bluuebunny/crossref_metadata_2025_split huggingface dataset:
Soledad en el adulto mayor: implicaciones para el profesional de enfermería
Authors: Chaparro Díaz Lorena , Carreño Moreno Sonia , Arias-Rojas Mauricio 
Published: May 2019

Introducción: La soledad es una vivencia desfavorable, relacionada con la sensación de tristeza, que afecta la cotidianidad de la persona, el adulto mayor es más propenso a tener sentimientos de soledad debido a la falta de interacción con amigos, la enfermedad, la viudez o el deterioro cognitivo. El objetivo de este estudio fue integrar los hallazgos sobre la soledad en el adulto mayor e identificar los aspectos que influyen en la misma. Materiales y Métodos: Se realizó una revisión sistemática de alcance integrativo. La búsqueda de información se realizó en 9 bases de datos, durante el periodo 2007 al 2018, se incluyeron en la revisión 36 estudios. Resultados: De acuerdo con la información encontrada emergieron 4 temas: características de la soledad en el adulto mayor, causas de la soledad, consecuencias de la soledad y factores que disminuyen los sentimientos de soledad. Discusión: La literatura indica que la soledad se relaciona principalmente con el aislamiento social, debido a la falta de interacción con otras personas y el desapego familiar lo que genera baja calidad de vida y riesgo de padecer enfermedades crónicas, es por esta situación que los profesionales de la salud deben prestar atención a una valoración holística del adulto mayor. Conclusiones: Los estudios muestran que existen varios aspectos que influyen en el proceso de soledad del adulto mayor, así como las principales acciones que puede realizar el profesional de la salud para intervenir este fenómeno.Como citar este artículo: Chaparro LD, Carreño SM, Arias-Rojas M. Soledad en el adulto mayor: implicaciones para el profesional de enfermería. Rev Cuid. 2019; 10(2): e633. http://dx.doi.org/10.15649/cuidarte.v10i2.633
Exostosin 1/Exostosin 2–Associated Membranous Nephropathy
Authors: Sethi Sanjeev , Madden Benjamin J. , Debiec Hanna , Charlesworth M. Cristine , Gross LouAnn , Ravindran Aishwarya , Hummel Amber M. , Specks Ulrich , Fervenza Fernando C. , Ronco Pierre 
Published: May 2019

Significance Statement
In approximately 70%–80% of cases of primary membranous nephropathy (MN), phospholipase A2 receptor (PLA2R)/Thrombospondin Type-1 Domain–Containing 7A (THSD7A) and anti-PLA2R/THSD7A antibodies form immune complexes along the glomerular basement membrane (GBM) that characterize the condition. In other cases of primary MN and all secondary MN, the target antigen is unknown. Using proteomics and immunohistochemistry, the authors detected two proteins, exostosin 1 (EXT1) and exostosin 2 (EXT2), in the GBM of PLA2R-negative MN. EXT1 and EXT2 were absent in all cases of PLA2R-associated MN and controls. Clinical and biopsy findings showed features of autoimmune disease, including membranous lupus nephritis, in 81% of the 26 EXT1/EXT2-associated MN cases the authors identified. These findings suggest that EXT1/EXT2-associated MN represents a distinct subtype of MN, most commonly associated with autoimmune diseases (secondary MN).

Background
In membranous nephropathy (MN), which is characterized by deposition of immune complexes along the glomerular basement membrane (GBM), phospholipase A2 receptor (PLA2R) and thrombospondin type 1 domain–containing 7A are target antigens in approximately 70% and 1%–5% of cases of primary MN, respectively. In other cases of primary MN and in secondary MN, the target antigens are unknown.

Methods
We studied 224 cases of biopsy-proven PLA2R-negative MN and 102 controls (including 47 cases of PLA2R-associated MN) in pilot and discovery cohorts. We also evaluated 48 cases of PLA2R-negative presumed primary MN and lupus MN in a validation cohort. We used laser microdissection and mass spectrometry to identify new antigens, which were localized by immunohistochemistry.

Results
Mass spectrometry detected exostosin 1 (EXT1) and exostosin 2 (EXT2) in 21 cases of PLA2R-negative MN, but not in PLA2R-associated MN and control cases. Immunohistochemistry staining revealed bright granular GBM staining for EXT1 and EXT2. Clinical and biopsy findings showed features of autoimmune disease, including lupus, in 80.7% of the 26 EXT1/EXT2-associated MN cases we identified. In the validation cohort, we confirmed that EXT1/EXT2 staining was detected in pure class 5 lupus nephritis (eight of 18 patients) and in presumed primary MN associated with signs of autoimmunity (three of 16 patients); only one of the 14 cases of mixed class 5 and 3/4 lupus nephritis was positive for EXT1/EXT2. Tests in seven patients with EXT1/EXT2-associated MN found no circulating anti-exostosin antibodies.

Conclusions
A subset of MN is associated with accumulation of EXT1 and EXT2 in the GBM. Autoimmune disease is common in this group of patients.
A civil law aspect of the dual-use goods regime
Authors: Shcherbakov M. G. 
Published: May 2019

The paper analyzes the civil law regime of dual-use goods in the aspect of dual-use goods turnover. The author reveals the role of civil law rules as elements of the legal regime in the legal regulation of vertical and horizontal legal relations, as well as analyzes the process of transformation of civil law rules in the course of law enforcement. The author dwells on the main legal characteristics allowing to differentiate dual-use goods, namely: technical features, scope of application, availability of export control. In the paper, the author offers his own definition of the legal regime of dual-use goods. In addition, we identify such a feature of the regime of dual-use goods as dependance of the degree of turnover of dual-use goods upon external factors.The author concludes that the functional purpose of civil law rules in the legal regime has changed.In conclusion, a number of recommendations are proposed to improve efficiency of the legal regulation of foreign economic activity in the sphere of turnover of dual-use goods.
Hydrocarbon Reservoir Evaluation: a case study of Tymot field at southwestern offshore Niger Delta Oil Province, Nigeria
Authors: Nwaezeapu Victor Cypren , Tom Izediunor U. , David Ede T. A. , Vivian Oguadinma O. 
Published: May 2019

Abstract: Aim: This study presents the log analysis results of a log suite comprising gamma ray (GR), resistivity (LLD), neutron (PHIN), density (RHOB) logs and a 3D seismic interpretation of Tymot field located in the southwestern offshore of Niger delta. This study focuses essentially on reserves estimation of hydrocarbon bearing sands. Well data were used in the identification of reservoirs and determination of petrophysical parameters and hydrocarbon presence. Three horizons that corresponded to selected well tops were mapped after well-to-seismic tie. Structural depth maps were created from the mapped horizons. The structural style is dominated by widely spaced simple rollover anticline bounded by growth faults, and this includes down-to-basin faults, antithetic faults and synthetic faults. The petrophysical values – the porosity, net-to-gross, water saturation, hydrocarbon saturation that were calculated yielding an average porosity value of 0.23, water saturation of 0.32 and an average net-to-gross value of 0.62. Three horizons H1, H2 and H3 were mapped. The three horizons marked the tops of reservoir sands and provide the structures for hydrocarbon accumulation. Hydrocarbon in-place was estimated. The total hydrocarbon proven reserves for the mapped horizons H1, H2, and H3 were estimated to be 39.04MMBO of oil and 166.13BCF for sand E.
What Services Exist for LGBTQ Perpetrators of Intimate Partner Violence in Batterer Intervention Programs Across North America? A Qualitative Study
Authors: Cannon Clare E. B. 
Published: May 2019

ObjectiveThe purpose of this study was to determine available services for LGBTQ clients in domestic violence batterer intervention programs across North America and to ascertain which theoretical models informed these services.MethodData collected from the North American Survey of DomesticViolence Intervention Programs were analyzed using deductive and inductive coding. Using guidelines established by the American Association for Public Opinion Research, the response rate for mailings was 20% and for e-mails was 45%.ResultsRespondents indicated a range of approaches to LGBTQ clients from doing nothing specific to serving LGBTQ clients with one-on-one sessions.ConclusionsRecommendations include more LGBTQ facilitators, developing curricula that addresses homophobia, issues related to family of origin, and foster methods of outreach to the LGBTQ community to make those affected aware of treatment possibilities. Moreover, evidence suggests a disconnect between practitioners and researchers when it comes to defining and treating the problem of intimate partner violence in LGBTQ relationships.ImplicationsPractitioners should not only undergo cultural training and provide LGBTQ-specific curricula, but also engage how and why such social inequality exists and persists. Further implications for policy and treatment are discussed.
High Reliability Protector-Less Artificial Lift Technology for Electrical Submersible Pumps/Compressors
Authors: Chen Kuo-Chiang , Kulkarni Pandurang , McMullen Patrick , Biddick David , Nader Lukasz , Sellers Chris 
Published: May 2019

Abstract
The Electric Submersible Pumps (ESP) is an efficient artificial lift method for lifting liquids from wells. The topology of the typical ESP with a pump, protector, and a motor has been fixed for many decades. The protector plays a critical role in the ESP to ensure that the electrical motor can function in the downhole environment. However, the protector's failure-prone components limit the ESP's reliability. To take the reliability of the ESP to the next level, the best approach is to eliminate the protector and thus all the associated failure modes.
The new topology of the protector-less technology for downhole rotary machinery is enabled by several magnetic technology building blocks. To eliminate the protector from an artificial lift device, the motor section is completely hermetically sealed from the downhole fluids by an isolation can. A set of magnetic couplings transmits torque from the motor to the hydraulic section via magnetic forces through the isolation can to replace the solid shaft between the motor and pump in the case of the ESP. When there is no solid shaft to transmit torque, thus no shaft seal required to prevent downhole fluids from leaking into the motor, there is no need for a protector. The thrust and radial loads from the hydraulic section are supported by magnetic bearings, which completely levitate the shafts and prevent any physical contacts between the rotating and stationary parts.
The architecture and its associated magnetic building blocks of protector-less technology are engineered into the subsurface compressor to ensure its reliability at high speed. The subsurface compressor provides both suction effects to lower intake pressure near producing zones and boosting effects to increase discharge pressure downstream of the compressor. With the lower downhole pressures and higher wellhead pressures generated by the subsurface compressor in a gas well, the gas production and recoverable reserve will increase due to higher drawdown and lower abandonment pressures. In the meantime, more liquids will be carried uphole due to higher gas velocity in the wellbore, lower intake pressure, and higher discharge temperature. The gas production in the proof-of-concept field trials of a subsurface compressor increased by 12 to 58%.
The implementations of the protector-less technology and its associated magnetic technology building blocks into the subsurface compressor are discussed in detail. The successful implementation of the protector-less technology into subsurface compressor demonstrates the ease of applying protector-less technology to the ESP. With the advantages of reliability and the ease of implementation to ESPs, protector-less technology provides a solution to ESPs when their applications require high reliability.
Systematic Selection of Drill-In and Completion Fluids for Development of the Dvalin HT Gas Field
Authors: Czuprat Oliver , Dahle Bjørn Olav , Dehmel Ulf , Ritschel Robert , Storhaug Jens , Adrian Thomas , Patey Ian 
Published: May 2019

Abstract
For the development of the HPHT gas field Dvalin a completion scheme using standalone screens is planned. To secure maximum clean-up and productivity, even after long term suspension, comprehensive lab testing of specific properties from drilling and completion fluids at downhole conditions, e.g. optimum bridging, minimizing formation damage, thermal stability and mobility was carried out. Furthermore, compatibility with production screens and formation fluids were verified. Drill-in fluid systems were advertised by different vendors to be compatible under the given initial reservoir conditions. For the sake of efficiency, the systematic test program consisted of a sequence of four test phases, where only successful fluids went to the next phase. The most important parameters of the test program were long-term high temperature stability and related sand screen compatibility, a detailed rheology characterization as well as complementary formation damage and return permeability tests. Finally, the additive concentrations of the awarded fluid system were systematically optimized to yield the least completion- and formation damage and highest return permeability.
A Data Driven Management Strategy to Reduce the Environmental Impact of Upstream Production Plants
Authors: Cadei Luca , Loffreno Danilo , Camarda Giuseppe , Montini Marco , Rossi Gianmarco , Fier Piero , Lupica Davide , Corneo Andrea , Lancia Lorenzo , Milana Diletta , Carrettoni Marco , Purlalli Elisabetta , Carduccu Francesco , Sophia Gustavo 
Published: May 2019

Abstract
This paper highlights results of a first campaign of tests of an innovative tool to predict the short term trend of the energy efficiency index and the optimal management of an Oil&Gas production plant. The developed tool represents a step towards the Digital Transformation of the production plants by the integration of Big Data Analytics and Machine Learning methodologies with experts’ domain knowledge.
The predictive model has two main features: produces a forecast of the energy efficiency index 3 hours into the future and supports the site engineers to take optimal management choices by highlighting the energy performances of the most energy-intensive equipment of the plant. The operator can use this information to act on the plant and reduce the overall energy consumption.
The energy efficiency index is described by the Stationary Combustion CO2 Emission KPI [tCO2/kboe] that relates the consumed energy and the associated CO2 emission with the total production. A Gradient Boosting regression model is implemented and fed with a mix of autoregressive and exogenous real-time parameters.
The paper shows the results obtained through a series of actions taken by production engineer, using the model's outputs on a real operating oilfield. The methodology entails a real-time run of the model to analyze the Stationary Combustion CO2 Emission Index trend, identifying a subset of equipment with abnormal/atypical consumption. This activity is followed by a monitoring phase, where such subset of equipment is further analyzed in terms of energy consumption and main process parameter. The purpose of this phase is to identify a relevant set of actions. The final step requires interaction with the control room to act on the equipment operative parameters. Preliminary tests show the daily average CO2 emission from stationary combustion were reduced by 0,9%, with a peak reduction of 1,35%.
The main advantages experimented by the first implementation tests are related to the significant reduction of CO2 emissions while granting the highest level of production, allowing a step towards the field carbon neutrality target.
AICD Implementation on Oseberg H Vestflanken 2
Authors: Lien Andreas , Midttveit Øyvind , Johnsen Gyllensten Atle , Halvorsen Martin 
Published: May 2019

Abstract
Vestflanken 2 (VF2) is an ongoing field development project in the Oseberg area. The development concept chosen includes an unmanned wellhead platform (Oseberg H) with seven gas lifted production wells, two gas injection wells in addition to two sub-sea production wells using existing infrastructure. Four of the production wells will be multi-laterals completed with autonomous inflow control devices (AICDs). AICDs in VF2 wells have two main objectives: Accelerate oil production by delaying gas breakthroughChoke back gas after gas breakthrough
AICDs have been successfully implemented at the Troll field, and further implementation on other fields are pursued. There are differences between fields and careful considerations must be taken when implementing the technology on a new field development like VF2. It is essential to select a type and size of the AICD that fit the application. This paper discusses the process of selecting the AICD flow capacity. The lower completion design was based on experiences and results from inflow simulations. However, the design for future wells will be made based on production experience from the first VF2 wells in production.
This paper also discusses the clean-up and start-up of the first VF2 well and presentation of results. The well is well instrumented with downhole P/T gauge and multi phase flow meter on well head. This is the operators first AICD well equipped with multi phase meter which makes it a very good candidate for evaluating flow performance and AICD efficiency. The well was started October 2018. Step-rate tests were performed on both branches and on the comingled MLT production. This allowed to compare measured data from the multi-phase meter to results obtained by the simulation model. The simulation results matched the measured data to a varying degree with different model assumptions. The initial well performance data and simulation model will be valuable tools when evaluating AICD design for future wells.
Innovative and Established LCM Cementing Solutions Combined to Create Novel LCM Cementing Fluid Train
Authors: Olsen Maximillian , Lende Gunnar , Rehman Khahlil , Haugum Per , Mo Jakob , Smaaskjar Geir , Næss Randi 
Published: May 2019

Abstract
Losses to the formation when drilling can lead to non-productive time (NPT), altering the wellbore construction due to unplanned casing points, and well control incidents due to the loss of overbalance pressure. The karstified and fractured carbonate reservoir formations sometimes encountered in the Barents Sea represent a high lost circulation risk. The large vugs (or caves) in these formations can be as large as 50 cm in diameter and cause severe to total losses while drilling. Dynamic loss rates are typically in the range of 30-60 m3/hr and can be greater. A unique lost circulation mitigation (LCM) solution is required for these conditions. An operator which plans to drill through this type of formation is wise to plan effective LCM solutions in order to rapidly cure any losses.
The presented method is setting a reactive cementing fluid train downhole that creates an effective blockage in the loss zone. The cementing fluid train is composed of three fluids: sodium silicate, calcium chloride, and an innovative thixotropic and low compressive strength cement slurry designed to rapidly cure loss zones. When the first two fluids come into contact, they instantly form a viscous slush-like precipitate of calcium silicate. The fluid train is designed so the ‘slush’ forms inside the loss zone and creates a base for the cement following behind, allowing the cement to set up inside the loss zone. Together these fluids create the ideal LCM solution to large vugs and cavernous zones.
The fluids are pumped through the drill string and the bottom hole assembly after it has been pulled above the loss zone. After the fluids are pumped, a short wait on cement time allows the operator to drill ahead through the cement and continue with the planned well path.
The content presents a description of the procedures and successful results from two operations performed in the Barents Sea. The operator cured the loss rate to the necessary level to continue drilling, negating the need for a sidetrack. Furthermore, multiple LCM solutions had failed prior to pumping this fluid train, proving the effectiveness of the solution.
Drilling Fluid Power-Law Viscosity Model - Impact of Model Parameters on Frictional Pressure Loss Uncertainty
Authors: Riisøen Solveig , Iversen Fionn , Brasileiro Raoni , Saasen Arild , Khalifeh Mahmoud 
Published: May 2019

Abstract
The estimated frictional pressure loss of fluid flow in a pipe is highly dependent on the rheological properties of the fluid. The applied curve fitting method of the viscosity curve will impact the accuracy of the modelled frictional pressure loss. This study evaluates a new approach for application of the power law model previously presented by Saasen and Ytrehus (2018), using dimensionless shear rates, allowing for simpler comparison between fluid characteristics.
The modelling approach is based on selecting an appropriate characteristic shear rate for the flow, replacing the consistency index. The curvature exponent is subsequently fitted to the shear rate region of interest. The applied test fluid is Poly-Anionic Cellulose (PAC) in aqueous solutions. Apparent viscosity measurements have been performed using a high precision rheometer (Anton Paar MCR 302) keeping the temperature constant at 20˚C.
A method for evaluating the accuracy of estimated frictional pressure loss when using the new model of Saasen and Ytrehus is presented. The uncertainty evaluation of the derived model coefficients is based on the estimated probability distribution of the apparent viscosity measurements and error in the model parameter estimation. This uncertainty is further propagated in the estimated frictional pressure loss for evaluation of total modelling accuracy. The new simplified model is more robust and reduces the need for iterative calculations. It has the advantages of simplifying digitalization of the drilling process, being easier and quicker to curve fit at the rig and making it easier to compare different fluids.
Considering the uncertainties related to the rheological properties of the fluid and the impact on the frictional pressure loss is highly applicable when evaluating non-Newtonian fluid flow in pipes. This increased understanding of the uncertainties related to the modelled frictional pressure is also essential information when automating the drilling process.