bluuebunny/crossref_metadata_2025_split huggingface dataset:
A deaf and a hearing student learning Portuguese and Libras in a tandem context
Authors: Figueiredo Francisco José Quaresma de , Oliveira Quintino Martins de 
Published: February 2019

Inclusive education in Brazil has created a linguistic reality at schools in which deaf and hearing people share the same space (QUADROS; KARNOPP, 2004). However, some obstacles make it hard for this interaction to flow naturally, both by deaf people who do not master Portuguese and hearing people who do not know Brazilian Sign Language. Various studies about the process of teaching and learning spoken languages emphasize the relevance of collaborative interaction in pairs or in groups in the co-construction of knowledge (FIGUEIREDO, 2006; SWAIN, 1995). It is in this collaborative context that the present research takes place with the objective of promoting authentic contact between deaf and hearing people, who are beginners in the languages being studied, by means of tandem language learning. It is an approach used in the learning of spoken languages with the purpose of promoting linguistic and cultural exchange among people whose native languages are different (BRAMMERTS, 1996). We intended to verify the possible benefits of such approach to the speakers of languages of different modalities: a spoken language (Portuguese) and a visual-spatial language (Brazilian Sign Language - Libras). A deaf student and a hearing one who take Brazilian Sign Language as a major at the Universidade Federal de Tocantins, Porto Nacional, Brazil, took part in this study. They had to teach each other idiomatic expressions in their own languages. The collaborative strategies used by them and the negotiation established in such encounters show that the interaction among deaf and hearing students contribute to the process of learning the languages.
Slim Well Casing Design for a Deepwater Application Using a Fast and Flexible Finite Element Engine
Authors: Panayirci Murat , Houette Olivier , Brands Sjoerd , Paraschiv Marius , French Simon 
Published: February 2019

Abstract
In the exploration and production (E&P) industry attempts at reducing the cost of the well construction by applying various well architecture slim designs has attracted attention from operators for decades. The recent industry downturn has further contributed to a renewed focus on this strategy. In this study we present a slim well design application within the FortunaCo project (a Joint Venture between OneLNG and Ophir), which aims at developing the Fortuna and Viscata fields in Deepwater offshore Equatorial Guinea. An advanced static nonlinear Finite Element engine is used in this process, which considers contact and friction; can handle large deformations and is therefore suitable to carry out buckling analysis. The top hole structural robustness is analyzed using this engine in the event of a worst case axial load, which for this study is assumed to be:The Conductor Pipe (CP) able to take its own weight only,The upper section of the surface casing (inside the CP) free of cement,The full buoyant weight of the Horizontal Christmas tree and Subsea Blowout Preventer applied onto the well.
This paper demonstrates that the selected numerical model is suitable to estimate critical buckling loads and identify post-buckled modes exerted on surface structural casings. Furthermore, it is shown that the visualization capabilities and speed of the engine allow the operator to optimize the design iteratively in an efficient manner. We conclude that the selected methodology is suitable for the operator to validate a slim well design for a Deepwater development application at concept phase for minimal cost with the necessary level of confidence.
Eliminating Rig Time from MWD Surveying
Authors: Lowdon Ross , Breen Michael , Mouyiasis Michael , Edmunds Michael , Bulychenkov Konstantin , Brovko Katerina 
Published: February 2019

Abstract
Directional surveys are taken while drilling a well to enable well placement and to avoid hitting other wells. This requirement is becoming increasingly important as reservoirs become more complex to reach and fields become ever more crowded. Taking directional surveys either before, during or post connection takes time, waiting for surveys to be pumped up takes longer and may need to be repeated if a critical survey cannot be taken first time which is a particular problem in shallow hole offshore operations. This paper outlines an industry first technology that will effectively eliminate surveying time, a definitive continuous survey will be available to the directional driller at all times, eliminating the need to take and wait for a survey before making the next directional drilling decision.
Continuous 6 axis surveys are cutting edge replacement for the static six axis Measurement While Drilling (MWD) surveys which have been used as the primary surveying tool worldwide for decades. The three magnetometers and Inclinometers provide an accurate inclination and azimuth when the drillstring is stationary. Continuous six axis MWD surveying could be described as a static survey captured continuously while drilling a stand allowing for accurate inclination and azimuth at all times. The directional driller will know where they are definitively at all time, eliminating the requirement for surveying time, enabling efficient decision making while eliminating the need for additional pump cycles, their associated wash outs and the directional difficulties that stem from that.
Field test examples of this continuous 6 axis MWD surveying will be shown with comparisons between other MWD systems these will be analyzed to establish consistency and accuracy. An error model for the continuous six axis survey will be discussed in some detail, as it is inherently different to a normal static MWD survey and comparison will be made to other error models. The time savings involved with continuous six axis surveys will also be shown, with a discussion on the associated benefits to the directional driller from reduced pump cycles.
Directional surveying is generally seen as a must have on a rig, however the associated rig time is considerable. This unique and world first method will discuss how continuous six axis survey are made, the accuracy modelled and so how the industry can eliminate rig time associated with MWD surveying.
Automated Preprocessing Techniques for High Frequency Downhole Sensor Data
Authors: Baumgartner Theresa , Ashok Pradeepkumar , van Oort Eric 
Published: February 2019

Abstract
Good quality downhole drilling data can provide valuable insights into the downhole environment, allowing for improvement of the drilling process. It can also greatly facilitate drilling automation. Despite these benefits, there are still high barriers to using downhole data in a timely and efficient manner. The work presented here aims to improve its usability for engineers and analysts by introducing a variety of strategies to automatically correct and draw insights from downhole measurements without human inputs.
Downhole dynamics measurements show errors that are currently inevitable, particularly because downhole sensors are affected by factors such as high pressures, high temperatures and a lack of appropriate calibration procedures. Methodologies for automatic corrections of such errors are presented and described in detail. All approaches are tested on medium to high frequency downhole data from a variety of field data sets.
Commonly observed sensor errors include drifts in accelerometer and strain gauge data. An algorithm described here corrects vibration data for offsets and enables a comparison of vibration levels throughout runs which otherwise would be impacted by such drifts. Strain gauge sensor drift affects weight/torque on bit measurements, which are generally corrected manually. The algorithms proposed here make better corrections than manual procedures by finding the exact instance of neutrality. This can potentially make time-consuming taring procedures in rig operations obsolete. Time alignment of downhole and surface data is another barrier for a comprehensive analysis and is often a source of many errors. Simple but effective methodologies are described that auto-align time-based data sets, even considering latencies due to travel times. In addition, novel data reduction techniques that help to effectively process, display, and analyze high-frequency data are also discussed.
Analysis of downhole data currently requires skills and experience that must be developed in a labor-intensive way from scratch in many organizations. This work summarizes practical experiences and novel scientific insights that can help any engineer to kick-start downhole data analysis. The paper aims to increase transparency and share ideas amongst the drilling community, with the goal of improving drilling performance through downhole data analysis.
Real-Time Drillstring Vibration Characterization Using Machine Learning
Authors: Millan Ekaterina , Ringer Maurice , Boualleg Riadh , Li Denis 
Published: February 2019

Abstract
Downhole shocks and vibrations have been identified by many operators as one of the biggest causes of Non-Productive Time, the most significant factors limiting rate of penetration (ROP) and the leading cause of premature failure of downhole tools. Today most of the existing methods for detection and characterization of downhole dynamics rely on costly downhole sensors integrated in bottom hole assembly (BHA). This paper presents a new technique for detecting and characterizing drillstring shock and vibrations in real-time using solely surface measurements and a machine learning method. Using historical offset well data and simulated well data, this new technique provides a method to build a classifying model that can be used during drilling operations to characterize real-time drilling data. Validation of the new technique on recorded data demonstrates the method’s capability to detect and characterize downhole dynamics such as stick-slip and lateral shocks from surface measurements.
Optimized Cuttings and Slops Management Help Save 250 Days on Six-Well North Sea Program
Authors: Toft Martin , Farr David , Strøm Knut-Are 
Published: February 2019

Abstract
The operator set challenging rate of penetration (ROP) targets on a six-well campaign in the Norwegian Sea, with total depths between 6000 and 7000 m (19,500 to 22,750 ft) and initial targets of 70 m/h (17.5-in. interval) and 120 m/h (12.25-in. interval). To support these ROPs, the cuttings and slops management system should provide higher conveyance and storage capacities than typically observed during drilling operations. When specified ROPs were achieved, targeted rates increased on subsequent wells.
Collaboration among the operator, rig crews, and service provider was important to operating the high-volume cuttings management system. Adequate transfer and storage capabilities were essential on both the rig and vessels delivering waste to shore for disposal. The final configuration included the following components:2 × 16-in. Conveyors, each feeding 2 pneumatic cuttings collection/transfer units11 High-capacity, nonplugging storage tanks1 Flexible hard-pipe system for simultaneous transfer to/from storage tanks2 Cuttings transfer hoses for simultaneous discharge to vessel1 Modular slop treatment unitCuttings transport tanks on the vessel
On the final well, ROP targets increased to 130 (17.5-in.) and 230 m/h (12.25-in.). Operating at 80 to 90% capacity, the system managed up to 60 mT of cuttings per hour. A total of 8959 m3 slops was treated, resulting in the overboard discharge of 8769 m3 treated water (oil-in-water concentration was 11.9 ppm), and waste volume sent to shore was reduced by 98%. The drilling program was completed 250 days faster than planned, and wells were delivered for production one year earlier than planned. The reduced time allowed the operator to drill a seventh well within the timeframe allotted for the original six-well program. Achievements of the seventh well continue to exceed expectations.
Close collaboration between the operator and personnel in the service company’s integrated rig team made this possible. Equipment operators continually optimized the process and delivered a high level of adaptability while ROP targets increased. This project set new standards for drilling performance on the Norwegian continental shelf.
Data Quality at the Rigsite - Automated System to Zero Bit Weight and Differential Pressure
Authors: Borjas Ricardo , Creegan Andrew , Perdomo Angel , Shults Derrick 
Published: February 2019

Abstract
Surface sensor data quality at the rig site has been the topic of much discussion in the industry as the information is increasingly used for the optimization of rig activities, planning, and modeling. While a great portion of data quality relies on sensor calibration and maintenance, a few measurements require human input, such as surface weight on bit and differential pressure. The objective of this paper is to describe an automated system integrated in the Electronic Drilling Recorder (EDR) that tares the weight on bit and differential pressure readings based on rig activity.
The system utilizes high-frequency surface sensor data from the hook load, pump pressure, string rotation, mud flow in, and block position to determine the appropriate rig activity to tare both parameters. The system can be activated at any time by the driller at the rig site, real time center engineers, drilling engineers, drilling analysts, and any others with access to it remotely. After the process is done an automated note is placed on the EDR for traceability.
The result of the implementation of the system is improved data quality on the EDR that is used for real time monitoring, optimization, modeling, planning, and an ultimate improvement in the quality of the well's data archives.
Automating data sensitive work flows at the rig site, improves data consistency, quality, and frees the driller's attention to more important work flows.
Challenges and Solutions for Accurate Wellbore Placement in the Barents Sea
Authors: Mitkus Alexander , Maus Stefan , Willerth Marc , Reetz Andrew , Oskarsen Ray Tommy , Emilsen Morten Haug , Gergerechi Amir 
Published: February 2019

Abstract
As development of the Barents Sea continues with new plays such as the Castberg, accurate specification of the local magnetic field is important to reliably infer the orientation of the bottomhole assembly (BHA) in horizontal drilling. Since magnetic fields at high latitudes vary spatially and temporally, one requires both spatial models and a way to capture temporal changes. Large temporal changes in the magnetic field can severly distort measured azimuths and therefore must be corrected for.
This study, based on a report written for Petroleumstilsynet (Maus et al., 2017), shows that in regions of the Barents Sea within 50 km of a magnetic observatory, either the nearest observatory, interpolated infield referencing (IIFR), or the disturbance function (DF) method may be used for corrections in wellbore surveying to meet accuracy requirements. IIFR and DF will give better error reduction but are slightly more complicated to implement. At distances between 50 km and 250 km, the disturbance field (DF) method best meets accuracy requirements. In remote regions beyond 250 km, a local observatory must be deployed to meet the highest accuracy specifications, but the DF will still far outperform the other interpolated methods at such large distances from an existing observatory.
Despite having focused on the Barents Sea region, this comparison of the accuracy of different spatial and temporal magnetic field mitigation methods for wellbore surveying is applicable to high latitude northern and southern regions across the globe.
Customized High-Rate Cuttings Reinjection System: Effective Design Maintains Continuous Zero Discharge Operations on Sakhalin Island
Authors: Mahrous Ramy , Tsoy Vassiliy , Ellis Robert 
Published: February 2019

Abstract
Cuttings reinjection (CRI) is a globally accepted method for the disposal of drilling and production wastes, as it eliminates logistical challenges related to waste transport and storage, as well as the need for third-party disposal, which is often required by more conventional approaches. However, the CRI system must support penetration rates as high as 152.4 m/s (500 ft/hr). In arctic regions, the entire system must be winterized, while retaining ease of mobility for rig moves. Therefore, each CRI operation requires a customized design that correlates with drilling parameters, the local climate, and the scope of the drilling project.
On Sakhalin Island, an arctic area known for stringent regulations and a focus on highly optimized well construction, a CRI system was installed after intensive planning that accounted for the continued use of the original 2009 injection well, real-time cuttings collection in a winterized module, high capacities and process rates, continuous slurrification operations, and injection performed using cement pumps.
During a 14-month period, the customized CRI system successfully injected 95,867 m3 (602,988 bbl) of waste fluid from the six wells where the highest volumes were generated. The system delivered 100% operating efficiency throughout the project, keeping pace with the drilling activity, with a cuttings volume reaching up to 385 m3 (2,425 bbl) in one 24-hr period. Water-based cuttings and waste fluids from other rigs were also processed during this time. The system met all established performance criteria as outlined for the project's scope of work, including specified processing rates per hole section, slurries within specification, effective pumping schedule, and accurate and timely reporting.
Zero surface discharge projects present unique challenges that can be safely overcome with CRI technology. This paper describes essential steps in designing the site-specific system, best practices for managing sustained high-rate cuttings injection operations, and lessons learned concerning system optimization under harsh conditions.
Real-Time System to Calculate the Maximum Load of High-Frequency Torsional Oscillations Independent of Sensor Positioning
Authors: Andreas Hohl , Eric Palata , Pedro Arevalo 
Published: February 2019

Abstract
Cutting forces at the bit or mass imbalances in downhole tools such as mud motors can cause severe vibrations in drillstrings and bottom-hole assemblies (BHA). Negative effects include reduced rate of penetration, low-quality measurements and downhole tool failures. A value that represents the real downhole vibration level is needed to perform a reasonable mitigation strategy. The most common values are statistical values derived from acceleration signals that are received from a sensor at a specific distance from the bit (DfB). The interpretation of an acceleration signal is limited if only one mode shape is dominantly excited. In this case, the measurement signal is very sensitive with respect to the DfB of the sensor placement.
The derivation of a representative value for the severity of high-frequency torsional oscillation (HFTO) is shown that is independent of the sensor position. In the proposed approach, the dynamic torsional torque is used in addition to the tangential acceleration measurement. The frequency information of both measurement signals are determined and an analytical model is used to calculate the maximum value of vibration amplitudes that occurs along the BHA. The algorithm is implemented in the measurement-while drilling (MWD) tool for vibration and load measurements. The maximum load value in the BHA corresponding to HFTO can be sent to the surface in real time for interpretation by the driller.
In a case study, different scenarios from the field are discussed. The maximum load values are compared to numerical simulations that show an excellent agreement. The maximum value calculated by the approach is factors higher than the values measured by the accelerometers.
By using the algorithm-upgrade of the MWD tool, a representative measurement value for the severity of HFTO loads is derived. This is a clear advantage compared to tangential acceleration measurement only. The value enables the driller or an automated advisory system to initiate the optimal HFTO mitigation strategy that leads to reduced levels of vibration with the known benefits for the cost of a well.
Steering Advisory System for Rotary Steerable Systems
Authors: Zalluhoglu Umut , Demirer Nazli , Marck Julien , Gharib Hossam , Darbe Robert 
Published: February 2019

Abstract
The challenging offshore and shale production environments have increased the need for cost-effective, standardized drilling operations while providing accurate well placement and high borehole quality. Automation of directional drilling processes bears the promise of delivering these consistent and reliable performances while maximizing production potential. This paper introduces a steering advisory system for rotary steerable systems (RSS), which provides steering decisions automatically given the BHA configuration, bit selection, well plan and/or target(s), and real-time sensory information received from the RSS. These decisions can be either displayed to directional drillers or down-linked directly to the tool for autonomous directional drilling. The system has proven itself on multiple commercial jobs across North America with a new generation RSS. By exactly following the advisory system-generated steering decisions, multiple curve sections were smoothly drilled and accurately landed within tight tolerances.
Using High-Resolution MWD Survey Data in Mud Removal Simulations for Effective Cementing Program Design
Authors: Monterrosa Leida Cristina , Tay Chuang Hwee , Salazar Jose Martin 
Published: February 2019

Abstract
The main objective of this study was to understand the impact high-resolution measurement-while-drilling (MWD) surveys have on casing standoff and mud removal simulations and its impact on final cement program design and risk analysis.
High-resolution surveys use a combination of static and continuous MWD inclination data to characterize the well trajectory at 3-m (10-ft) intervals rather than the current industry practices at every stand; i.e., 30 m (100 ft). However, several case studies had demonstrated that surveying the well path at these intervals is often not sufficient to capture the true characterization of the well in question. This result, in some scenarios, leads to significant errors in the final reported dogleg severity (DLS) and tortuosity; therefore, resulting in optimistic well engineering simulations due the hidden additional tortuosity not applied in the models.
Two North Sea wells were analyzed when using conventional trajectories defined at each drillstring stand as well as using high-resolution trajectories to evaluate the impact on casing centralization and mud removal simulations.
The latest generation cementing software for placement simulation was used in this study. The simulation has the capabilities to deal with computing pipe standoff and angle direction in a 3D annulus, including gravitational forces for accurate mud displacement and removal.
This study confirmed that high-resolution MWD survey data can provide additional precise input for casing standoff and mud removal simulation, resulting in a more realistic simulation result due to the appearance of microtortuosity and DLS. Simulation results using high-resolution directional survey data identified conditions where the original mud removal assessment using a standard survey was overestimated due to higher standoff. This result allows an appropriate level of risk assessment and cement job design optimization to improve both the casing standoff and mud removal, which will eventually impact the well integrity quality.
This study proved that centralization and mud removal simulations can be, in some scenarios, optimistic if performed using standard trajectories. The results also proved that the risk assessments for the cement program designs will be evaluated differently because the enhanced simulations provide a more accurate result, which impacts the final centralization and mud removal to ensure effective zonal isolation.