bluuebunny/crossref_metadata_2025_split huggingface dataset:
Does lidocaine gel produce an effective analgesia prior to copper IUD insertion? Randomized clinical trial
Authors: Abbas Ahmed M. , Ragab Ebtehal , Ali Shymaa S. , Shady Nahla W. , Sallam Hany F. , Sabra Ali M. 
Published: February 2018

Background: IUD is a small contraceptive device, often containing either copper or levonorgestrel, which is inserted into the uterus. Objective of present study was to determine if lidocaine gel prior to intrauterine device (IUD) insertion decreases pain with the insertion procedure among multiparous women choosing the copper T380A-IUD.Methods: It is a randomized double-blind controlled trial carried out at Assiut Women's Health Hospital, Assiut, Egypt. Parous women eligible for Copper IUD insertion attended the Family Planning Clinic were recruited and randomized in a 1:1 ratio to lidocaine gel or placebo. Two ml of the study medications were topically placed on the cervix 3 minutes before IUD insertion. The primary outcome was the difference in pain scores using a 10-cm Visual Analogue Scale (VAS) during IUD insertion. We considered a 1.5 cm difference in VAS scores between study groups as clinically significant.Results: One hundred women consented to participate and randomized either to group I: lidocaine group or group II: placebo group. Both groups were homogenous in baseline socio-demographic data. There was significant difference in mean pain scores for IUD placement between women who received lidocaine gel and placebo at two steps of insertion (at vulsellum application and at uterine sounding) while the rest of steps show no statistical significant difference (p=0.000). There were no statistical significant differences between both group as regard the ease of insertion, the duration of insertion and the satisfaction score after the procedure (p>0.05).Conclusions: This study depicts that the use of lidocaine gel prior to copper IUD insertion in multiparous women could partially reduce the pain during tenaculum placement and uterine sounding.
Diagnosing genital tuberculosis in female infertility by clinical, histopathological, culture and polymerase chain reaction techniques: an evaluative study
Authors: Thangappah Radha B. P. , Narayanan Sujatha 
Published: February 2018

Background: In developing countries, the genital tract tuberculosis is one of the common causes of tubal damage leading to infertility. Objective of present study was to evaluate the efficacy of Histopathological examination (HPE), culture and Polymerase Chain Reaction Technique in diagnosing genital tuberculosis.Methods: It was a prospective evaluative study. 173 women were subjected to investigations for tuberculosis. AFB smear, culture and HPE examination and PCR testing were carried out on 173 endometrial samples, 81 POD fluid and 52 urine samples. Based on the clinical profile and laparoscopic findings a diagnostic criterion was derived to suspect GTB and the specific diagnostic tests were evaluated against this diagnostic criterion.Results: Based on the diagnostic criteria, tuberculosis was suspected in 61 of the 153 cases. AFB smear was positive in 4.6%, culture was positive in 3.5%, HPE positive in 4.0% and PCR was positive in 28.1% of cases. On evaluating against the diagnostic criteria, the sensitivity of PCR, HPE, culture and AFB smear were; 44.3%, 8.2%, 6.6% and 6.7% respectively. PCR was positive in 18 of the 92 cases in whom GTB was not suspected. The PCR results were negative in 34 of the 61 clinically suspected cases.Conclusions: This study has shown that HPE, AFB smear and culture have low pick up rates. PCR is found to be useful in confirming diagnosis in clinically suspected cases. False negative PCR was an important limitation in this study.
La grammaire: sa place dans l’enseignement-apprentissage des langues et sa demarche
Authors: López Sosa Carmen Diosa , Fonseca Ayala Misael 
Published: February 2018

Pendant les dernières années, il y a eu quelques discussions par rapport à la grammaire en tant qu’outil important lequel ne doit pas être oublié ou rejeté dans les cours de langue étrangère. C’est ainsi qu’aujourd’hui, on parle de la différence qui existe entre apprentissage grammaticale et apprentissage grammaticalisé. Le premier fait référence à la méthode traditionnelle de l’apprentissage d’une langue qui consiste à apprendre des règles par cœur pour construire des phrases correctes, dans cette optique l’apprenant est au service de la grammaire. De nos jours, avec le travail mené à bien par le Cadre Commun de Référence pour les langues, on a une autre idée de ce que c’est la grammaire et son enseignement car cette composante grammaticale est au service de ce qui apprend la langue. De là, que les processus d’enseignement de la langue changent aussi les perspectives et mettent en avant les besoins des apprenants pour satisfaire les goûts et les façons d’acquérir les connaissances.
Development and Examination of Personal and Social Responsibility Behaviors Scale
Authors: FİLİZ Bijen , DEMİRHAN Gıyasettin 
Published: February 2018

In
this study, “Personal and Social Responsibility Behaviors Scale (PSRB-S)” was
developed in order to determine students’ responsibility behaviors in
accordance with “Personal and Social Responsibility” model developed by Don
Hellison and students’ personal and social responsibility levels were examined
in terms of gender, age and years of sport practice
through this scale. Pertaining to personal and social dimension of responsibility,
four-category Likert type trial scale consisting of 52 items and Exploratory
Factor Analysis (EFA) were applied to 330 high-school students. Items that did
not apply as a result of the analysis were omitted from 52-item trial scale and
the scale was reduced to 14 items. A final scale consisting of two factors was
created. Obtained scale was applied to different 250 high-school students for
Confirmatory Factor Analysis (CFA). It has been determined that EFA and CFA
results of two-factor PSRB-S and reliability and validity of internal
consistency coefficients are at an acceptable level. It was not detected a
significance difference in total scores of athlete students’ responsibility
behaviors in terms of gender and age variables
while there were significant difference in their total scores of years of sport
practice.
Viability of EOR Processes in the Bakken Under Geological and Economic Uncertainty
Authors: Joslin K. , Abraham A. M. , Thaker T. , Pathak V. , Kumar A. 
Published: February 2018

Abstract
For tight oil reservoirs, primary depletion using multistage hydraulically fractured horizontal wells typically only recovers between 5 to 15% of original oil in place, and can exhibit an exponential decline in production rates within a few months. Various enhanced recovery techniques exist, which offer great potential to increase the recovery in conventional reservoirs, however their feasibility within tight formations is not proven. This paper investigates the applicability of several different recovery techniques using a simulation-integrated workflow to both optimize the hydraulic fracture and well configuration design, and determine under which conditions these EOR methods are feasible.
In addition to natural depletion, the EOR techniques investigated included immiscible and miscible gas flood and a cyclic Huff n Puff process. Using a simulation model representative of the Elm Coulee reservoir in the Bakken formation, a net present value optimization was performed with comprehensive economic analysis. Optimal operating constraints, fracture design and well configurations were found for each of the techniques investigated. Upon completion of the optimization, each optimal case was subjected to a sensitivity analysis on geological and economic parameters which cover the expected range of the Middle Bakken formation within the Elm Coulee region. Based on this uncertainty, a greater confidence can be achieved in each of the techniques as well as their versatility.
From the simulation study, it was discovered that the optimal configuration was different for each of the recovery techniques evaluated. For natural depletion and immiscible flooding, the optimal well spacing was 400m combined with the largest fracture spacing of 125m. Conversely, the miscible flooding method achieved optimal NPV values at the closest well spacing. The cyclic process, which used CO2 for the injected fluid, produced its optimal NPV at a closer fracture spacing when compared to the other 3 methods. Additionally, the Huff n Puff process required further optimization on cycle time to achieve the ideal conditions. The uncertainty analyses performed showed that for each of these recovery techniques the results varied significantly depending on the combination of reservoir, hydraulic fracture design and operating input parameters. Economically, the oil price was the most influential parameter, while geologically the connate water saturation and formation thickness carried the greatest impact. A change in conditions could greatly influence the application of the recovery techniques and possibly yield different optimum configurations.
This paper provides an extensive workflow for optimizing EOR techniques and insight into their applicability in tight oil formations. It also demonstrates the importance of understanding the geological parameters prior to determining the ideal recovery technique and corresponding well configuration.
Nano-Particle Surfactant in Hydraulic Fracturing Fluids for Enhanced Post Frac Oil Recovery
Authors: Quintero Harvey , Mattucci Mike , Hawkes Robert , Zhang Kewei , O'Neil Bill 
Published: February 2018

Abstract
Due to the mixed-wettability phenomenon found in Montney rock fabric, choosing the ideal flowback enhancer/surfactant to Enhance Post Frac Oil Recovery (EPFOR), has not been a straightforward task. Along with the wettability ambiguity, Montney exhibits nano-Darcy permeability making laboratory testing challenging.
Conventionally at the flowback stage, injected treatment water is recovered as soon as possible with the intent to reduce the water saturation in the invasion zone and newly created complex network of fractures. On the contrary, the soakback/slowback concept has been recently adapted as a new practice for flowback management. The well is left shut in for an extended period to promote counter-current imbibition phenomena, where the residual hydraulic fracturing fluid can imbibe deeper in the formation matrix driven by osmotic and capillary forces. The imbibition mechanism into the matrix and dissipation of water saturations beyond the invasion zone help clean up water in the propped fractures and can help to ramp up peak hydrocarbon rates.
Common surfactant chemistry applied in hydraulic fracturing on Montney can be rendered inefficient due to the fast-adsorbing effect in the near-wellbore (hydraulic fracture face) area. Instead, an innovative nano-particle surfactant (NPS) has been developed, that can penetrate through formation rock and oil layers more efficiently, carrying low salinity hydraulic fracturing fluids deeper in the rock matrix, by reducing the in-situ interfacial tension between crude oil and the stimulation fluids and altering the mixed wettability of the formation rock to a more water-wet state. Additionally, the fabric of the Montney formation contains clays, which displays osmotic membrane characteristics in the presence of high salinity gradients (stimulation fluid and connate water). Once stimulation fluid invades the pore space through clay platelets, pore pressure increases and an expulsion of hydrocarbon from pore space is followed.
In this paper, we examine properties of NPS through a rigorous laboratory testing protocol with Montney core and liquid hydrocarbon specimens. Interfacial tension testing shows that when NPS is added at a minimum loading of 0.1 L/m3 in the stimulation fluid, a further interfacial tension reduction of approximately ~41.3% is reached in comparison to other commercially available petroleum surfactants at the same loading. Long-term Amott cell testing performed with Montney core samples in the presences of NPS displays a substantial increase in oil recovery when compared to the blank.
This paper attempts to detail the development of the NPS through laboratory and field testing which includes the characteristics of hydraulic fracturing fluids, produced hydrocarbons, and formation rock interactions.
Enhanced Recovery by Injection of Nitrogen and Carbon Dioxide Mixtures in Tight Reservoirs: A Combination of Partial Pressure Reduction and Competitive Adsorption
Authors: Santiago C. J. , Kantzas A. 
Published: February 2018

Abstract
Due to its superior properties in releasing hydrocarbons while reducing carbon foot-print, CO2 injection has been considered a promising technique for Enhanced Recovery in tight/shale reservoirs. However, although it has the potential to increase reserves, CO2 does not necessarily result in faster production. In this work, numerical modeling is used to demonstrate that a combination of N2 and CO2 as the injection gas mixture provides superior results in terms of both production performance and CO2 sequestration. The competing effects of Knudsen and molecular diffusion are incorporated by using the Maxwell-Stefan equations and the Dusty-Gas approach. The total flux of gas considers contribution of viscous flow, molecular and Knudsen diffusion, adsorption/desorption and surface diffusion. The 1D model is solved using the Method of Lines, and validated against counter-diffusion experiments available in the literature. Once validated, the model is used to perform numerical experiments demonstrating the effects of transport mechanisms during injection of N2 and CO2 mixtures. We evaluate average pressure, breakthrough times and chromatographic separation effects in the presence of a wider range of components (C1, C2, C3 and C4+) in flow through adsorbing porous media.
During validation, it is demonstrated that the Maxwell-Stefan equations are able to properly model friction between molecules, which is critical in evaluating displacement front advancement during gas injection. This demonstrates the superior properties of the Maxwell-Stefan equations, when compared to classical Fick’s law, which is commonly used in upstream modeling.
Due to adsorption and diffusion effects, the mobility of N2 and CO2 molecules in the medium is significantly different. It is observed that N2 moves quickly, since it does not interact strongly with the pore walls. As a result, breakthrough times are short. Behind the displacement front, N2 composition is high, and hydrocarbons are released due to partial pressure reduction. CO2, on the other hand, is readily adsorbed by the organic sites. This results in a self-sharpening behavior of the displacement front. Whenever a molecule of CO2 advances ahead of the concentration shock, it is quickly adsorbed, keeping a distinct front, in a piston-like fashion. Therefore, breakthrough times for CO2 molecules are considerably longer. Competitive adsorption of CO2 results in release of heavier hydrocarbon fractions, which forms concentration banks that are transported through the medium by the fast flowing N2.
The use of Maxwell-Stefan equations for evaluating chromatographic separation provides a well-founded approach to track frontal velocities and properly predict heavier hydrocarbon fractions production. It is demonstrated that a combination of N2 and CO2 injection in tight reservoirs helps in enhancing production while retaining injected CO2.
Eagle Ford and Pimienta Shales in Mexico: A Case Study
Authors: Cruz Marcela , Aguilera Roberto 
Published: February 2018

Abstract
The objective of this paper is to highlight the potential of the Eagle Ford (Cretaceous) and Pimienta (Upper Jurassic) shales in Burgos basin (Mexico) through a comparison with the Eagle Ford shale in Texas. The comparison is a case study focused on real data and their interpretation, north and south of the border, including geochemistry, geology, production, and reservoir engineering data.
The overall approach includes the description of Eagle Ford data in Texas, as well as Eagle Ford and Pimienta data in Burgos basin. The geologic comparison is carried out with the use of cross sections of the various formations and geophysical data. Geochemical and petrophysical data are compared with the use of specialized crossplots. Production data are compared through rate transient analysis and by investigating the different flow periods observed in wells in both sides of the border. Reservoir engineering aspects are compared with the use of material balance methods developed specifically for the case of multiporosity shale petroleum reservoirs.
Results indicate that there are many similarities but also some discrepancies between the Eagle Ford shale in Texas and shales in Mexico. The geologic and seismic cross sections show that there is continuity of the Eagle Ford in both sides of the border. However, structural geology in Mexico tends to be more complex than in Texas. The geologic and geochemistry descriptions also show important similarities in the rock mineralogy, and the quantity, quality and maturity of the organic matter. Well log data show the same pattern distribution on modified Pickett plots developed originally for evaluation of the Eagle ford shale in Texas. Shales production data in the Burgos basin are characterized by very long periods (several months or even years) of transient linear flow, something that compares well with the Eagle Ford in Texas. Specialized material balance calculations, which consider multiple porosities, have been used in the Eagle Ford shale in Texas and are shown to have similar application in the Burgos Eagle Ford and Pimienta shales. Based on the Eagle Ford shale performance in Texas, and the similarities with Burgos shales, the conclusion is reached that there is significant potential in the Mexican Eagle Ford and Pimienta shales.
The novelty of the paper is that it presents a comparison of the interpretation of real geoscience and engineering shale data collected in both sides of the border. The comparison is meaningful and suggests that the potential of shale reservoirs south of the border will be quite significant. Playing its cards right, Mexico should benefit from the good, the bad and the ugly learned in the Texas Eagle Ford.
Evaluating the Impact of Mechanical Properties of Kerogen on Hydraulic Fracturing of Organic Rich Formations
Authors: Khatibi Seyedalireza , Aghajanpour Azadeh , Ostadhassan Mehdi , Ghanbari Ebrahim , Amirian Ehsan , Mohammed Rehanali 
Published: February 2018

Abstract
Kerogen as one the main constituents of mud rocks is not thoroughly understood in terms of its mechanical characteristics. Kerogen is not as stiff as inorganic minerals within the rock matrix, but it can have a significant impact on the propagation of fractures. This becomes more important in organic rich shale reservoirs. In this study, first we proposed a fast method to predict mechanical properties of kerogen using Raman spectroscopy, which is a function of its molecular structure and chemical compounds, and then incorporated the results in hydraulic fracturing simulation. FLAC software was used to simulate opening of a fracture in the shaly and kerogen rich members of the Bakken formation. Then results were compared with a shale simple model missing organic matter properties. Results showed organic matter mechanical characteristics affects the hydraulic fracturing simulation by having faster fracture closure and requiring more fracing volume to achieve a specified fracture length compared to the simple model. The proposed method of using Raman spectroscopy can be used to make a profile of mechanical properties of organic matter and then be used in hydraulic fracturing simulation to optimize the operation.
On Estimating Irreducible Water Saturation in Tight Formations Using Nuclear Magnetic Resonance Relaxometry
Authors: Solatpour Razieh , Bryan Jonathan Luke , Kantzas Apostolos 
Published: February 2018

Abstract
Most of the Nuclear Magnetic Resonance (NMR) log based permeability models require the estimation of the irreducible water saturation (Swirr). Several methods are available for calculating this parameter using NMR relaxometry. The most straightforward method with the lowest accuracy is to consider a fixed relaxation time (T2) value. It has been suggested to use a T2-cutoff equal to 10 ms for tight reservoirs. Another traditional experimental method involves centrifuging core plugs to Swirr. In this paper, an additional approach to separate free and bound water using NMR relaxation time is introduced. This method involves the area under the amplitude-T2 relaxation time graph.
A series of experiments were conducted on 81 core plugs. These samples are mainly from the Western Canadian Sedimentary Basin. Core plugs are from Montney, Nordegg, Mist Mountain, Red Beds, Doig, Killam, Lathom, York River, Wapiti, Teslimkoy, Kesan, and Ordivician Quartz formations. NMR measurements were obtained initially on the dry cores to establish the presence of any liquids that were not cleaned or any isolated porosity. The air permeability was measured using an in-house permeameter. The cores were then brine saturated in two steps of spontaneous imbibition followed by forced imbibition under vacuum. The Archimedes principle was used to measure the sample pore volumes. Porosity was subsequently calculated. NMR relaxation data were then acquired on the brine-saturated cores. Then the core plugs were centrifuged under air to an expected irreducible saturation. NMR relaxation times were obtained on all cores at Swirr.
NMR porosity, T2gm, Irreducible Bulk Volume (BVI), and Free Fluid Index (FFI) were calculated. Swirr was calculated with the three aforementioned methods. Excel Visual Basic for Applications (VBA) programming language was employed for analyzing the relaxation times. The Timur-Coates model was applied for permeability calculation using all the aforementioned Swirr estimation methods. Data were analyzed, and discrepancy analysis was conducted.
The implemented area analysis method has been used previously in reservoir typing based on formation types and also as a factor in one permeability model. However, this is the first time this approach is used in calculating FFI/BVI exclusively. This method is faster than conventional estimators, and it is the only method that can implement Timur-Coates based permeability models for logging tools. From the experimental point of view, only a single NMR measurement is needed. Centrifuging the cores is not necessary. The possibility of cracking these cores due to spinning is eliminated. This new approach is less computationally demanding, and calculations are easier to perform. It is proven that the fast peak area method is more accurate than the fixed T2-cuttoff and in some cases the centrifuge method.
Wettability and Capillary Imbibition in Shales; Analytical and Data-Driven Analysis
Authors: Mohammadmoradi Peyman , Kantzas Apostolos 
Published: February 2018

Abstract
A semi-analytical formulation of the spontaneous capillary imbibition is used to analyze the liquid intake of six shale samples, linking imbibition capacity and rate to lab-scale measurements. Moreover, a data-driven approach is utilized to examine the effect of mineralogy and porosity on the macroscale wettability of shales. According to the results, the presence of connected organic sub-layers lowers the destructive impacts of spontaneous water imbibition on hydrocarbon permeability. Furthermore, the intrinsic permeability, tortuosity, wettability, and initial and residual saturations are among the most influential factors influencing the water uptake during shut-in periods after hydraulic fracturing operations.