case studies of inspection through a thick coating are presented. In one case risers had to be inspected through as much as 12mm of coating and with a wall thickness of 25mm. The high stand-off measurement usually conflicts with a high resolution of the scanned surface. Metal loss defects as small as 10 mm and as shallow as 10% have been found. In a different project a wire disorganisation of a flexible pipe had to be detected through a coating of 9 mm. In this case it was possible to show, how a regular signal pattern and its distortion by defects can lead to a sensitive detection of defects through a coating.

In the last 4 years more than 800 inspections have been completed on & off-shore with the latest generation MFL ILI technology, capturing information on tens of thousands of kilometres of pipe, and generating a significant volume of dig verification data.

In collaboration with Oil & Gas pipeline operators around the world this growing dig verification database has been utilized to improve software models, algorithms, & analysis processes to validate and further enhance system detection, sizing, & reporting capabilities.

This paper focuses on the recent collaboration between ExxonMobil and PII, to investigate system capabilities with respect to “Pinholes”, to address a known threat to a specific pipeline in the United Kingdom.

This paper will describe the:

• Evolution of the "Pinhole" specification that captured the interest of ExxonMobil.
• Use of Finite Element models to predict entitlement for characterization of "Pinhole" type defects
• Detail of and results from the ExxonMobil sponsored test program that was conducted in early 2013
• The in-line inspection, analysis report, and dig verification that followed for the pipeline in question.

Internal corrosion can lead to production reduction as corrosion by-products accumulate in the pipeline and, in the event of a through-wall failure, can cause extensive hazard to people and damage to asset and the environment.

Corrosion inhibitors have proven to be very effective at reducing the overall corrosion rate when added to the pipeline product in small amounts. The inhibitors are generally introduced into the pipeline by injection, either as slug treatment or continuous injection, or most commonly as batch treatment employing a chemical column between two pigs.

Operators are looking for alternative treatment options. This may include the application of corrosion inhibitors by an innovative “spray pig” technology.

Mechanical interlocking products guarantee strict adherence to procedure and thus avoid human error. They are particularly useful for operations that are generally recognized as highly dangerous, such as pigging. Interlocks are a cost-effective measure that results in extremely high safety levels.

Traditionally however, interlocks function as independent and stand-alone safety systems. But as advanced digital technology now enables us to combine process control and safety instrumented functions within a common automation infrastructure, wouldn’t it be better to integrate operator procedures, such as those safeguarded by mechanical interlocks, with the Distributed Control System (DCS) and Safety Instrumented System (SIS) as well?

As the overall infrastructure in the oil and gas industry is aging there is an increasing demand to assess the integrity of all existing assets. As a result pipeline inspection using In-Line Inspection (ILI) tools has become the standard for pipelines that can be considered piggable. Many of the world's pipelines were however never designed to be pigged, the so-called unpiggable pipelines.

To operators these unpiggable pipelines are equally important to the overall integrity of the pipeline system and suitable inspection solutions are therefore required. Although alternatives like direct assessment and spot checks using in-field, non-destructive testing exist, the most valuable information can only be obtained from the inside of the pipeline using in-line inspection devices.

Typical challenges involve access (no pig traps installed), operating conditions as well as the pipeline geometry. Due to the individual challenges arising from pipelines deemed to be unpiggable a wide variety of tailored solutions has been developed in recent years.

One of ROSEN's recent developments is the extremely short Bi-Di Inline-Inspection tools. Their bi-directional design, passage capabilities and wide range of operating conditions provide great flexibility to operators, thus minimizing the operational impact and required pipeline modifications. Applications include ILI of tanker loading/unloading pipelines, gathering pipelines, branch connections, risers and flare lines.

This paper will discuss the continued development of ILI solutions specifically designed to close the gap between piggable and unpiggable pipelines by discussing their challenges, practical application, case studies, and the future of additional research and development.

In 2005, Total were planning to carry out an inspection of two 32” gas and condensate pipelines running 92 km from the South Pars field in the Persian Gulf to the shore terminal at Assaluyeh in Iran. The pipelines were overdue for inspection but it was known that hard scale deposits were present in the line which would present significant difficulties to the passage of either MFL or Ultrasonic tools. Total were therefore planning to carry out an acid clean of Sea Line 1 to remove the scale prior to the use of the inspection pigs. Our company was asked if we could run a multi-channel caliper tool through the line to measure the thickness and the distribution of deposits and to provide the information to the pipeline engineers to allow them to optimise the acid clean. In due course we successfully carried out the caliper run and from the data, we were able to map of the distribution of the scale and an estimate of the total volume of the deposits. From this information, Total were able to determine the quantity of acid required and optimise the soak time to ensure all of the scale was removed. Following the acid clean, we were asked to return and run the caliper to confirm that all of the deposits had been removed. In fact when we did the run we found that some of the thickest deposits had not been removed so a mechanical cleaning pig was used to remove the remaining deposits allowing the MFL inspection to be carried out.

In 2006 we were invited back to carry out the pre-cleaning caliper survey of the second pipeline – Sea Line 2. Foam pigs had been run through this pipeline but no hard bodied pigs. We therefore offered a smart gauging pig to run in the line first to get an idea of the size and location of the major restrictions before running our caliper tool.

However, when the gauging pig was run, it was severely damaged and the rear disc stack was completely stripped off the pig and left in the line (Figure 1). Clearly the restriction in this line was much more severe than in Sea Line 1. Fortunately the pig had not been completely stuck in the line and by measuring the damage we were able to figure out the key design parameters of a caliper pig which should be able to get through the restriction in the bend at the bottom of the riser.

With help from the engineers at Propipe, a caliper pig was produced and much to our relief, it passed through the line without a hitch. Once again, data from the caliper run was used to produce a mapping of the scale deposits and this time the post cleaning caliper run showed that the deposits had been successfully removed.

Several of the world’s oil and gas facilities are experiencing aging production infrastructure. Operators are now applying greater focus to integrity management and more frequent inspections. Internal visual inspection is one method for the inspection of pipeline systems. Challenges exist with this method related to camera tools and receiving a clear image as well as performing swift inspections to keep disruption of production to a minimum.

When a major operator on the Norwegian continental shelf required effective inspection of several flexible production risers, it became apparent that the existing technology did not provide the required image quality and operational effectiveness. This lead to the development of an inspection camera tool that combines existing technology used for inspection of drilling risers and blowout preventers (BOPs) with a commonly used deployment vehicle (pig) design.

The tool enables single inspection runs to acquire digital images in a high-pressure environment. It incorporates high resolution, wide-angle 185/360° images, powerful lighting, and customized software with digital unwrapping and advanced digital filtering.

The tool body has a bidirectional pig design and is launched and controlled using a high-tensile-strength control cable. An effective stripper unit mounted on a regular pig launcher helps ensure a safe launch and control of the tool. The visual inspection tool is normally launched in clear fluid, but other driving media can also be used.

Within pipeline systems, this camera tool enables inspection for abnormalities, corrosion, coating, functions, and other features. Operators can use this technology to improve and expedite the decision-making process, leading to time savings, reduced costs, and increased offshore safety.

When it comes to a fast, non-intrusive, complete and meaningful inspection of an offshore pipeline in-line inspection (ILI) has been the method of choice for several decades now. However, not all pipelines, piping or other tubular structures can be inspected with in-line inspection tools (pigs). The method is usually limited to looping flow lines or export pipelines, specifically designed for ILI operation. The remaining structures are often summarized under the buzzword “non-piggable”.

The typical ILI viewpoint is to consider the piggability under either the aspect of pipeline design or pipeline operation. Typical piggability issues in pipelines under pipeline design aspects are launching/receiving facilities, bends, and internal obstructions. The other aspects are operations-related. ILI may be impossible due to too high/low flow, too high temperature and other. In both cases ILI solutions can still be conceived and realised by either changing the pipeline or by adapting the pig. The latter is the technically more interesting solution for service providing companies. ILI providers are busy in designing and already offer tools for multiple diameters, for bi-directional operation and tools with special insertion techniques. Also there are many solutions available that use a cable operated tool and/or a crawler type tool. Discussions on solutions for unpiggable pipelines usually focus on these types of solutions.

There still remains an area of inspection tasks that can be summarized under “Not at all piggable”. For either technical or financial reasons, a pig-like solution may still remain unfeasible. In some cases the involved technical risk may also convince the involved parties to refrain from any ILI adaptation. In these cases either key-hole solutions or external inspection may remain the only option. The distinction between a key-hole solution and a pig-based inspection can be made by the aim to reach a 100% coverage in the latter case. For other inspection types a lower inspection coverage is usually accepted.

Acoustic pipeline pig tracking, simply put, is the attachment of a battery powered acoustic pinger to a pipeline pig; the acoustic signal generated by the pinger travels through the pipeline and into the surrounding water and is subsequently tracked with a suitable receiver system.

Receivers consist of a hydrophone, essentially an aquatic microphone tuned to the frequencies of interest, and some sort of user interface which displays, or more often plays back downshifted audio of the ping.

The hydrophones attached to receivers can be either omni-directional or directional depending on the task at hand. For tracking from a surface vessel, omni-directional is often the obvious choice. However, when precise locating of the pinger is required, a directional hydrophone can be used.

The energy emitted by the acoustic pinger are acoustic tones, often only a few milliseconds long and outside the range of human hearing, typically between 10kHz and 40kHz.

Acoustic pig tracking itself is not a new field. For decades pinger suppliers have supplied pinger equipment to offshore pipeline construction companies and pipeline operators alike. These pingers, when properly mounted on pipeline pigs, have provided these basic offshore pig tracking functions.

Despite this list of strong positive features, acoustic pig tracking has a somewhat spotty record of reliability in the field. Over the years CDI has had the opportunity to speak with many of the end-users of acoustic equipment. Anecdotal end user experiences have varied widely, with some firms having good experiences and others having complete failures.

Some of the failures of the systems are no doubt due to a lack of understanding and training of the operator; user error. This is not uncommon when infrequently used systems are put into the hands of end users. However, user error cannot account for all of the failures experienced by otherwise competent operators. There are some subtle underlying technical problems with existing acoustic pig tracking systems.

Perhaps greatest among these is multipathing.