bluuebunny/crossref_metadata_2025_split huggingface dataset:
‘BUT EVER SINCE SO TO SAY I HAVE TAKEN OVER THE PROPER WORDS … SO TO SAY I HAVE NO PROBLEMS’: LANGUAGE IDEOLOGIES OF VOJVODINA HUNGARIAN MIGRANTS AND COMMUTERS FROM SERBIA TO HUNGARY
Authors: Gábrity Eszter 
Published: March 2017

In this paper, I examine and compare views, beliefs and ideas about two varieties of Hungarian in the framework of language ideologies. The purpose of the present paper is to illuminate the linguistic situation of the Hungarian migrants and commuters from Vojvodina through the examination of their language ideologies. The study focuses on the language ideologies of migrants and commuters who belong to the Hungarian minority community in Vojvodina and moved to Hungary or commute between Hungary and Serbia on a regular basis, thus they have frequent linguistic contacts and interactions on both sides of the border. The research analyzes ordinary people’s views upon the relationship between their vernacular and the standard variety, their views related to the status of their vernacular as well as their bidialectal language use. I intend to reveal how members of the Hungarian minority community locate, interpret and rationalize (if so) sociolinguistic complexities of their everyday lives. [1] The present paper presents a segment of a research project: Integrating (trans)national migrants in transition states (TRANSMIG) – joint research project in the framework of the co-operation program SCOPES (2009-2012), submitted to the Swiss National Science Foundation (SNSF), coordinated by Prof. Dr. Doris Wastl-Walter (Department of Geography, University of Bern).
ПЕСМЕ У ПРОЗИ РЕНЕА ШАРА
Authors: Медан Маја Ј. 
Published: March 2017

Рад се бави проблемом форме песме у прози збирке „Бес и тајанство” Ренеа Шара. Механизам функционисања самог жанра, који се темељи на хераклитовском јединству супротности и принципу антистатичности, препознаје се на више различитих нивоа у Шаровом песништву. На тај начин, кроз сраслост за сопствену форму, пропитују се и интензивирају основне карактеристике Шарове поетике.
Using Turbine Technology to Run Casing, Liners and Completions to TD in Challenging Wells in Saudi Arabia
Authors: Okot Mike , Chima Jude , Muqeem Muhammad , Hajji Ali , Ramirez-Narino Alfredo , Al Haj Haitham , Rider John 
Published: March 2017

Summary
Reactive formations, resulting in wellbore instability, can obstruct the running of casing, liners, and completions. This problem is particularly acute in highly deviated, complex wellbore geometries, and long horizontal sections, where increased exposure time can lead to deteriorating hole conditions.
This paper reviews the use of a novel fluid-powered Turbine Reamer Shoe (TRS) to successfully run 9⅝" casing, 7" drilling and production liners, and 4½" liners and completions through problematic intervals and hole conditions. The downhole turbine provides high speed reamer rotation without rotating the entire string, and requires minimal modification to standard running practices.
The 9⅝" and 7" casing/liner running turbines present a further novel design feature: an unobstructed through bore (at API drift ID of the string on which it is run) for rapid drill out and drilling ahead.
Results from over 30 onshore and offshore wells from the Manifa development, and several other fields, including Berri, Zuluf, Qatif, and Safaniya are analysed.
The TRS is now becoming a technology of choice in the planning of challenging wells, to mitigate the risk of sticking, and to reduce the flat time and HSE exposure involved in conditioning the wellbore and re-running casing, liners, and completions.
Drilling the World's Longest 6-1/8 in. Offshore Sidetrack Completed With ICD Screen Partially Cemented System
Authors: Aljubran M. J. , Al-Yami A. S. 
Published: March 2017

Abstract
A 6-1/8 in. sidetrack was planned for well-M as a result of water coning where the water cut climbed to as high as 35% in this old well. Drilling a pilot hole preceded the sidetrack operation in order to assess the surrounding reservoirs in the target area and most prolific candidate. Local geomechanical analysis was carried out in order to establish a mud window and ensure quality drilling with minimal wellbore instability, thus save rig time and operational cost. Cutting flow meters were deployed to monitor the hole cleaning performance and raise any red flags for immediate reactions to any abnormal wellbore behavior that may indicate wellbore instability.
A drillmap was constructed highlighting the different hazard categories that could be encountered throughout the job and the proper solution that needs to be implemented. Tripping and hole cleaning best practices were also established to further increase the operational awareness and alertness throughout the job. Sweep pills, reaming and short trips were optimized to keep a clean hole and avoid disturbing the borehole. Two different BHA's were utilized to complete this borehole: steerable mud motor to drill the curved section, and rotary steerable system to drill the horizontal section.
Well-X witnessed the deployment of the world's longest 4-1/2 in. partially cemented system with ICD screens, 7,389 ft. The competent drilling efforts enabled running this stiff assembly all the way across this extended reach lateral. The off-bottom liner system was hydraulically set and cemented in place where the reservoir was compartmentalized across the section with 48 ICD screens and five non-inflatable mechanical isolation openhole packers. This paper will focus on the drilling design and operational practices that enabled the achievement and deployment of this record system.
Improving Torque and Drag Prediction Using the Advanced Spline Curves Borehole Trajectory
Authors: Abughaban Mahmoud F. , Eustes Alfred W. , de Wardt John P. , Willerth Marc 
Published: March 2017

Abstract
Torque and drag [T&D] are critical elements in drilling deep vertical wells with unnoted tortuosity along the borehole and in extended-reach and deviated wells with high and repeated tortuosity. Current T&D models generate unreliable predictions due to the assumption that borehole trajectories are composed of constant curvature arcs between survey stations [the minimum curvature calculation method]. This assumption causes the bending parameter in the T&D equilibrium balance equations to be nil. Today's T&D models are either based on a continuous drillstring to wellbore contact [the soft-string model] or intermittent contact due to drillstring stiffness [the stiff-string model]. In both cases, the wellbore trajectory is based on the minimum curvature method.
The T&D model proposed is a phase II initiative of the non-constant curvature trajectory model: the advanced spline curves [ASC] borehole trajectory model published at the 2016 IADC/SPE Drilling Conference and Exhibition (Abughaban el al. 2016). This modified three-dimensional [3D] T&D model [the ASC 3D T&D model] is a stiff-string model that includes geometric torsion, wellbore curvature, change in the rate of wellbore curvature and drillstring bending stiffness in the T&D equilibrium balance equations. The model has been validated using field cases with real-time forces that define T&D measured at the surface. The calculated outputs from these wells provide more accurate view of the drilling conditions downhole, including the downhole weight on bit and torque on bottom.
The novelty of the proposed model is the ability to estimate a more realistic bending effects, accurately predict the contact forces between the drillstring and the wellbore, and solve T&D parameters from surface to total depth in reasonable time using standard engineering computer. Accurately estimating these parameters will allow drilling engineers to update the driller with surface weight on bit and torque parameters to improve the drilling performance without taking undue risks with the drilling system such as stuck pipe, casing and drillpipe wear and drillstring fatigue. Thus, the ASC 3D T&D model is not only an alternative approach to accurately model downhole T&D parameters to be used in real-time operation centers [RTOC]; it can also serve as a step toward drilling automation.
Permeability Study of API Class G and B Cements Considering Seawater and WBM Contamination
Authors: Le-Minous Jean Christophe , Mutti Didier , Bouvet Alexandre , Unanue-Rodriguez Iker , Chang Andy , Massie Iain , Xiao Erin , Schnell Ernst 
Published: March 2017

Abstract
In preparation for decommissioning work in the Southern North Sea sector, the permeability of historically used cement systems was investigated to help determine their effectiveness as well barriers. Because the placement of cement typically involves some degree of contamination with other wellbore fluids, determining the influence of seawater and water-based drilling fluid (WBM) contamination on the permeability of the set cement was of particular interest.
This study investigates the historically used API Class G cement at 16 lbm/gal and Class B cement at 15.8 lbm/gal using contemporary material samples.
Cores were prepared using neat cement, cement contaminated with up to 50 vol% seawater, and cement contaminated with up to 50 vol% WBM. The permeability to nitrogen flow of the set cores was measured using a Hassler sleeve.
To further investigate the structural changes causing the higher permeability observed in the contaminated samples, the structure of the cores was imaged using X-ray computer tomography (CT) scans.
All Class B mixtures within the investigated contamination range, all Class G mixtures with seawater contamination, and Class G mixtures up to 30 vol% WBM contamination produced set cores after curing.
The neat Class G cores showed approximately twice the permeability of the Class B cement cores, with the contaminated slurries of both cement types showing much higher permeability—approximately one to two orders of magnitude greater.
Further analysis using the CT scans revealed irregularities in the structure density in the contaminated samples, which might explain the increased permeability; however, further work is necessary to fully understand the mechanism causing this change. Understanding the potential effects of contamination on permeability and the structure could be useful for gaining insight into barrier performance of the cement sheath in circumstances where contamination is suspected.
Enhanced Formation Integrity Test FIT Interpretation and Decision Making Through Real-Time Downhole Pressure Measurements
Authors: Jebutu S. O. , Silbernagel M. , Dugas B. C. , Lamborn R. , Akimov O. 
Published: March 2017

Abstract
Acquiring accurate downhole pressure data for casing shoe test interpretation and real-time decision making is critical to the delivery of a safe, efficient, and cost-effective well. With modern logging-while-drilling (LWD) technology, pressure profiles from a formation integrity test (FIT) or leak-off test (LOT) can now be measured during wellbore pressurization, stored in the memory of the downhole tool, and transmitted in a compressed 60-point pressure versus-time data format via mud-pulse telemetry when circulation is re-established. This data are decoded and decompressed at the surface to provide a detailed downhole flow-off pressure profile. If a higher-resolution data set is required, a "zoom" function using the same telemetry loop can be affected over a selected (smaller) time interval to provide another 60 (enhanced) pressure points. The ability to transmit these data sets real-time, without a special downlink, saves rig time and ensures quality data as well as test objectives are attained before terminating the test.
FIT's are routinely carried out to determine the fracture gradient around the casing shoe (shoe strength), or the maximum pressure the wellbore can withstand with regard to the casing setting depth. The pressure profile can also provide an indication of the quality of the cement bond around the casing shoe. While picking an inflection point from the pressure-versus-time plot seems straightforward, there are a number of factors that can distort the FIT results and lead to interpretation difficulties, particularly when differentiating between cement problems and formation effects. Additionally, the effect of drilling fluid properties can induce inaccuracies in the interpretation of surface-collected data, often resulting in a higher pressure than the correct value. With the advent of data compression and high-speed telemetry technology, downhole pressure profiles can now be acquired with improved resolution. This enhanced data set is essential for robust FIT/LOT interpretation, the accuracy of which is critical for avoiding costly drilling problems. A Gulf of Mexico deepwater case history will be analyzed to display effective ways in which this emerging technology has been successfully implemented. This approach in downhole pressure measurements during FIT/LOT can provide on-demand, high-precision data sets for enhanced interpretation and real-time decision making.
Integrated and Longest Directional Casing While Drilling Mitigates Hole Problems and Improves Drilling Performance While Saving Drilling Time
Authors: Radhakrishnan Venkataramanan , Gonzalo Hevia Garcia , Borge Diego Barrero , Pickup Duncan Ian , Anggraini Fauzia Dwi , Kongoun Chortip 
Published: March 2017

Abstract
Directional Casing While Drilling (DCwD) with Steerable Motor or a Rotary Steerable System is an emerging technology with proven results in Casing While Drilling applications. DCWD has been successfully applied in wells in Asia, North Sea and Middle East using rotary steerable systems & PDMs, proving up its operational reliability. The technology has been implemented in Asia Pacific region as well overcoming several challenges. The project was successfully implemented in 2 back to back wells in Gulf of Thailand & being the first of its kind.
Since the DCWD is first of its kind in Gulf of Thailand and to the operator, a proper planning and detailing the procedures along with risk assessment is the key to the success of the project. The procedure, in addition to directional capabilities requires that the well meet the demands of anti-collision concerns within the torque and hydraulic operating parameters of the formation. The quest ot overcome the problems faced by the customer led the operator to choose the DCWD technology to deliver step changes in drilling performance while meeting company's strict operational and safety directives.
The Integration of the directional drilling segment along with DCWD team along with the operator and the drilling contractor resulted in achieving the following➢Longest 9 5/8 DCwD run world wide➢Highest angle achieved with DCwD run in the field➢Saved 2 days of drilling time compared conventional drilling➢Increase in on bottom ROP compared to offset wells.
Successful Deep Water Drilling MPD, Early Kick Detection and Performing Managed Pressure Cementing With CML Controlled Mud Level System in GOM and North Sea
Authors: Elahifar Behzad 
Published: March 2017

Abstract
Control mud level (CML) technology is a method to manipulate the mud level in the riser in order to control bottom hole pressure (BHP) and Equivalent Circulating Density (ECD). It is also a Dual Gradient Drilling (DGD) technology, designed for drilling post-BOP sections. The system uses a subsea pump installed on a modified riser joint (MRJ) to control mud level in the riser's annular space.
CML eliminates the effect of ECD and enables drilling with a close-to-constant BHP. This may impact well design by allowing more optimal placement of casing points. By eliminating circulating friction, flow rate can be increased in the horizontal section and in unstable formations, to clean the wellbore from cuttings.
CML is a valuable tool while drilling into formations with a high probability of losses, or the layers with a high risk of influx. This paper will show that a CML system detected kicks earlier than the rig crew and geo-service company sensors both in GOM and the North Sea. In addition, how quickly was the kick detected and the driller informed will also be examined. With the CML system, the sensitivity for kick detection was greatly improved as the effect of rig motion on surface volumes was eliminated.
It is also explained how the CML system can help drilling in weak zones, and also drill deeper by adjusting the mud level in the riser by using a subsea pump module (SPM) which is connected to the riser to control BHP. The system is not a part of the well control equipment and the mud is still the primary well barrier.
Successful managed pressure cementing (MPC) method is also covered in this paper. The system was used to manage downhole pressure for cementing operations to mitigate losses and ensure good cement integrity. With MPC offering precise control over the pressure, it is possible to keep the wellbore pressure profile inside the drilling pressure window during the cementing operation.
A Novel Rheological Hierarchy Optimization Methodology with Artificial Intelligence and Inverse Technique Improves Spacer Design
Authors: Xie Liangjun , Chen Zhongming , Chaudhary Saleem , Alegria Adriana Estela 
Published: March 2017

Abstract
The quality of zonal isolation and well integrity are two main objectives for a successful cementing job. These objectives require proper placement of cement in the annular depth interval of interest. Cement placement, in turn, is dependent on effective drilling mud removal. A spacer fluid is designed to aid displacement of the drilling fluid and to minimize cement contamination. It takes into consideration not only wettability tests and compatibility results between spacer/mud and spacer/cement, but also rheological properties to improve friction pressure hierarchy. The rheological properties vary depending on flow rate, polymer concentration, spacer density and temperature. Trial-and-error lab tests and re-designs are needed to establish a spacer to meet those requirements. To optimize the costly process, and to expedite the job design, it is necessary to propose a smart rheological hierarchy optimization methodology that can predict the spacer rheologies and polymer concentrations by leveraging information from known data.
In this paper, a novel rheological hierarchy optimization methodology with artificial intelligence and inverse technique is introduced to improve spacer design. First, sufficient existing rheological property data (FANN readings) as a function of spacer density, temperature and polymer concentration are used to train the machine learning algorithm. Second, depending on the selected mud and cement, density of the spacer and the bottom-hole temperature, the required spacer properties are predicted by the trained machine learning algorithm for each polymer concentration. Third, given the wanted rheological properties, the best solution can be found by the inverse optimization algorithm with the least- square error in the range of polymer concentration.
The proposed methodology is applied to a new class of spacer system, which is a premium, water-based spacer, designed to effectively displace the drilling fluid in the annulus. Hundreds of rheological properties are recorded with various combinations of density, temperature and polymer concentration. The data are used in training the nonlinear machine learning algorithm. In real cement-job design, with the required FANN readings of the spacer and FANN readings of mud and cement, the algorithm finds an optimized solution. The FANN readings predicted by the machine learning algorithm are compared in the inverse search step. The calculated polymer concentration and FANN readings are confirmed by laboratory tests with minor variations.
MPD Applicaton on ERD Well Offshore Venezuela – Managing Bottom Hole Pressure within Narrow Window in a Faulted Limestone Formation with an Static Underbalanced Drilling Fluid
Authors: Martinez Ricardo , Scotto Maurizio , Mendez Gerardo , Santaniello Filippo , Reda Mohammed , Rojas Freddy , Bustos Felipe , Tang Jose , Rojas Jimmy , Borges Sergio , Richards Dylan 
Published: March 2017

Abstract
This paper describes the use of the Managed Pressure Drilling technology in the largest offshore gas field in Latin American and the first offshore gas field to be brought to production in Venezuela.
Managed Pressure Drilling technology with the assistance of Continues Circulation System was successfully implemented in the drilling of an extended horizontal section across a fractured and faulted limestone reservoir in an offshore gas well in the Venezuela Perla field.
This paper presents the planning, operation and challenges faced while drilling across the reservoir and while running the production liner, how the severe losses were managed keeping the bottom hole pressure within a narrow mud window and preventing gas influxes with the assistance of the Automated MPD system
Managed Pressure Drilling (MPD) is a technology where well control is maintained during the drilling operation by using a constant bottomhole pressure through the application of a surface back pressure (SBP) with the utilization of MPD chokes and a Rotating Control Device (RCD). The accurate measurements of flow in/out are essential to the MPD system to provide early indication of well losses or gains with the use of mass flow meter to measure flow rate and mud density (Coriolis meter). The closed fluid system provides high resolution of mud density, flow rates and pressure with the ability to direct measure formation pressure at key places and fracture gradients without detaining the drilling operation.
The Perla field is located in the CARDON-IV block in waters of the Golf de Venezuela, 50 km offshore Peninsula Paraguana. Perla consists of one production platform with a total gas production 500 MMscfd dedicated for local consumption.
The objective reservoir is the lower carbonate at a depth of approximately 9000ft SS. The thickness of the reservoir is approximately 700ft. The anticipated production from each well is in the order of 80 MMCFD to 135 MMCFD with an initial condensate yield of 25-30 BC/MMCF.
In previous wells, severe lost circulations were encountered while drilling the Lower Carbonate Reservoir which has a formation pressure of 9.8 ppg at the top. Several LCM pills and eventually cement squeezes were required to control these losses. In some cases, major losses were encountered, resulting in early termination of the section. Losses of this magnitude are due to a fractured carbonate and the crossing of several faults along the open hole.