bluuebunny/crossref_metadata_2025_split huggingface dataset:
GluBi® Pipe - A New Development of A Reelable Lined Pipe
Authors: Schueller Thomas , Hoffmann Reinhold , Banse Joachim , Lahmann Volker 
Published: April 2017

Abstract
For two decades the mechanically lined pipe has been applied as onshore and offshore pipeline in the oil and gas transportation. Up to now more than 1,000 kilometres of this kind of linepipes have been installed. In the past the main offshore installation methods for mechanically lined pipes were S-lay, J-lay or Bundle. The objective was to produce a reelable mechanically lined pipe with dimensions of 6 up to 18" without any further procedures such as application of internal pressure or reinforcements of the liner material. Over the last years, various approaches were investigated to prepare the mechanically lined pipe for the reeling technique which is much more efficient and economic than the above mentioned installation methods.
The manufacturing process of the new product is based on the process of the mechanically lined pipe called BuBi®. A CRA pipe is expanded inside a carbon steel pipe, using a hydroforming process. Between the two pipes a glue is coated to produce adhesion. The pipe ends are welded using a weld overlay method. The main development work was finding a solution of the welding at a glued pipe end. This was successfully done.
The result is a glued linepipe called GluBi® having the same weldability and processability properties as the well-known mechanically lined pipes and it is reelable without the risk of wrinkling. Furthermore the strength and corrosions resisting properties as well meet the requirements of the onshore and offshore oil and gas transportation. Currently the new product development is going through the DNV qualification DNV-RP-A203. The market launch is planned for 2017.
The main benefit of the new product, the glued mechanically lined pipe, is the cost saving factor. The reeling process can be faster because the pipe section does not have to be filled and pressurized with water. Another advantage is the lighter weight. The vessel is able to load more pipes. The glued mechanically lined pipe is a reasonable completion of the metallurgically clad pipe and the conventional mechanically lined pipe. It will find its place in the future of the oil and gas business.
Establishment of a Quantitative Risk-Based Approach for Evaluation of Containment Performance in the Context of Permanently Plugged and Abandoned Petroleum Wells
Authors: Arild Øystein , Lohne Hans Petter , Majoumerd Mohammad Mansouri , Ford Eric P. , Moeinikia Fatemeh 
Published: April 2017

Abstract
A large number of offshore oil and gas wells need to be plugged and abandoned on the Norwegian Continental Shelf in the coming decades, implying significant costs to the industry. To develop a methodology for evaluation of the quality of the barrier system of permanently plugged and abandoned wells from a risk perspective, the research project "Leakage risk assessment for plugged and abandoned oil and gas wells" has been initiated. The chosen quality measure to quantify containment risk in this context is the "leakage risk" expressed in terms of probability of barrier failure and potential future leakage rates.
Reviewed papers consist of fragmented contributions to a complete framework for leakage risk assessment of plugged and abandoned wells. However, they do not provide a complete risk assessment framework with a corresponding detailed analysis. Without such a framework, regulations will be limited to prescriptive approaches.
As an alternative to the currently prescriptive approach to plug and abandonment operation, this article presents how a risk-based approach can be used in practice by incorporating assessments of probability of leakage and the consequence (leakage rate), as well as uncertainty quantification. A comprehensive methodology and workflow, encompassing required steps for risk-based evaluation of containment performance, is established and presented in the paper. It is shown that this approach can provide a quality measure for a given plug and abandonment design and subsurface conditions.
Managing Missteps: Complications with Marine Magnetometer Surveys and Data Interpretation
Authors: Haddock Daniel A. 
Published: April 2017

Abstract
The objective of this paper is to outline the advantages of using a gradiometer over a marine magnetometer for surveying the seafloor. Marine surveys conducted with a gradiometer will minimize external interference in the field allowing the interpreter to provide quick results with confidence.
Many survey companies operating in the oil and gas industry rely heavily on a single magnetometer, which if not utilized properly can create multiple problems for archaeologists. Magnetic data with outside interference, bottom strikes, or collected during geomagnetic storms will creates data artifacts that look like real magnetic anomalies. Several shallow water surveys from 2015 are provided as examples of poorly collected data, which show how the data can inhibit an archaeologists' recommendations to operators. Operators that are required to use marine magnetometers will see the value in using gradiometers over single marine magnetometer, especially in surveys that may potentially identify shipwrecks or in areas with the potential for unexploded ordinance (UXO).
Poorly collected magnetometer data can increase interpretation costs and may require the area to be resurveyed there by delaying future projects. The adoption of the gradiometer over the magnetometer is recommended across the board for all operators. With the broad adoption of the gradiometer, archaeologists can provide better recommendations for future exploration and development to the oil and gas industry, which can prevent damage to cultural material, subsea structures, UXO and allow for a better collaboration with BOEM and BSEE.
Even though gradiometers have been in use for marine surveys for over 60 years (Wow, Cooper 1989), they are rarely used for marine surveys, especially in the well developed areas. This paper will show the results of poorly collected magnetometer data to demonstrate the need to adopt the gradiometer as the standard for marine magnetic surveys.
A Submarine Full of Mercury
Authors: Sparrevik P. M. , Eek E. , Klinkvort R. T. , Eiksund G. R. 
Published: April 2017

Abstract
This paper describes the geotechnical conditions and preparations for remediation work performed so far by the Norwegian Coastal Administration in order to protect the marine environment from the toxic legacy of U-864, a German submarine sunk by the British navy outside the west coast of Norway near the end of the Second World War. As the sloping seabed at the location of the wreck is unstable, the first step was to install a large counter fill to prevent sliding of the contaminated sediments.
NorMoor JIP, Structural Reliability Analysis for Mooring Lines in Ultimate and Accidental Limit State
Authors: Hørte Torfinn , Okkenhaug Siril , Paulshus Øivind 
Published: April 2017

DNV GL is currently running a Joint Industry Project, "NorMoor JIP," with participants from oil companies, engineering companies, rig-owners, manufacturers and marine authorities. Our motivation for initiating a study on mooring line reliability started out with questions raised with regards to the applicability of the mooring standards. All the global standards (API, ISO, DNV, others) are mostly based on work from late 1990s, when frequency domain analysis was prevalent while time domain analysis is often applied today. The reliability level implied by these regulations is not known, and we also see that the mooring standards are interpreted and applied differently.
The objective of the NorMoor JIP has therefore been to provide a more consistent analysis methodology, and calibrated safety factors for time domain in line with this methodology. This is achieved through reliability-based calibration for a range of different units, mooring systems, water depths and geographical locations. Thus, the NorMoor JIP is intended for global application, and the aim is to get the results implemented into global standards like ISO.
Structural reliability analysis has been applied to calculate the probability of mooring line failure for intact mooring systems (ULS) and damaged mooring systems where one line is removed (ALS). The reliability analysis is based on a detailed probabilistic model of the metocean environment, state-of-the-art response analyses and strength data from break load tests. The probability of failure is calculated as a function of the magnitude of the safety factor. It is shown that present regulations result in a significant scatter in reliability level between the cases. An alternative design format with 2 partial safety factors may potentially reduce the scatter. Differences in results for hurricane conditions in the Gulf of Mexico and storm conditions on the Norwegian Continental Shelf are obtained, indicating the need for a different design philosophy for the two locations.
The present work provides a unique and comprehensive set of results, where advanced reliability methods are used in combination with detailed response calculations in the time domain. The results provide a basis for calibration of mooring design for ULS and ALS and subsequently for regulators to update their rules. Calibration of safety factors and selection of target reliability level are presented in a companion paper at OTC 2017.
Towards a Global Public-Private Protection Model
Authors: Faulk Kimberly L , Fucik Ken , Varmer Ole , Wachsmann Shelley 
Published: April 2017

The offshore energy extraction industry, both renewables and oil and gas, continues to push into frontier areas where little to no protection exists for underwater cultural heritage (UCH) sites. Despite relatively rigorous regulatory requirements in the United States and the North Sea, other areas around the world have minimal to no cultural heritage regulatory frameworks to manage discovered archaeological sites.
Operators with experience in more mature fields often assume any archaeological discoveries will result either in additional regulatory pressure by the national or domestic government, or that the sites will be protected as a matter of course. Unfortunately, a patchwork of cultural heritage laws that imperfectly interface with offshore energy regulations can all too often result in no protection for these sites, meaning the sites are protected only by the silence that surrounds their discovery.
A new model, under development by partners from the energy industry and external cultural heritage experts, suggests a solution: a standalone database of discovered antiquity sites from energy extraction projects that would be voluntarily shared both with industry partners and government regulators. Operators would be able to access the database to help guide field decisions, and regulators would be able to use the information in their efforts to prevent looting and unauthorized salvage by third party salvage firms. The concept, while simplistic, requires industry and governmental consultation and cooperation.
This paper provides an overview of the solution, and calls for assistance from stakeholders to help solve a 21st century archaeological and industry problem - protecting the sites that lie deep beneath the surface, and that have survived for thousands of years - while allowing responsible energy development to continue.
Subsea Smart Crossing: An Innovative Solution to Simplify Field Architecture and Enable Cost Effective Installations of Subsea Pipelines for Long-Tie Backs, Scarp and Canyon Crossings, and Ultra-Deepwater Applications
Authors: Kalia Akshay , Pinho Adriano , Skowronek Tyler , O'Neill Eoghan , Mebarkia Sid , Critsinelis Antonio 
Published: April 2017

Abstract
Subsea pipelines play a significant role in E&P systems and are often called the lifelines of offshore oil and gas fields. These pipeline systems now cover greater areas and therefore traverse greater distances, go to deeper regions, and use larger-diameter pipelines. These developments present several challenges, including:
■ geohazards due to scarp or canyon crossings ■ multidiameter requirements ■ reduced-diameter risers to interface with large bore pipelines ■ ultra-deepwaters where top tensions become installation limitations ■ piggability of varying pipeline diameters, branching, and materials
Most current approaches for these new frontiers rely on stretching the current design and installation practices that involve pushing materials and equipment to their limits, which increases risks and leads to very expensive solutions (high capex and high opex) for developing, installing, maintaining, and operating subsea pipeline systems.
A subsea pipeline smart crossing system was developed to be a cost-effective solution that enables interconnectivity of different types and sizes of pipes to address the previously mentioned challenges and simplify subsea field architecture.
This paper presents the challenges and constraints for two different field architectures, outlines the subsea pipeline smart crossing solution, and presents its associated technical and commercial benefits that allow operators to optimize their spend on development, installation, and operation of subsea pipeline systems.
Profit Increase With New Subsea Boosting Products
Authors: Hofstad Åge , Nilsen Hans Christian 
Published: April 2017

The oil and gas industry is continuously developing new technologies in answer to increasingly challenging demands. In the current market situation, where the oil price is dramatically reduced, these demands are strongly driven by finding the most cost efficient field development solutions. These solutions often call for stretching the requirements on subsea technologies. One solution that has been applied for years, with good track record, is the use of subsea boosting. Pressure on more efficient subsea boosting solutions has led to a number of development initiatives in the industry.
Aker Solutions has, together with a few main oil companies, developed a new multiphase pump technology which is soon ready for the market. This will expand the operation envelope for subsea boosting and create better opportunities for more effective offshore field development. A parallel, and equally important, development activity has been the development of a new large duty, 6 MW, subsea motor.
This paper will focus on the new 6 MW multiphase pump and motor developed and tested by Aker Solutions and its JIP partners. The step-wise applied development program will be reported, describing the main activities in the qualification of the new technology. Newly obtained results from the pump and motor qualification programs will be presented. Finally, an example will be presented on how this new boosting machine can be utilized to generate increased economic value for a subsea project.
The new pump and motor opens up for improved field economics with a greater ability than ever before to maximize profit by increasing the oil recovery and reduce the total production time by, in some cases, several years. This has demonstrated to provide considerably improved net present value since the oil production peaks out years earlier.
Design Verification and Load Estimation of Subsea Wellhead in HPHT Applications
Authors: Chang Gwo-Ang , Liu Meng-Lung , Song Hao 
Published: April 2017

Abstract
Subsea equipment design verification and validation are to be performed by analysis and testing, respectively. Two of the most important aspects of this process for high-pressure, high-temperature (HPHT) applications are load estimation and fatigue assessment. This paper presents dynamic loading scenarios typically considered in the design of subsea wellhead in HPHT applications during service life as well as load estimation of these scenarios, particularly on riser loads. Fatigue damage to the subsea wellhead is also included to examine the significance and effect of the loads from each of the loading scenarios.
Dynamic loading scenarios in drilling and production phases are evaluated in the paper. In the drilling phase, typical loading scenarios for the riser in connected conditions with wellhead are evaluated. A typical drilling system, generic sea state scatter diagram, soil condition and operational profile are selected to estimate the dynamic loads for each of the scenarios. In the production phase, typical loading scenarios are also evaluated. A typical subsea production system with the same sea and soil condition as drilling but with different operational profile is selected to estimate the dynamic loads for each of these scenarios.
A typical wellhead system including wellhead housing, conductor, and casing system is selected for the riser load estimation and the wellhead fatigue assessment using fracture mechanics method is carried out in accordance with API 17TR8.
Dynamic loads estimated from the scenarios in drilling and production phases are compared at the top of the wellhead in terms of maximum load and load histogram. The significance and effect of these loading scenarios are also evaluated from the fatigue standpoint at select hotspots on the wellhead system. From the study, it is observed that loading from drilling and production phases are equally important and both should be considered to verify the subsea wellhead's structural capability.
In the paper, an analysis procedure to evaluate the riser load to the wellhead and fatigue assessment of the wellhead is proposed, which may be used for the design verification of subsea wellhead in HPHT applications.
A Comparative Study of Pressure Vessel Design Using Two Different Asme Methodologies
Authors: Faraut Germain , Randrianarivony Liva Christian 
Published: April 2017

Abstract
As offshore production moves to higher pressure reservoirs, water injection, gas lift and gas injection swivel designs need to follow the trend. To accommodate these higher pressures, an internal study was launched to reassess the capacity of a 12" toroidal swivel called VHP swivel. A first attempt in this requalification was performed using the ASME Div. 3 Part 5 "elastic stress analysis" method. Even though being widely used in the pressure vessel industry, the stress linearization method rapidly showed its limitations. Indeed, above 830 barg, the deformed swivel geometry was producing highly non-linear stress profiles which invalidated the method's results. On the other hand, the "elastic plastic stress analysis" method gave higher acceptance pressure levels but required advanced modeling skills. The use of sub-models, programed failure criterion verification tools, mesh refinement and converge criteria control were mandatory for complying with the code requirements. Numerical results confirmed that the VHP maximum operation pressure could be extended from 830 barg to 1020 barg, but also gave reliance in using this methodology as it properly predicted the swivel behavior. Indeed the FE predictions were confirmed by calibrating the numerical results against the actual swivel deformations through monitoring of the deformations during live testing. Finally, the completion of the VHP swivel test program, simulating 25 years of a recent offshore North Sea yaw cycle motions, confirmed the robustness of the overall design approach.
This paper presents the analysis performed as part of the requalification of the VHP swivel at a maximum operating pressure of 1020 barg.
Data Mining the Red Sea Atlantis II Deep
Authors: Brueckmann W. , Kraetschell A. , Augustin N. 
Published: April 2017

Abstract
The Red Sea is a textbook case of a modern-day oceanic rift basin forming as a result of continental break-up. A characteristic feature of this setting in the central and northern Red Sea are more than two dozens of isolated bathymetric depressions, "deeps", filled with brines derived from leaching of the early-breakup Miocene salt deposits that lie beneath the entire Red Sea. The Atlantis II Deep is the largest basin of this type in the axial rift zone of the Red Sea. A topographic depression enclosing a volume of an estimated 15 km3 at water depths from 1900 to 2200 m, the Atlantis II Deep contains layered fluids with temperatures of up to 66°C and salinities of up to 27%. Beneath the brines, up to 30 m of fine-grained metalliferous sediments have been accumulating for the past 23 000 years (Anschutz, 1995). Unlike those in modern hydrothermal systems at mid-ocean ridges, where most of the metals are expelled to the open ocean in buoyant hydrothermal plumes, metals in the Atlantis II Deep are trapped and precipitated beneath a 200-m-thick brine layer. These sediments show extremely high concentrations of zinc, copper, silver, and gold (90 Mt of dry salt-free sediment at Zn&gt;2%, Cu&gt;0.5%, Ag&gt;39 g/t., Au&gt;0.5 g/t.). While the mode of metal deposition found in the Atlantis II Deep is not known from anywhere else on the seafloor today, it has yet been widely suggested as an analog for many ancient sediment-hosted ore deposits (Laurila et al. 2015). From 1975 to 1981 the German company PREUSSAG was contracted by the Saudi-Sudanese Commission for the Exploitation of the Red Sea Resources to explore the Atlantis II Deep. The project was aimed at assessing the overall technical viability of recovering and processing metalliferous muds on board of a mining vessel. The program encompassed several sampling cruises, a pre-pilot mining test (PPMT), environmental surveys, a study of pre-mining environmental conditions, as well as an economical evaluation. However, despite a highly successful PPMT, economic interest in the project waned due to declining commodity prices in the early 1980s. A substantial data set was derived from this campaign, including several kilometers of well preserved sediment cores and &gt;20 000 pages of analog information. Utilizing this information, several GIS-based data mining efforts were carried out in recent years, driven by renewed interest in developing this unique resource. Our presentation will discuss results from these efforts and focus on the technical, economic and environmental boundary conditions of ocean mining of metalliferous sediments. Recently acquired geophysical data in the central Red Sea provide an unprecedented level of ground truth to historic data on Atlantis II.
Industry Applications for Additive Manufacturing
Authors: Imrie Andrew 
Published: April 2017

Abstract
Additive manufacturing (AM) is estimated to grow significantly in the next few years, the potential for AM is significant, however, AM is not the plug and play technology that it appears to be, AM works for specific applications, the first question that should always be asked is ‘does it make sense to make the product using AM compared to more traditional methods of manufacture’. The hype around AM has led many traditional manufacturers to assume that the manufacturing controls and material properties for a given material produced by AM processes are similar (if not the same) as those required and resultant from a conventional manufacturing process (such as a forging). There are many individual steps involved in the process of manufacturing a part by AM. In order to have confidence in the integrity of the part each of these individual steps must be carried out correctly and can greatly reduce production cost and time, yet there is no standardized way of proving to manufacturers and regulators that printed products are safe.
LR is working with a number of partners, to consolidate research and development efforts, alongside real-world AM practices, to create new product certification guidelines - paving the way for widespread adoption of the technology.
The purpose of the guidance document is to provide industry with goal-based certification guidelines for the manufacture of metallic parts/components using additive manufacturing (AM).