bluuebunny/crossref_metadata_2025_split huggingface dataset:
Big Data is Here, Challenges of Converting Big Data for Use by the Human Brain
Authors: Wu Yin , Bourgeau Edward Kenneth , Aspin Jason Conrad 
Published: April 2020

Modern offshore processes can now generate a large amount of high-resolution data, and this data is now being collected on various data collection systems. The traditional approach of process data is real time changes in operations (controllers or human operators taking action) or in the case of a failure, post-event scrutiny by experts. With the current data handling technology, the sheer volume of data actually deteriorates the effectiveness of post-event scrutiny. The promised insight to our process from access to "Big Data" has not yet been fully realized.
To simply implement effective post-event clarity and further, to really capitalize on this massive volume of data, industries need new technologies and approaches to "data." The studies in this paper fully embraced the data driven concept, and actions taken to integrate and interpret this data to drive faster and more accurate decisions.
There is real proof that managing and interpreting big data will lead to safely finding new resources, increasing recovery rates, reducing environmental impact and improving commercial efficiency.
This paper introduces strategies and specific examples of the utilization of Big Data analytics and how to use edge computing and cloud computing to reduce the cognitive burden of highly efficient operations. The infrastructure necessary to acquire data from existing digital machines, how to manage security risks associated with data collection, synchronizing data from multiple sources and how to benefit from this data now and in the long term.
Validation of a Transient Multiphase Flow Simulator for Offshore Transient Operations in a Gas-Condensate Pipeline
Authors: Jauseau Nicolas , Zakarian Erich , Morgan Julie E , Zambare Neeraj 
Published: April 2020

Abstract
The performance of a transient multiphase flow simulator was evaluated using high-quality field data measured in a large diameter gas-condensate offshore production system during different operating conditions (pigging, production shut-in and restart, production ramp-up, quasi steady state).
Production data included measurements recorded from more than 120 sensors (pressure, temperature, flow rate, monoethylene glycol (MEG) fraction, slug catcher volume) during a three-year production time span. After thorough data screening and analysis, 19 distinct subsets encompassing both steady state conditions and at least one pigging event per subset were selected as benchmarks for validating simulation results. For each subset, a simulation model was developed to account for ambient and operating conditions, fluid properties, bathymetry profiles, thermal insulation and pipe burial, and hydrate inhibitor tracking (MEG).
A comprehensive statistical analysis comparing predicted and measured pressure drop, pigged liquid volumes, outlet temperatures, and rich MEG mass fractions over the three-year time period demonstrated that the simulator predictions were in good agreement with the field data. The analysis included an uncertainty assessment of the measured production flow rates and volumes to better estimate the simulator accuracy. It was found that the simulator predicted both the cumulated rich MEG and condensate volumes received at the delivery point within the measurement uncertainty. The predicted rich MEG fractions at delivery were also in good agreement with the measurements, underlining the reliability of the inhibitor tracking module of the simulator. The pig travel time and the total liquid volume displaced by the pig during each pigging event were the main parameters considered to evaluate the accuracy of the simulator; both were predicted within a 10% error margin.
Multiphase flow simulators are often developed and tuned against experimental data recorded in small to medium diameter scale pilots. The opportunity to validate a transient multiphase flow simulator against measured operating conditions in large diameter pipelines over an unprecedented three-year time span is valuable, not only for quantifying the performance of the simulator, but also for assessing its scalability.
An Evaluation of the Effect that Motions at the Nacelle have on the Cost of Floating Offshore Wind Turbines
Authors: Taboada Miguel , Ortega Alvaro , Martín Rafael , Pombo Albino , Moreu Jaime 
Published: April 2020

Offshore Floating Wind is finally emerging as a promising source of Renewable Energy, but the Industry still faces important challenges. Among these, the impact the floater's motions have on the product life-cycle performance still requires evaluation and validation. In this sense, the industry has struggled to define an approach that minimizes the Levelized Cost of Energy (LCOE). The reasons for this, among others, are that each floater typology induces different motions on the nacelle equipment, each metocean site conditions are different, and the wear at the nacelle depends on the turbine model and manufacturer. Hence, the industry recommendations have so far usually limited the maximum longitudinal accelerations at the nacelle to 0.3-0.4g, and the maximum roll-pitch combination is set below 10°.
The induced motions add dynamic loading, wear down the mechanical equipment, produce fatigue damage on the structural members and are a source of potential downtimes, due to machine failures or simply due to unacceptable accelerations at the nacelle. Therefore, the different components of the turbine should be reinforced, increasing the CAPEX; or the maintenance and repair activities with its associated costs should increase; being both a possible combination.
The purpose of this paper is to analyze the different costs items associated with more or less conservative approaches with regards to the motions at the nacelle highlighting the combination of accelerations, operational weather windows, construction and maintenance strategies that can lead to the optimum LCOE.
Several response spectra of accelerations at the nacelle will be obtained for two different floaters, namely; a spar and barge preliminary sized for the DTU-10MW reference wind turbine. The effect of the turbine controller on the motions is not considered. For different acceleration cutoff values, the energy produced is estimated.
Leveraging Additive Manufacturing AM Technology to Enhance the Performance and Reliability of Gas Turbines for Offshore Oil and Gas Applications
Authors: Panfili Gianni , Balestrino Cristiano 
Published: April 2020

Abstract
With world-class experience and capability in metal additive manufacturing (AM), Siemens is introducing this game-changing technology throughout the entire gas turbine portfolio. Today Siemens Gas and Power has a dedicated organization to implement and adopt this technology, which enables engineers to design new components free of the barriers and constraints of conventional manufacturing methods.
A product like the SGT-A35 (Industrial RB211) gas turbine, which has earned a dependable reputation worldwide in offshore applications, has been enhanced in several ways by additive manufacturing. This paper will explore some of the AM development efforts for the SGT-A35, as well as the many benefits being realized. These benefits include improved reliability and performance, manufacturing and supply chain simplification, faster iterations and shortened development programs and opportunities for new repair and aftermarket solutions.
Water Intake Riser WIR – from Design to Installation, an Example of Complex Structure Requiring Multi-Disciplinary Approach
Authors: Minguez Matthieu , Clergue Simon , Van Kessel Jan , Bessière Lionel , Pattedoie Stephane , Renaud Maxime , Skledar Matthew , Lange Frank , Miller Edward , Masterton Stephen 
Published: April 2020

AbstractIn strong collaboration with the oil company consortium, contractor and their subcontractors successfully designed and installed a novel Water Intake Riser (WIR) on Prelude FLNG, the world's largest FLNG facility. The scope involved transforming a concept into reality by close collaboration between the contractor and client team at various offices and worksites from project start to offshore installation. Preparation for this operation included activities at various locations around the world such as Factory Acceptance Testing in Norway, USA, UK and France. The final Site Integration Testing was performed at the FLNG in South Korea before Prelude FLNG left the yard.Designing a Water Intake Riser (WIR) at this scale capable of surviving 10,000 years cyclone with a design life of 25 years has raised a variety of engineering challenges including; riser head-loss, loadings under survival events, novel flying leads and umbilicals, fatigue of key element such as chains, spacer-frames and riser girth welds. Full-scale tests were performed on critical components of the WIR for example the rubber hose, chain, and connectors. In addition, the system was tested at scale in model scale basins.Offshore execution in Australia involved the installation of large diameter steel pipe sections assembled with merlin connectors and the largest submersible pumps of their kind inside the FLNG Hull. Bespoke installation aids were used such as an over-the-side Riser Assembly Tower. Successful execution required maintaining Prelude FLNG at a favorable heading to minimize motions and achieve millimeter precision pipe assembly.
Floating Production Systems: What’s Next?
Authors: Turner William Judson 
Published: April 2020

Abstract
The drastic fall of oil prices in late 2014 forced a harsh but necessary overhaul to design philosophy in deepwater projects. Bigger was no longer better; the industry set to work on methods for commercial improvement like lean design and standardization. Throughout a slow recovery in commodity prices and steady persistence to innovate and implement improvements, the deepwater sector made significant strides in commercial and operational efficiency. This paper discusses some background and foundation providing insight on the commercial drivers post 2014 that significantly changed floating production system (FPS) design philosophy, with a particular focus on US Gulf of Mexico. The paper explores near-term outlook of design; looking more in depth at lean design and "hub-n-spoke" models. It also explores longer-term outlook of the next chapter in FPS design, touching on technology and automation that can relocate staff onshore, increasing safety, reducing capex, opex and increasing return on investment (ROI). The commercial analyses presented in this paper are indicative and subject to revision.
The paper is one that will set the stage for the 2020 OTC technical session: Floating Memories – Look Back to Leap Forward.
Pipeline Walking: Accurate Estimation of Mitigation Force for Axial Movements due to Global Seabed Slope and Steel Catenary Riser Tensions
Authors: Elendu Emmanuel Chigozie 
Published: April 2020

Abstract
Deep water pipelines operating under high pressures and temperatures are susceptible to gradual global axial movements over a number of heating and cooling cycles – A phenomenon known as axial walking. These cyclic axial movements that occur in high pressure-high temperature(HPHT) offshore pipelines are usually induced by four mechanisms: Seabed slopes along the pipeline routeRiser base tension induced by a steel catenary riser at the end of a pipelineThermal transients during startup/shutdown cyclesMultiphase flow behaviour like slug-induced flows, start up, shut down and ramp up operations
Several mitigation measures for pipeline walking as a results of these mechanisms have been developed and studied over the years with the most common being the use of hold-back anchors installed either at the middle or the end of a pipeline, the latter being the preferred method. Historically, estimation of the required anchor force to restrict pipeline axial movement has been premised on the amount of soil frictional resistance required to equal the driving force due to temperature and pressure. This methodology can lead to erroneously high estimates of the required anchor force for walking mitigation, leading to large-sized pipeline anchors with an attendant increase in capital expenditure associated with pipeline projects. This paper estimates, with a higher degree of accuracy, the required anchor force to mitigate axial walking due to seabed slope or steel catenary riser(SCR) tension.
The methodology described in this work involves the use of a mathematical proof to show that the magnitude of the walking mitigation force for a pipeline susceptible to walking is directly proportional to the pipeline submerged weight. The solution was also validated by a finite element analysis(FEA). The finite element analysis was carried out using the multipurpose industry FEA tool, Abaqus with the pipeline modelled using beam elements and the soil modelled using three dimensional analytically rigid elements. The coulomb friction model was used with frictional forces defined in the axial direction only.
Several cases were analysed in Abaqus using several pipeline sizes and soil friction coefficients in order to validate the analytical results. The analytical and FEA results agree quite well and show that the restraining force required to mitigate pipeline walking due to global seabed slope and SCR tension is solely dependent on the pipeline submerged weight and SCR tension respectively.
This paper proffers a cost-effective mitigation to seabed slope and SCR induced walking by showing that pipeline walking mitigation is not dependent on the magnitude of the axial friction resistance which usually requires large mitigation forces to counter the large frictional forces that may result particularly when we have a fairly long pipeline.
Delivering a Clean-Sheet Active Sealing Device for Deepwater MPD Operations: From Design to First Use
Authors: Johnson Austin , Sundaramoorthy Saravanan , Ameen Kareem , Nichols Jess , MacGregor Alex , Fraczek Justin 
Published: April 2020

Abstract

Objectives/Scope
This paper shares results from the successful first use of an active sealing device in a narrow margin deepwater well in the Black Sea. The active sealing device is a clean-sheet design approach which is purpose built for deepwater Managed Pressure Drilling (MPD) operations. This paper shares highlights from design, testing, and first-use stages of the program.

Methods, Procedures, Process
This paper discusses the three key program phases from development to field operation. An overview of the detailed design phase introduces system elements and purposes. An overview of the fullscale prototype testing phase discusses design verification testing, system optimization testing, and systems integration testing measures taken prior to field deployment. Finally, an overview of the field deployment phase shares outcomes from the first deployment on a dynamically positioned deepwater rig drilling a narrow margin MPD well in the Black Sea.

Results, Observations, Conclusions
The paper shares conclusions from each of the active sealing device development program phases. Upscaling passive RCD technology for deepwater has had negative effects on performance. A nonrotating seal sleeve element design eliminates multiple high-wear RCD components. Elimination of bearings and rotary seals removes common system failure modes. Redundant, active seal elements ensure wellbore seal quality throughout the seal life. A lubrication system extends seal life and enables active seal condition monitoring. Active seal condition monitoring alerts the rig crew prior to failure to replace the seal assembly. Full-scale testing demonstrates the system under simulated drilling conditions. Seal life observed at over 200 rotating hours, outlasting most deepwater MPD hole sections. First active sealing device integrated into deepwater drillship. Multi-modal seal control system provides crew operational methods to reach the total depth. Consistent seal life enables rig crew to better plan and drill MPD sections with confidence. First deepwater MPD well drilled using the new active sealing device.

Novel/Additive Information
The project discusses other novel aspects such as drilling contractor ownership and integration of the MPD equipment. A design objective is to enable new models of MPD system fleet management to allow drilling contractors to share equipment between rigs. The integrated active wellbore sealing system allows communication between the rig drilling control system, subsea and topside equipment, and all 3rd party systems, while sharing commonality with other rigs in the fleet.
Tripping the Light Fantastic – When 3 Becomes 1
Authors: Murdoch Euan , Day Paul , Walduck Steven 
Published: April 2020

This paper addresses the hurdles that have prevented the single-trip installation of upper and lower completions in the complex world of subsea and deepwater applications. It examines the processes, technologies, and risk mitigation steps that took a concept from pilot to successful deployment
This paper examines the current practice and rationales that had dictated a near 30-year industry standard methodology. This was not a case of tearing up the rule book, but of re-writing certain chapters. Our study examines the methods used to evaluate risks, mitigate same, test thought processes through to systems integration testing, and ultimately take what was a complete-the-well-on-paper exercise to a complete-the-well-in-practice outcome. The study will look at novel and not-so-novel technologies deployed; why were they chosen and how were they qualified.
Offshore and deepwater activity is returning; cost control, better project management and new technologies have provided a step-change in project economics. Typically, the completion of certain deepwater wells will necessitate the separate deployment of sand face, intermediate and upper completion. But what would result if this could be done in a single trip? In the simplest terms, completing in a single trip reduces the overall completion time by half and more. The case against is well founded; building the case for the change of long-established methods in our industry has never been an easy task. The steps taken to build this case will be examined, how fear of the new was overcome, and, having established proof-of-concept and beyond, taking the project to a fruitful outcome will be explored. However, what will be explored is no silver bullet, has no universal appeal and requires diligence, planning and contingency to drive success. But the prize is there, the risks can be mitigated, and when successful, will deliver an impact on project economics that very few technologies and techniques have delivered on such a scale.
Additive Manufactured Shapes used to Cure Total Lost Circulation Events
Authors: Hitchcock Graham 
Published: April 2020

Abstract
Lost circulation is a major cause of drilling non-productive time. Lost circulation events can range from seepage, partial, severe and total losses. An extensive range of Lost Circulation Materials (LCM) are available and commonly used to cure seepage and partial losses. However, severe and total losses are not curable using standard LCM solutions and alternative time consuming and expensive remedial solutions are required. A supplement to conventional LCM has been designed to extend standard LCM loss curing capability to cope with severe total loss circulation events.
Conventional LCM limitations are reported to be formation fracture widths up to 4-6 mm in size. Formation fractures greater than this limit will become problematic to cure using conventional LCM, the fractures are too large for LCM to collect, bridge and create an efficient pressure seal between the formation and well bore. When conventional Lost Circulation cure solutions prove ineffective, more costly solutions involving tripping and specific remedial treatments have to be utilized.
An Additive Manufactured shape used as a supplement to standard LCM has been designed and tested has be shown to increase the loss curing capabilities of the standard LCM to larger formation fractures typical of Total Lost Circulation events.
The Additive Manufactured Lost Circulation Shape when used with existing and readily available LCM product has been shown to extend the plugging range of a LCM from the typical 4mm - 6mm to larger total loss fractures of 20mm to 40mm. The Lost Circulation Supplement deployed with standard LCM will extend the loss curing capability of existing standard LCM's. By extending the curing capabilities of standard LCM costly and time-consuming tripping and alternative Lost Circulation remedial solutions can be avoided.
Autonomous Evolution Robotic Systems for Underwater Surveillance and Inspection
Authors: Jabari Rami , Cheng Tao 
Published: April 2020

Abstract
The oil and gas industry has been focusing on enhancing safety, reliability, and reducing costs associated with subsea surveillance and inspections. Emerging robotic and sensing systems, as enabling technologies, are being adopted and adapted by ExxonMobil in various applications. This paper presents multiple use cases where ExxonMobil has utilized these systems to address the challenges within our operations, more specifically, miniature remotely operated vehicles (mini-ROVs) and shallow-water autonomous underwater vehicles (AUVs), along with the learnings from these applications and proposed future systems.
Mini-ROVs equipped with optical and acoustic sensors are currently being used by ExxonMobil for the inspection of hulls, platforms, and mooring chains. After achieving favorable results with miniature systems that are remotely operated, there was a natural shift towards autonomy. Low-logistics shallow-water AUVs equipped with sidescan sonar, multibeam sonar, and optical cameras are now being utilized by ExxonMobil for pipeline inspections and environmental surveys. The successful experiences from both robotic systems have built a strong foundation for ExxonMobil as the industry's interest in subsea resident systems increases.
Successful pilot tests by ExxonMobil conducted in the past couple of years have demonstrated that a large support vessel and extensive human intervention can be eliminated. The utilization of emerging robotic and sensing systems for subsea surveillance and inspections has proven to enhance safety and reduce cost by an order of magnitude when compared to conventional techniques.
Private Equity Financing and Third-Party Infrastructure: Future Enabler
Authors: Khurana Sandeep , Rostant Justin , Wilson Julie 
Published: April 2020

Abstract
This is one in a series of papers in the technical session, "Floating Memories – Look Back to Leap Forward." The paper focuses on the evolution of ownership and the financing model for upstream and midstream infrastructure in deepwater. It provides an historical perspective on the value chain, starting in the 1990s when offshore oil companies owned and operated entire infrastructures. As industry matured, pipeline companies and service providers began taking ownership positions in partnerships with the operators. Most recently, private equity has stepped up to invest in infrastructure, using creative financing models now in play.