bluuebunny/crossref_metadata_2025_split huggingface dataset:
Offshore Hydrogen Production in the North Sea Enables Far Offshore Wind Development
Authors: Peters Rene , Vaessen Jacqueline , Meer Rene van der 
Published: April 2020

The North Sea area is in transition. While oil and gas production is in decline, the deployment of offshore wind turbines in large scale wind parks to produce offshore renewable energy is accelerating. The accelerated deployment of renewable wind increasingly far offshore creates challenges to transport large amounts of energy to shore. Traditional energy transport from offshore wind by means of HVAC power cables becomes uneconomic beyond 100 km from shore and energy losses are unacceptably high. Moving to HVDC cables reduces the power losses, but increases the cost of power conversion offshore. An alternative that currently is being considered is energy transport via molecules, in the form of hydrogen. The hydrogen is produced from seawater after desalinization by means of water electrolysis. The current pipeline infrastructure in the North Sea can be reused to transport the hydrogen at high pressure and low cost to shore. As large industry sectors are considering decarbonization by means of hydrogen, in particular for hydrotreatment, desulfurization and ammonia production, the so called ‘green’ hydrogen can directly be used onshore without reconversion to power.
Half of the assets in the North Sea are approaching end of life and decommissioning in the coming decade, which means they become available for re-purposing. Most offshore trunk lines also operate under their maximum capacity. Prior and ongoing research projects are aimed at identifying win-win combinations from this situation: to re-use platforms for hydrogen production (P2G), pipelines for hydrogen transport and perhaps wells for hydrogen or CO2 storage such that the variable nature of wind power can be exploited more efficiently.
The objective of the PosHYdon project, the first offshore hydrogen production plant is not only to build up experience with the production of H2 in an offshore environment, but it will also be a test center for innovative Power to Gas (P2G) technologies and integrated systems. The aim of the facility is to accommodate at least 1 MW of electrolyzer capacity, including its water treatment unit and auxiliary units. The objective of the project is to gain experience with the operation of a hydrogen production unit offshore, and the admixing of hydrogen in an multiphase flow pipeline carrying oil and gas towards a process separation and treatment hub located nearby. The pilot seeks to gain more detailed information on cost of installation and operation of an electrolyser unit in an offshore environment.
The Limits of Reduced Order Current Energy Converter Modeling
Authors: Olson Sterling S. , Topper Mathew B. R. , Chartrand Chris C. , James Scott C. , McWilliams Sam , Jones Craig A. , Roberts Jesse D. 
Published: April 2020

Abstract
Reduced-order models for mesoscale current energy converter (CEC) modeling allow for tractable computation times for investigations of array configurations on power performance and environmental effects to support design optimization. The CEC representation in these models take the form of actuator discs in codes such as SNL-Delft3D-CEC-FM treating the rotating CEC blades as momentum sinks. In the first-of-its-kind, whole-plant optimization software, DTOcean, the hydrodynamic modelling of CECs is reduced one step further by superimposing wake models based on normalized CFD simulations onto a set of pre-computed velocity fields, to provide power estimates. DTOcean is a new tool and the amount of verification and validation evidence gathered is presently limited. To gain additional confidence and industry buy-in to the software penetration, this study investigated a primary component of levelized cost of electricity (LCOE) calculation, annual energy production (AEP), through an analytic calculation of power using the results of an identical simulation in SNL-Delt3D-CEC-FM. Three configurations of an 8-turbine array are studied with DTOcean where two rows of 4-turbines are spaced (unstaggered) 5-, 10-, and 20-Diameters apart and the AEP was calculated; The energy calculation in SNL-Delft3D-CEC-FM were more computationally expensive for the mesoscale domain making the optimization of solely an arrays power production using the wake superposition method implemented DTOcean attractive. The codes however are complementary as SNL-Delft3D-CEC-FM simultaneously investigates environmental effects of varying array configurations while DTOcean considers all aspects of array costs through its lifetime to optimize LCOE from a whole-plant perspective.
Managing Hydrate Formation in Subsea Production
Authors: May Eric F. , Metaxas Peter J. , Lim Vincent W. S. , Jeong Kwanghee , Norris Bruce W. , Kuteyi Temiloluwa O. , Stanwix Paul L. , Johns Michael L. , Aman Zachary M. 
Published: April 2020

Abstract
Quantitative prediction of gas hydrate formation risk is critical for the successful implementation of risk-based approaches to hydrate management in subsea production. Here we use a high pressure, stirred, automated lag-time apparatus and a high pressure acoustic levitator to experimentally obtain smooth probability distributions describing stochastic hydrate formation. Robust, repeatable hydrate nucleation and growth rate probability distributions as a function of induction time and subcooling are measured for various gases, shear rates and inhibitor dosages in systems with interfacial areas ranging from (0.1 to 60) cm2. The results reveal that new engineering models can be used to reliably predict hydrate formation probability. Importantly these new models have solid theoretical foundations which enables them to be generalized with confidence to industrial systems.
Hidden Value in Maintenance System Data: Using Machine Learning to Correlate and Predict the Risk of Asset Failures
Authors: Pereira Paul Christopher 
Published: April 2020

Abstract
The prediction of equipment failures typically falls along two paths: statistical analysis of past failures, or using sensor data to monitor the condition of equipment in the field. This study instead takes a novel approach by implementing machine learning on the data within maintenance systems (which are typically used to monitor and track maintenance activities/workflows). This implementation serves to map the correlations between maintenance data and failures, to predict failures by only monitoring an organization's maintenance system.
This involved identifying maintenance system variables or attributes that normally represent specific steps in the maintenance process, but could potentially provide indirect information on the reliability of assets or the risk of future failure (e.g. work orders created/completed, work order types, original equipment manufacturer recalls/upgrades, inventory rotation rates, procedure changes, turnaround events, etc.). Machine learning is then used to determine correlations between failures and system variables (which results in an optimized model). The resulting model can then be implemented on current data to predict future failures.
Although largely designed around workflow management, the underlying metadata from an organization's maintenance system can indeed be transformed to provide valuable insights and quantify risk. Machine Learning is able to predict failures with a meaningful degree of accuracy. Even if the transparency of model logic is insufficient to take specific actions to mitigate failures, it is enough to dynamically assign a level of risk to individual assets, and even predict risk for future time periods. When interpreting the optimized machine learning model with methods such as feature impact charts, it is also possible to identify the strongest correlations between failures and different Computerized Maintenance Management System (CMMS) derived variables (variables that were designed and transformed from actual historical data for the purpose of model building). Insights gained from this additional analysis, such as the true impact that preventive maintenance delays have on risk, offer great potential for understanding the behavior of equipment and maintenance organizations.
Text-Mining Maintenance Records to Automate the Identification and Grouping of Failure Modes
Authors: Christopher Pereira Paul 
Published: April 2020

Abstract
The investigation of failure data typically involves manual interpretation of free text maintenance system records. Even if failure classification codes exist within an organization's system, they often do not include enough detail or accuracy to group or identify trends. The objective of this study is to develop an automated method to identify functional failures from maintenance record data. The result is a reduction in workload for manual analysis, as well as improved identification of failures and trends.
This study's methodology involves the sequential arrangement of multiple text-mining techniques. The techniques include: term frequency-inverse document frequency (TF-IDF), clustering, association rules, term matrix creation, and lexicon development for pre-processing text. In isolation these techniques have shown to be effective in non-industrial pursuits, such as marketing and retail sales. This study serves to apply them in the domain of equipment reliability. They are iteratively implemented and refined on maintenance system records, including work orders (which may or may not represent failures), as well as failure report records. The ability to identify failure modes, failed components, and trends is then evaluated.
The techniques were successfully implemented, and the effectiveness was evaluated for each when applied to science of equipment reliability. Text mining was shown to be partially effective in the pursuit of identifying failure modes from maintenance record free text. Certain sub-techniques were shown to be quite effective, in particular the clustering technique's ability to group failed components and failure modes. Hierarchical clustering is a promising technique for technical and industrial themed free text. It was also shown that the outputs of clustering can achieve different and valuable insights based on the types of text records implemented, and the types of pre-processing available to the organization. The association rules method was somewhat effective relative to clustering, as it was able to identify certain failure modes; however, this method still requires a degree of manual intervention and interpretation at this time. The overall results are promising. There is great opportunity for continued study along multiple fronts, including additional techniques such a sentiment analysis and topic modelling.
On the Development of an in-House Fines Stabilizer to Control Formation Damage
Authors: M. Ibrahim Jamal Mohamad , Mat Piah Mohamad Faizzudin , Panuganti Sai Ravindra , Salleh Intan Khalida , O. Hussein Adil Mohamed 
Published: April 2020

Abstract
Almost all Malaysian hydrocarbon-bearing sandstone reservoirs contain minerals which are potential sources of mobile fine particles. For this reason, formation damage in injection and production wells has been frequently associated with the migration of fines in reservoir pores. In this work, an effective, novel, environment friendly and cost beneficial fines stabilizer is formulated in-house.
The developed chemical works on the principles of coagulation and flocculation. Different coagulant and flocculant chemical combinations are trialed, and the understanding of their performance is shared using turbidity and zeta potential testing. The developed fines stabilizer chemical is later tested for compatibility with reservoir fluids and production chemicals of a field which is planning to apply fines stabilizer. Based on the potentiality in static screening results of turbidity, zeta potential and compatibility, a fines stabilizer is chosen for dynamic testing.
The constraint of critical flow rate for fines migration is addressed in dynamic study using core flood experimentation. Critical flow rates are determined by forward and reverse injection into core samples. Accordingly, the performance of in-house synthesized fines stabilizer is judged by enhancement in critical flow rate in comparison to untreated and commercial fines stabilizer treated cores. Since the constraint from the critical rate effects injectivity and productivity, modification of this constraint and increase of the critical rate consequently provides more economic benefit. The additional revenue from oil production by using the in-house developed fines stabilizer chemical is estimated, and the costs are compared with a commercial fines stabilizer.
The uniqueness of this endeavor is in developing an in-house fines stabilizer chemical which can be used after acidizing, enhanced oil recovery treatment, in production and injection wells. The synthesized in-house formulation is more effective and cost saving compared to commercial fines stabilizer.
The Tension Leg Platform: from Hutton to Big Foot
Authors: Leverette Steven J. , Hodges Stephen B. 
Published: April 2020

Abstract
This paper is one of seven papers that will be included in the special session: Floating Memories – Look Back to Leap Forward. The focus for this paper is on the Tension Leg Platform (TLP), one of the four major platform types that include the Floating Production Storage and Offloading platform (FPSO), the semisubmersible floating production system (Semi) and the Spar platform.
The paper summarizes the evolution of the TLP over three and half decades, and provides a thirty-five year retrospective of the progression of TLP technology, including hull shapes, tendon connectors, flex elements, and riser systems. It will walk through the evolution of understanding, analytical methods, and model testing to assess the complex global performance of a TLP, and the unique challenges of system dynamic resonant excitation, the so-called "ringing" and "springing" phenomena.
The TLP was a game-changer in bringing dry tree wells to floating platforms, leveraging dry tree drilling and well control methods from a generation of fixed platforms, and enabling multiple top- tensioned production and drilling risers in close proximity due to the limited tensioner stroke not possible on a drill ship or semisubmersible. The TLP has shown its applicability in water depths from the Hutton TLP (1982) in barely 150 m of water in the North Sea, to the Big Foot TLP installed in 1584 m of water in the Gulf of Mexico in 2018, the deepest TLP to date. And it has shown its flexibility in size ranging from the smallest mini-TLP's of 10,000 tonnes displacement, to the North Sea concrete hulled Heidrun TLP of 290,000 tonnes.
Fire and Blast in 1 Edition of API RP-2TOP Standard
Authors: Parihar Arun , Sari Ali 
Published: April 2020

Abstract
The main objective of this paper is to present and discuss the Fire and Blast design methodology for offshore platform topsides with reference to the API RP-2TOP Standard. The first edition of the API RP-2TOP standard has been published recently and consists most up to date provisions for the tospides design for fire and blast loads. The paper focuses on the key aspects of the topsides design of offshore platforms for fire and blast loading as addressed in the API RP-2TOP standard, summarizes the design recipe and highlights the differences between the API RP-2TOP and corresponding API RP-2FB provisions. A risk matrix is provided as a means to determine the acceptability of the risks from accidental events of fire and blast and can primarily be used as a means of screening low-risk events that do not need further investigation. In addition, a detailed and structured methodology is provided for structural assessment from fire and blast events. The fire and blast scenarios should be developed as part of the process hazard analysis.
A Preview of the Digital Component in the New Wireline Formation Testing Era
Authors: Garcia German D. , Dumont Hadrien , Chen Li , Eberhardt Scott , Babin Chris , Pfeiffer Thomas , Edmundson Simon 
Published: April 2020

Wireline formation testing has been routinely used for reservoir characterization in the Gulf of Mexico. The significant impact that fluid composition has on designing and operating production and processing facilities for these complex reservoirs requires comprehensive fluid sampling during exploration and appraisal. Vertical and lateral connectivity, fluid compatibility when commingling to meet production targets, or asphaltene onset potential along the production flow path are examples of the need for thorough understanding of fluid property variations.
This case study combines the use of the newest generation of formation testing platform with innovative workflows to acquire critical fluid data and refine the geological reservoir model in near real time. Conveyance difficulties foreseen in the S-shaped well suggested that the use of a shorter, lighter tool could increase the chances of success in a field where past keyseating episodes left few reliable alternatives for conveyance apart from drillpipe-conveyed logging. The application of the smart sampling platform capabilities introduced important changes to the standard protocols used in these cases.
The increased cleanup efficiency of the new formation testing technology enabled fast investigation of reservoir fluids at multiple depths with robust metrology for specific properties. The outstanding sample purity formed the foundation of advanced interpretation workflows. With its high-quality fluid data, this case was used to perform a "proof of concept" of advanced interpretation workflows aimed at updating geological and fluid models in near real time once the downhole fluid analysis data become available at the end of each sampling station.
The formation testing data and the near real-time answers expedited tailoring the completion of the well, which involved a nontrivial commingle decision. The fluid information also provided clarity for the geological model in a section of the field where the current seismic interpretation had shown uncertainty for the reservoir architecture in the downthrown block of the field.
The combination of new formation testing hardware and short-cycle workflows makes this case study the first of its kind. The proof of hardware performance and data processing/interpretation capability cements the case for higher-density data streams and a shortened data life cycle. It serves as a preview of how digitally enabled formation testing operations will be conducted in the future to provide new insights to reservoir understanding.
Subsea Wellhead Retrieval Tool Uses New Technologies to Successfully and Efficiently Complete Abandonment Operations
Authors: Olstad Delaney 
Published: April 2020

Abstract
The objective of the campaign was to safely and efficiently complete a plug-and-abandonment (P&A) operation in a harsh Norwegian North Sea well using a high-performance conductor-recovery tool. The operation used the newly reinvented, second generation mechanical, outside-latch, single trip (MOST) tool system. Along with recovering the subsea wellhead, the associated casing strings and conductor were to be cut and retrieved.
The standard MOST tool is a field-proven system, which latches externally to the wellhead, then cuts and recovers subsea wellheads. The newly released second generation system is a reinvented P&A tool that includes several innovative technologies to increase tool capabilities and performance. The latest release of the MOST tool includes a newly designed tension-cut mandrel, nonrotating flexible stabilizer (NRFS), large-diameter cutter, and high-angle knives. The system confirms the cut without the need for tripping, easily latches and releases to inspect the cutting knives, and does not cause damage to the internal wellhead sealing profile. Furthermore, the external-latch mechanism helps to prevent swarf buildup by allowing more flow area in the high-pressure wellhead, which permits the cuttings to easily exit. The latch and unlatch function can also be visually confirmed using a remotely operated vehicle (ROV) on the seafloor. External latching provides superior lateral support for the wellhead assembly to eliminate any lateral whipping that might impede cutting. The second-generation design of the MOST tool, with the tension-cut mandrel, provides pulling capabilities up to 1,000,000 lb (453,592 kg) and fail-safe features, which enable the outside latch to be released by the ROV, if needed.
The newly deployed system successfully recovered multiple subsea wellheads in Norway and demonstrated its operational effectiveness with reduced cutting times compared to traditional cut-and-pull operations. With advanced features, the subsea wellhead-retrieval system reduces rig time by cutting and retrieving multiple cemented or uncemented strings in a single trip. The NRFS and large-diameter cutter increase stabilization and minimize vibration during cutting, and the high-angle knives increase cutting efficiency when compared to traditional retrieval systems. The MOST system supports quick wellhead recovery, minimizes operational expenditure, and reduces rig time.
The new developments to the next generation MOST tool system give the customer several additional application choices. The various interchangeable components allow for a wide range of cutting options including abrasive cutting, tension cut, motor cut, and umbilical support for laser cutting.
New Innovative Technique for Scale Management During Water Flooding in Offshore Reservoirs
Authors: Salah Mohanad Ahmed 
Published: April 2020

Offshore reservoirs EOR present new challenges every day, during water flooding the primary injectant is sea water which is the mostly used fluid in Egyptian offshore wells in Mediterranean sea and Red sea which demonstrate undesirable problems to overall oil recovery process, main problem is scale deposits formation, specially of metal sulfate scale.
Scale deposition was found in many offshore wells in injection tubes and production well and both surface and subsurface equipment causes production declines and costing millions of dollars every year
In this study we developed unconventional techniques to remove and control scale formation during using sea water in injection, That techniques must be efficient and consider all reservoir and water compatibility aspects.
When scales found in either in water flooding pipelines or oil production pipelines and surface equipment's, the conventional way to remove those scale and regain efficient flow is mechanical jet blasting using high-pressure water to crack the scale but it was a time consuming root and need special equipment and large man power although it wasn't that efficient in areas with heat exposure and it can't reach some areas. So we moved to next root for removing scales by chemical cleaning based on inorganic acid like hydrochloric acid, sulphuric acid, etc. although it can dissolve the scale in very limit efficiency we didn't accept this method because those chemicals was very corrosive to metal surface like cast iron and stainless steel grade 304/316 also using those chemical present hard handling problem for adding or dilution. Therefore, we had to take the challenge to develop our new chemical cleaning methodology that combines between efficiency and safety. In new methodology, we developed new chemical formula based on mild organic acid mixture combined with sequencing agent, anti-re-deposition agent, wetting agent and pickling agent to chemically dissolve the scale in efficient and safe way.
The chemical cleaning technique was successful to dissolve the scale in very short time and in safe way to metal surface like cast iron and stainless steel. This invention is useful for the removal of sulphate scale like iron sulphate, calcium sulphate, barium sulphate and strontium sulphate from process equipment including pipes, pumps and storage tanks. It is also can be used to the removal of these scale deposits from other equipment such as boilers and heat exchangers.