bluuebunny/crossref_metadata_2025_split huggingface dataset:
Translation and Psychometric Properties of the Chinese Version of the Perceived Workplace Environment Scale in Taiwanese Information Technology Professionals
Authors: Lin Yun‐Ping , Kao Tsui‐Sui Annie , Mccullagh Marjorie C. , Edington Dee W. , Larson Janet L. 
Published: April 2012

Translation and Psychometric Properties of the Chinese Version of the Perceived Workplace Environment Scale in Taiwanese Information Technology Professionals: Yun‐Ping LIN, et al. School of Nursing, University of Michigan, USA—BackgroundThe six‐item Perceived Workplace Environment Scale (PWES) is a self‐report instrument designed to measure employees' perceptions of the extent to which their workplace environment supports employee physical activity. A Chinese version is needed to facilitate workplace physical activity research in Chinese speaking countries.ObjectivesThis paper describes the translation process and the psychometric properties of the newly translated Chinese version of the PWES (PWES‐C).MethodsThe PWES in English was translated into Chinese using a modified committee approach with the consideration of cross‐cultural equivalence. Psychometric properties were examined by a cross‐sectional survey of 466 male and 109 female Taiwanese information technology (IT) professionals from three IT companies in northern Taiwan.ResultsContent validity of the newly translated PWES‐C was supported by a panel of experts. Internal consistency reliability was high (Cronbach's alpha=0.88), and no significant ceiling and floor effects were observed for the PWES‐C. Construct validity was supported by examining the factor structure of the PWES‐C using a confirmatory factor analysis, and the results suggest a single‐factor structure.ConclusionsThe PWES‐C is a reliable and valid measure of perceived workplace physical activity environments in Taiwanese IT professionals. The scale could be used by employers to document employees' perception of the workplace environment.
Work‐family Conflict and Burnout among Chinese Doctors: The Mediating Role of Psychological Capital
Authors: Wang Yang , Liu Li , Wang Jiana , Wang Lie 
Published: April 2012

Work‐family Conflict and Burnout among Chinese Doctors: The Mediating Role of Psychological Capital: Yang WANG, et al. Department of Social Medicine, School of Public Health, China Medical University, P.R. China—ObjectivesThe aim of this study was to investigate the relation between work‐family conflict and burnout, and the mediating role of psychological capital (PsyCap) in the relation between work‐family conflict and burnout, among Chinese doctors.MethodsThis cross‐sectional study was performed during the period of September/October 2010. A questionnaire that comprised work‐family conflict assessed by the work‐family conflict scale, PsyCap assessed by the PCQ‐24 scale and burnout assessed by the Maslach Burnout Inventory‐General Survey (MBI‐GS), as well as age and gender, was distributed to 1,300 doctors in Liaoning Province, China. A total of 1,011 effective respondents became our final study subjects. Hierarchical linear regression analyses were performed by using SPSS 17.0 to explore the mediating role of PsyCap in the relation between work‐family conflict and burnout.ResultsBoth work interfering family conflict (WIF) and family interfering work conflict (FIW) were positively related with emotional exhaustion and cynicism among both male and females doctors. However, WIF was positively related with professional efficacy only among male doctors, whereas FIW was negatively related with professional efficacy among both male and female doctors. PsyCap partially mediated the relation between WIF and professional efficacy among male doctors and partially mediated the relations of FIW with emotional exhaustion, cynicism and professional efficacy among female doctors.ConclusionsWork‐family conflict was associated with burnout among Chinese doctors. PsyCap was a mediator between work‐family conflict and burnout. PsyCap might be a positive resource to reduce the negative effect of work‐family conflict on burnout of doctors, especially female doctors, in China.
From Operations to Desktop Analysis to Field Implementation: Well and ESP Optimization for Production Enhancement in the Cliff Head Field
Authors: Dholkawala Z.F.. F. , Daniel S.. , Billingsley B.. 
Published: April 2012

Summary
Understanding the integrated performance of complex artificially lifted wells on not normally manned (NNM), offshore platforms without invasive techniques represents a challenge not only to minimizing operating costs but also to optimizing production and thereby maximizing value. Often the analysis of such problems is hindered by the complex interactions between identified production constraints and by a lack of operating data.
The Cliff Head oil field (offshore Western Australia) is developed with an innovative coiled-tubing deployed-electrical-submersible-pump (CT-ESP) artificial-lift system. This paper describes the process by which ESP and well data, in conjunction with a well-performance-modeling software, have been used as a powerful tool to diagnose well-performance issues and optimize production. Production trends were created on the basis of real-time production data to understand ESP performance. Individual-well models were created to identify potential causes of declining performance—in this case, the use of an ESP performance-limiting factor (PLF) indicating deteriorating ESP performance because of solids buildup.
On the basis of the model results, chemical soaks were implemented on two production wells to remove flow restrictions within and around the ESPs. The treatments increased the oil-production rates by 17 to 48%.
Following a debottlenecking study, reservoir simulation in combination with detailed ESP-performance analysis concluded that total-field-production improvements of up to 50% were possible. Consequently, the next phase of field development will install larger-capacity ESPs.
This paper outlines how field data and desktop tools were combined successfully to monitor and diagnose well-performance issues to deliver material production enhancements.
Mobility Ratio - Its Influence on Flood Patterns During Water Encroachment
Authors: Aronofsky J.S. 
Published: April 2012

Abstract
The results of potentiometric model studies and numerical computations are described. The purpose of these studies was to determine the influence of the mobility ratio on flooding efficiencies during water encroachment in petroleum reservoirs, in systems of regular well geometry.
The direct line drive well pattern having relative spacing distances of one and one-half to one was investigated for water to oil mobility ratios of 10, 1, and 0.1. The results of these studies indicate that the pattern sweep efficiency is very dependent upon the mobility ratio.

Introduction
The almost universal occurrence of water in the immediate neighborhood of oil-bearing sands lends considerable emphasis to the desirability of having a rational analysis of water encroachment into petroleum reservoirs. This problem has become increasingly important with the accelerated use of water injection for secondary recovery operations.
The water encroachment problem has been studied from both the theoretical and experimental viewpoints by Muskat. He has formulated, in a precise manner, differential equations to express flow in a water encroachment system, and rigorous analytical solutions have been developed for the linear, radial, and spherical cases. However, it becomes exceedingly difficult to solve the encroachment problem rigorously for any general two-dimensional system in which the shape of the two-fluid interface is not immediately evident from the geometry of the system. The difficulty lies in the fact that a rigorous analytical solution requires that the shape of the two-fluid interface be known simultaneously with its instantaneous position and with the pressure distribution on both sides of the interface.
Although this paper concerns the study of the two-fluid system of oil and water, the methods described in the paper are generally applicable to other systems of incompressible and immiscible fluids in which the displacing fluid sweeps the displaced fluid down to a residual value. In each region it is assumed there is only one mobile fluid and its mobility is constant throughout the region. The same procedure, with minor alterations, is applicable for gas injection systems provided the assumption can be made that both the displaced and displacing gases can be described by steady state formulas.
Reservoir Modeling: From RESCUE To RESQML
Authors: King Michael J. , Ballin Paulo , Bennis Chakib , Heath David , Hiebert Allan , McKenzie William , Rainaud Jean-Francois , Schey Jana 
Published: April 2012

Summary
The RESCUE consortium formed in 1995 in response to the requirement to transfer the structural framework, 3D gridded models, and associated well data from "geomodels to upscalers." RESCUE developed a data standard and libraries that allowed multiple vendors to support subsurface projects across the geoscience and engineering domains. To date, more than 20 of the sponsoring petroleum companies and application vendors have integrated RESCUE into their applications.
In late 2008, the consortium began a transition to a much more flexible standard: RESQML™. RESQML joins with WITSML™ and PRODML™ as the latest XML-based data-transfer standards managed by Energistics. The V1.0 developer's release of the RESQML data standard was published in December 2010, followed by a fully commercial V1.1 release in October 2011. We expect vendor applications using RESQML V1.1 to be available commercially in 2012.
RESQML has been designed to support
Interaction with real-time production and drilling domains Transfer of gigacell reservoir-simulation models, as are currently in use in some areas of the world, together with static reservoir models, which may be several orders of magnitude larger Lossless data transfer for complex grids, especially for nonstandard connectivity Retention of the geologic and geophysical meta-data associated with 3D grids Data standards to support flexible and iterative multivendor subsurface workflows across geology, geophysics, and engineering As an example of the latter, workflows that support fault-seal analysis or 4D-seismic interpretation benefit greatly from the integration of data, metadata, and interpretations from multiple geophysical, geologic, and engineering applications into a coherent subsurface model. Such integration is not possible for a single application or vendor.
In this paper, we will present our objectives, challenges, and work plan for 3D/4D-reservoir-model exchange. Details of the technical design defined by participating petroleum oil companies and software vendors will be shared to demonstrate the efficiency of the RESQML standard.
Method for Determining Wettability of Reservoir Rocks
Authors: Slobod R.L. , Blum H.A. 
Published: April 2012

Abstract
A semiquantitative method for measuring the wettability of reservoir rocks has been developed. These data are needed for reservoir analysis and for interpretation of laboratory displacement studies. The wettability of a core sample is measured by the contact angle for the system oil-water-solid. These contact angles are calculated from the displacement pressure (threshold pressure) obtained by use of the centrifuge, using first oil-water and second air-oil in the same core sample. This method is based on the assumption that the air-oil and oil-water interfaces occupy similar positions in the porous medium when desaturation of the wetting phase is initiated. The assumption is also made that the contact angle for the air-oil-solid system which is close to zero in value does not change appreciably even when the contact angle for the oil-water-solid system experiences marked changes. "Apparent contact angles" for five different solids ranging from 31? to 82? have been determined, and changes in the "apparent contact angle" of a given sample with laboratory use from 33? to 53? have been observed.

Introduction
Reservoir rocks vary in their wettability, some being preferentially water wet while other are apparently preferentially oil wet. The degree of wettability, in theory, is measured quantitatively by the contact angle for the system solid-oil-water, but in practice this quantity is extremely difficult to determine. The need for obtaining some measure of this quantity has become obvious in recent years as a result of both laboratory and field observations. Several reservoirs such as the Bradford Sand in Pennsylvania and the Wilcox at Oklahoma City are reported to be oil wet. If these reports correctly reflect the true nature of the surface of the rock in the ground, then these reservoirs probably will not perform as predicted on the basis of a water wet rock.
Sequential Coupling of Geochemical Reactions With Reservoir Simulations for Waterflood and EOR Studies
Authors: Wei Lingli 
Published: April 2012

Summary
Many waterflood projects now experience significant amounts of water cut, with more water than hydrocarbon flowing between the injectors and producers. In addition to the impact on water viscosity and density that results from using different injection-water sources during a field's life, water chemistry itself may impact oil recovery, as demonstrated by recent research on low-salinity water-injection schemes. It is also known that water chemistry has a profound impact on various chemical enhanced-oil-recovery (EOR) processes. Moreover, the effectiveness and viability of such EOR schemes is strongly dependent on reservoir-brine and injection-water compositions. In particular, the presence of divalent cations such as Ca+2 and Mg+2 has a significantly adverse effect for chemical EORs. Using new developments in reservoir simulation, this paper outlines a method to couple geochemical reactions in a reservoir simulator in black-oil and compositional modes suitable for large-scale reservoir models for waterflood and EOR studies. The new multicomponent reactive-transport modeling capability considers chemical reactions triggered by injection water and/or injected reactive gases such as CO2 and H2S, including mineral dissolution and precipitation, cation exchange, and surface complexation.
For waterflood-performance assessment, the new modeling capability makes possible a more-optimum evaluation of petrophysical logs for well intervals where injection-water invasion is suspected. By modeling transport of individual species in the aqueous phase from injectors to producers, reservoir characterization can also be improved through the use of these natural tracers, provided that the compositions of the actual produced water are used in the history matching. The simulated water compositions in producers can also be used by production chemists to assess scaling and corrosion risks. For CO2 EOR studies, we illustrate chemical changes inside a reservoir and in the produced water before and after CO2 breakthrough, and discuss geochemical monitoring as a potential surveillance tool. Alkaline-flood-induced water chemical changes and calcite precipitation are also presented to illustrate applicability for chemical EOR with the new simulation capability.
HCl/Formic In-Situ-Gelled Acids as Diverting Agents for Carbonate Acidizing
Authors: Rabie Ahmed I. , Gomaa Ahmed M. , Nasr-El-Din Hisham A. 
Published: April 2012

Summary
In highly heterogeneous carbonate reservoirs, several acid systems have been used to enhance acid diversion during matrix acidizing such as surfactant-based acids and in-situ-gelled acids. In-situ-gelled acids are also used to reduce leakoff rate in acid fracturing. The main acid used in this system is hydrochloric acid (HCl). However, high reaction rates and severity of corrosion problems, especially for wells completed with Cr-based tubulars, limit the use of HCl at high temperatures. On the other hand, mixing organic acids with HCl either increases the acid penetration or reduces the necessary strength of HCl and the necessary load of the corrosion inhibitors. A few studies addressed the systems that use both advantages.
The objective of this work is to investigate the behavior and the performance of different in-situ-gelled HCl/formic acid blends as diverting agents by conducting viscosity measurements, reaction-rate measurements using the rotating-disk apparatus, and through coreflood study.
Formic acid was blended with HCl, and four in-situ-gelled acids were examined. Formic acid concentration varied from 0 to 6.31 wt%, and HCl concentration ranged from 0 to 5 wt%. Pink Desert limestone was used for reaction-rate and coreflood experiments. The rotating-disk apparatus was used to measure the reaction rate at 250°F at disk rotational speeds of 100 and 1,000 rev/min. The effect of formic acid concentration and zirconium crosslinking on the reaction rate was examined. Coreflood experiments were conducted at 250°F using two different rates of injection (2 and 10 cm3/min), and the core samples were imaged using a computed-tomography (CT) scan technique after each coreflood experiment.
Increasing formic acid concentration decreased the reaction rate of in-situ-gelled HCl/formic acid with calcite at both low and high disk rotational speeds. This was confirmed by viscosity measurements, which showed that increasing formic acid concentration increased the viscosity of the live acids and decreased the viscosity of the spent acids. Coreflood results showed that increasing formic acid concentration in HCl/formic acid blends reduced acid ability for diversion. In the selected range of acid concentration and for the type of polymer and crosslinking agent used, the in-situ HCl/formic acid behaved more like gelled acid and reached a breakthrough in all coreflood experiments. The higher the formic acid concentration, the higher the pore volume of the acid required to break through.
First Downhole Application of Distributed Acoustic Sensing for Hydraulic-Fracturing Monitoring and Diagnostics
Authors: Molenaar M. M. , Hill D. J. , Webster P. , Fidan E. , Birch B. 
Published: April 2012

Summary
The first exploration-and-production downhole field trial of distributed acoustic sensing (DAS) fiber-optic technology was conducted during the completion of a tight gas well in February 2009.
DAS is a novel technology that allows the detection, discrimination, and location of acoustic events on a standard telecom single-mode fiber several kilometers long. Using a combination of the measurement of backscattered light and advanced signal processing, the DAS interrogator system segregates the fiber into an array of individual microphones. To date, the technology has been applied mainly in the defense and security industries. One of the most exciting applications for downhole application of DAS is in the area of hydraulic fracturing of tight-sand and shale-gas reservoirs. Balancing the cost of hydraulic-fracture stimulation with the production benefit is crucial in tight-sand and shale-gas developments because, after drilling costs, the completion is the largest single cost component of the well.
Recordings can be made while tools are run in hole, bridge plugs are set and perforations are shot and during the fracture-stimulation treatment. The technology is sufficiently reliable and sensitive to detect and monitor these in-well activities. The fidelity of the recordings made during hydraulic-fracturing and flowback operations provides a step-change improvement in the ability to perform real-time and post-job diagnostics and analyses of the stimulation.
The different case studies presented in this paper will illustrate how, even in its earliest form, DAS has the potential to enhance the capability of monitoring and understanding in-wellbore activities. The technology enables the optimization of hydraulic-fracturing design and execution, which can drive down completion costs and lead to increased well productivity and ultimate recovery.
Development of a Continuous Directional Coring System for Deep-Sea Drilling
Authors: Shinmoto Y.. , Miyazaki E.. , Wada K.. , Yamao M.. 
Published: April 2012

Summary
Core sampling is one of most important methods for gaining knowledge on formation properties below the seafloor or for extracting such potential new energy resources as methane hydrates. The riser-equipped deep-sea drilling vessel Chikyu carries out scientific expeditions for such underwater formation core drilling to analyze the origin of hydrate generation near the coast of Japan. Among the various systems available, continuous coring using wireline is the most promising for obtaining a steady supply of core samples.
Although measuring-while-drilling/logging-while-drilling (MWD/ LWD) methods are deployed, an advanced directional control system specifically for deep-sea coring is currently under technical development. Core barrels consisting of the inner and outer barrels have been designed with an inner barrel that is retrievable and resettable. The new method combines an adjustable bent-housing sub that is located between the outer barrel and just above the inner core tube.
Laboratory tests in which the inner barrel is passed through the bent housing section have been performed, with results showing bent housing angles of 0.25-2.0°. Land drilling tests with the bent housing were also performed in order to ensure drilling efficiency and core recovery. This paper presents the progress of our newly developed coring system with an integrated analysis of directional-drilling and coring capabilities.
Effect of Alkalinity on Oil Recovery During Polymer Floods in Sandstone
Authors: Kazempour Mahdi , Sundstrom Eric , Alvarado Vladimir 
Published: April 2012

Summary
Alkaline flooding has been purported to be a promising process for enhancing heavy-oil recovery, while alkaline/polymer (AP) and alkaline/surfactant/polymer (ASP) injection represent commercial flooding strategies for lighter oils. The alkali in an ASP flood can reduce adsorption of surfactants and react with acids in the oil to form soaps. Polymers increase the viscosity of water and control mobility ratio. The addition of an alkali to a straight polymer flood can further increase the efficiency in polymer flooding. The alkali can react with the rock and polymer to reduce polymer adsorption and decrease polymer-solution viscosity to allow higher injectivity.
We report results of core experiments for polymer, alkali, and AP tertiary floods. The conditions tested correspond to Wyoming's Minnelusa sandstone reservoirs. Berea cores were waterflooded to residual-oil saturation, and then a tertiary injection of a polymer, alkali, or AP solution was run, followed by waterflooding. We also show results of polymer-solution viscosity with varying alkali concentration. Polymer-adsorption results from dynamic and static experiments with and without alkali are reported. Numerical history match of coreflooding results was performed using CMG-STARS.
Results show that a tertiary alkali injection produces negligible oil recovery and pressure-drop increase. Straight polymer injection produces considerable oil recovery with a significant increase in pressure drop that may not be favorable for field designs. The injection of the AP solution also produced considerable oil recovery, but the increase in pressure drop was less than that of the straight polymer flood. The effects of alkali on polymer and rock surface lead to a significant impact on recovery factor, resistance factors, and also residual resistance factors.
Results of this study demonstrate one of the benefits of adding alkalis in polymer flooding—namely, the improvement in injectivity—in addition to the known reduction in polymer losses because of adsorption on the rock surface. The modeling strategy should help with alkali-enhanced polymer-flooding designs.