bluuebunny/crossref_metadata_2025_split huggingface dataset:
El clock de la estación
Authors: Attig Remy 
Published: November 2019

Fabián Severo’s collection of short stories, Viralata, from which this short story comes, was originally published in Portuñol, a “hybrid” mix of Spanish and Portuguese, as it is spoken near the city of Artigas in northern Uruguay. Portuñol, like other “hybrid” border varieties, has rarely been published, though it would seem that interest is growing since the 1990s, particularly in Uruguay.

As a scholar of “hybrid”, diaspora, and transnational languages I decided to explore the possibility of translating this work into Spanglish, the “hybrid” mix of Spanish and English commonly heard among Latinxs in the US. Though the cultural realities of Portuñol speakers and Spanglish speakers is different, there are some important parallels: literature in both has emerged only relatively recently, little has been translated into either language variety, education is not conducted in either, and the dominant discourses around language in both contexts has traditionally favoured literature written in the prestige varieties of English, Spanish, or Portuguese—which should come as no surprise. Given this, I wondered about the experience, aesthetic, and cultural value of putting two distant borders of Spanish in contact through translation.

This is my first translation of Fabián Severo’s work.
Relationships of p16 Immunohistochemistry and Other Biomarkers With Diagnoses of Cervical Abnormalities: Implications for LAST Terminology
Authors: Castle Philip E. , Adcock Rachael , Cuzick Jack , Wentzensen Nicolas , Torrez-Martinez Norah E. , Torres Salina M. , Stoler Mark H. , Ronnett Brigitte M. , Joste Nancy E. , Darragh Teresa M. , Gravitt Patti E. , Schiffman Mark , Hunt William C. , Kinney Walter K. , Wheeler Cosette M. ,   New Mexico HPV Pap Registry Steering Committee,   p16 IHC Study Panel
Published: November 2019

Context.—Lower Anogenital Squamous Terminology (LAST) standardization recommended p16INK4a immunohistochemistry (p16 IHC) for biopsies diagnosed morphologically as cervical intraepithelial neoplasia (CIN) grade 2 (CIN2) to classify them as low-grade or high-grade squamous intraepithelial lesions (HSILs).Objective.—To describe the relationships of p16 IHC and other biomarkers associated with cervical cancer risk with biopsy diagnoses.Design.—A statewide, stratified sample of cervical biopsies diagnosed by community pathologists (CPs), including 1512 CIN2, underwent a consensus, expert pathologist panel (EP) review (without p16 IHC results), p16 IHC interpretation by a third pathology group, and human papillomavirus (HPV) genotyping, results of which were grouped hierarchically according to cancer risk. Antecedent cytologic interpretations were also available.Results.—Biopsies were more likely to test p16 IHC positive with increasing severity of CP diagnoses, overall (Ptrend ≤ .001) and within each HPV risk group (Ptrend ≤ .001 except for low-risk HPV [Ptrend &lt; .010]). All abnormal grades of CP-diagnosed biopsies were more likely to test p16 IHC positive with a higher HPV risk group (Ptrend &lt; .001), and testing p16 IHC positive was associated with higher HPV risk group than testing p16 IHC negative for each grade of CP-diagnosed biopsies (P &lt; .001). p16 IHC–positive, CP-diagnosed CIN2 biopsies were less likely than CP-diagnosed CIN3 biopsies to test HPV16 positive, have an antecedent HSIL+ cytology, or to be diagnosed as CIN3+ by the EP (P &lt; .001 for all). p16 IHC–positive, CP-diagnosed CIN1 biopsies had lower HPV risk groups than p16 IHC–negative, CP-diagnosed CIN2 biopsies (P &lt; .001).Conclusions.—p16 IHC–positive, CP-diagnosed CIN2 appears to be lower cancer risk than CP-diagnosed CIN3. LAST classification of “HSIL” diagnosis, which includes p16 IHC–positive CIN2, should annotate the morphologic diagnosis (CIN2 or CIN3) to inform all management decisions, which is especially important for young (&lt;30 years) women diagnosed with CIN2 for whom surveillance rather than treatment is recommended.
Laboratory Investigation of Sweeping Efficiency by Multiple Horizontal Wells CO2 Huff and Puff in Fault-Block Reservoirs with an Edge Aquifer
Authors: Wang Zhixing , Hou Jirui , Hao Hongda , Zhao Fenglan , Yan Li 
Published: November 2019

Abstract
Water coning constrains the effective development of fault-block reservoirs by horizontal wells. CO2 huff and puff from field cases prove to be effective in water control and oil stimulation. However, gas sweeping efficiency varies due to geological complexity and unclear oil-water interaction. Therefore, CO2 huff and puff by multiple horizon wells needs to be optimized for a better sweep efficiency. A physical model similar to a fault-block reservoir with edge aquifer and reservoir dip was devised. Three horizontal wells were deployed according to the distance from the aquifer. CO2 huff and puff experiments were conducted to investigate sweeping results of the selection of injecting well, combination of injection wells within the model. In addition, one numerical model corresponding to the physical one was built and numerical experiments were carried out to quantify the gas sweeping efficiency. The simulation results show that the sweeping effect decreased with the increase in the distance from the aquifer as CO2 was injected from one horizontal well. Furthermore, when two optimized horizontal wells huffed the similar amount of CO2, gas sweeping efficiency improved: A higher drop in water cut (34.26% to 33.53%), more oil recovery increase (15.38% to 17.59%), and a lager gas sweeping volume (33.56% to 24.66%) were obtained in the simulation experiments. It was concluded that CO2 sweeping efficiency could be further improved within the same gas volume by horizontal wells optimization. Both physical and numerical conceptional model of fault-block reservoir was devised. And the improved CO2 sweeping efficiency by multiple horizontal wells CO2 huff and puff offers theoretical reference for field application.
The Applicable Limits of the High Strength Gel System to the Tight Sandstone Fractured Reservoir in CO2 Flooding
Authors: Fenglan Zhao , Ting Xu , Jirui Hou , Liguang Song , Guoyong Lu , Hairu Feng 
Published: November 2019

Abstract
The matrix permeability of the tight sandstone reservoir is very low, which causes difficulty to inject water, the CO2 flooding is applied widely to these reservoirs for the better oil displacement and low injection pressure, but natural fractures develop as well as artificial fractures exist in the tight reservoir, makes gas-channeling along the fractures severe when proceeding a CO2 flooding process, blocking the fractures is necessary for displacing the residual oil trapped in the matrix. The self-developed tight sandstone fractured cores which can simulate different conditions of fracture width and matrix permeability had been used to evaluate the blocking effect of the high strength starch gel system, the mechanism that the high strength gel system blocked the fractures and activated the residual oil in matrix was analyzed by comparing the pressure when CO2 broke through and the incremental recovery after blocking in CO2flooding experiments, then the applicable limits that the high strength starch gel system improved the oil displacement of CO2 flooding in the tight sandstone fractured reservoir had also been discussed. The results showed that the high strength starch gel system could be used to block the fractures, and the blocking effect and the incremental recovery were the best when the fracture width was 0.42mm, however both effects became worse when the fracture width decreased to 0.08mm or increased to 0.65mm because of the injection limitation or the reduction of blocking effect; furthermore, the residual oil in the matrix could be activated effectively after the high strength starch gel blocked the fractures even if the matrix permeability reduced to 0.1mD, the research results can provide reference to the design and optimization of project when proceeding a CO2 flooding process in the tight sandstone reservoir.
The Development of CO2 Plume in CO2 Sequestration in the Aquifer
Authors: Fu Hao , Long Yifu , Wang Sai , Wang Yanbo , Yu Peng , Ling Kegang 
Published: November 2019

Abstract
Geological carbon sequestration through injecting large-scale carbon dioxide (CO2) into the deep saline aquifers represents a long-term storage of CO2. In the CO2 sequestration process, the injected CO2 is displacing water from the injection point and is expected to remain in the reservoir. Due to the nature of one phase displacing another phase in porous media, it is noted that different water saturation exists in the CO2 plume during the displacement. Water distribution in the plume will affect the size of the plume subsurface. Furthermore, the gravitational segregation between CO2 and water will cause overriding-tonguing during the injection and impact the shape of plume. To better understand the CO2 movement underground and development of CO2 plume, it is necessary to take the two-phase flow and gravity force effects into account when evaluating CO2 displacing water. The displacement of water by injecting CO2 is not a piston-like process in aquifer. Because water is the wetting phase and CO2 is the non-wetting phase when two phases flow in reservoir, water occupies the surface of matrix and small pores while CO2 resides in large pores and centers of pores. As a result, various water saturations distribute behind CO2 front during the displacement. The distribution is a function of fluid and rock properties, fluid-rock interaction, and injection operation. In this study, these factors are considered when developing new models to predict CO2 plume evolution during injection. Mass conservation, multiphase flow, and equation-of-states are applied in the derivation of the models, which guarantees a rigorous approach in the investigation. The modeling results indicate that CO2 does not displace water completely away from the plume. The shape of the CO2 front is controlled by the relative permeability of two phases and capillary pressure. Water saturation profile from CO2 injecting point to the displacement front shows that water saturation behind the CO2 front increases outwardly, and the change in saturation is non-linear. The injection rate impacts the sharpness of the CO2 front, thus leads to different gas plume sizes for same injection volume. The outward movement of the CO2 front decelerates as injection time goes on. The research illustrates that injection experiences two stages: transient and steady-state, in which the displacement behavior and the development of gas plume vary. Although the duration of transient stage is dictated by size of aquifer and is relatively short comparing with steady-state stage, its influence on the development of CO2 plume cannot be neglected when selecting gas compressor horsepower and determining injection rate.
Research on Well Integrity during CO2 Geological Utilization and Storage Based on CT Scanning Technique
Authors: Zhang Jingtian , Mu Lingyu , Guo Qingfeng , Cai Zhixiang , Lu Fan , Jiao Zhen 
Published: November 2019

Abstract
The ultra-deep formations of Tarim Basin is characterized by ultra-high temperature, high pressure, and ultra-thick composite salt-gypsum formations, so it will bring great challenge to well integrity during CO2 sequestration. Therefore it is necessary to evaluate the impact of temperature decrease and salt rock creep on injection well integrity.
Firstly, the numerical simulation method could be used to analyze the influence of temperature drop and salt rock creep on the integrity of the wellbore during CO2 sequestration. The actual stress of the wellbore cement sheath was equivalent to the simulated wellbore cement by the stress equivalent method. Secondly, CT scanning technology was used to detect the internal structure of the cement sheath, revealing its failure mechanism. Lastly, with the help of GMI and WELLCAT software, the optimization of design parameters during CO2 sequestration is realized.
The results show that under some circumstances the micro-annulus between casing and cement sheath can be changed by salt creep or self-healed. The mechanism of casing damage in salt layers was preliminarily revealed. CT scans were performed on the cement sheath before and after the experiment. By comparing the gap volume changes of the casing cement sheath, it was found that there was a micro-annulus between the casing cement sheath. The mechanism of casing damage in salt layers was preliminarily revealed during CO2 sequestration. It is indicated that casing damage is mainly caused by the non-uniform load induced by the creep of salt-gypsum layers, the low temperature, and the poor cementing quality. Finally, a series of measures were proposed to prevent casing damage during CO2 sequestration in the areas with a salt formation.
This new method can effectively reduce cost of casing material selection and make for guaranteeing oilfield development efficiency and CO2 sequestration while maintaining wellbore integrity and controllable well control safety.
Empirical Correlation of Minimum Miscible Pressure of Pure and Impure CO2 Flooding
Authors: Chen Hao , Li Bowen , Zhang Xiansong , Tan Xianhong , Tian Xiaofeng , Han Jingwen , Yang Shenglai 
Published: November 2019

Abstract
Several methods to determine the MMP can be introduced for the forecast. Slim tube test is one of the widely accepted methods for the use of actual crude oil, but it is high cost and time consuming. The accuracy of slim tube simulation method greatly depends on the accuracy of compositional model matched by the PVT test data. Analytical method is very fast, but it is difficult to find the unique and correct set of key tie lines in the displacements is very difficult. This paper presents a simple and accurate empirical correlation for MMP prediction of miscible flooding, which is faster and less cumbersome than slim tube test and slim tube simulation. Unlike previous empirical correlation methods, our new correlation considers the effect of both reservoir temperature, oil composition and gas contamination, as well as the influencing degree. For pure CO2, except reservoir temperature, mole fractions of the (C1+N2), (C2−C4), and (C5−C6), molecular weight of C7+of the crude oil are taken as the influencing factors for the MMP prediction. It is found that the relationship of MMP and these parameters is linearly dependent, thus, regress function based on least square method is used to fit a new correlation. On this basis, mole fractions of CH4, N2, H2S, and intermediate components (C2−C6) in the injection gases were separately selected to predict the MMP differences caused by the contaminated gas. Nlinfit function of nonlinear fitting was proposed due to the complex effect of reservoir temperature and volatile components of the oil on the mixing of oil and injection gases. Our approach is more accurate and robust than most of previous empirical correlations which lack specific consideration of the key factors. According our new empirical correlation, the MMP of miscible flooding for pure and impure CO2 can be calculated in minutes using by using a simple Excel spreadsheet with the input of just very basic data. Our approach supplies a more accurate method for the fast screening of potential oilfield to implement CO2 miscible flooding.
Analytical Solutions of Leakage Through the Caprock in Carbon Sequestration in a Closed Boundary Aquifer System
Authors: Mu Lingyu , Liao Xinwei , Zhang Jingtian , Liu Guoguang , Jiang Chenshuo , Zou Jiandong , Li Rongtao 
Published: November 2019

Abstract
Deep saline aquifer is deemed as an effective and promising site for carbon sequestration. A geological storage site must be operated safely; however, CO2 may leak through several pathways, such as fractures, faults and/or improperly plugged wells.
This study presents a new analytical model predicting the pressure change in the monitoring well and the leakage rate, caused by an inclined fracture in the caprock, to detect and evaluate the leakage. Distinct with previous analytical method, herein we propose a new case of the leakage through the inclined fracture in a closed aquifer system, which expands on earlier work to a wider application. The solutions for the injection at a constant rate and the time-dependent leakage through an inclined fracture of caprock are derived with Laplace transform, Fourier cosine transform and Duhamel's principle. Then, by means of the superposition method, the pressure change and the leakage rate with both of the two processes are determined in succession. Based on the above solutions, we discuss the effect of the leakage path and the boundary of the aquifer on the system.
At the early stage, the leakage rate increases more rapidly with the smaller radius of the aquifer. Moreover, in the smaller aquifer, the rapid pressure transient results in that the system quickly reach the stable stage. The effect of the inclined fracture on the system is embodied in its permeability, location and angle. With higher permeability the leakage rate increases more quickly at early stage and reaches the constant value more quickly at late-time stable stage. The fracture has slight impact on the leakage in the long term. Location of fracture does not affect the leakage rate at rapid increase stage. Leakage rate is larger and increases with smaller distance at transitional stage. With the increase of angle, leakage rate increases at all three stages. At the late-time stage, the larger the angle is, the larger the leakage rate is.
Models for Calculating Corrosion Rates in Water-Saturated and Under-Saturated CO2 Systems & Water Solubility in CO2 Systems at Supercritical Conditions
Authors: Kowta Rama , Erickson Dale , Barker Richard , Neville Anne , Hua Yong 
Published: November 2019

Introduction
Carbon capture and storage (CCS) is regarded as one of the main alternatives for the reduction of anthropologic CO2 emissions. In the CCS process, CO2 from power plants and from other large CO2 point sources are captured and transported at dense (liquid or supercritical) conditions after which it is injected into storage sites. Accurately predicting internal corrosion rates in high-pressure CO2 environments is critical to the design and operation of pipelines used for CCS systems. In water-containing dense phase CO2 environments, corrosion rate increases in conjunction with humidity, typically reaching a critical humidity, beyond which corrosion rates become particularly high. The presence of impurities in the CO2 stream influence the solubility of water and hence the humidity and corrosivity of the CO2 stream. If the CO2 stream is under saturated and below a particular humidity level, then there can be significant cost saving on CCS projects, as this enables carbon steel pipelines to be used with confidence.
The purpose of this work is to develop models to calculate corrosion rates of CO2 systems with under-saturated water conditions in presence and absence of impurities. These models depend on the solubility of water in the CO2 rich phase at saturated conditions. A modified Peng-Robinson equation of state (EoS), E-PPR78 (Jaubert and Mutelet (2004)), available in literature is modified to match water solubility in the CO2 phase for CO2 systems in the presence and absence of impurities at both supercritical conditions and on both sides of the two phase-region.
Roadmap to Asphaltene Characteristics, Properties, and Presence in Crude Oils Based on an Updated Database From Laboratory Studies
Authors: Fakher Sherif , Ahdaya Mohamed , Elturki Mukhtar , Imqam Abdulmohsin , Abdelaal Hesham 
Published: November 2019

Abstract
Asphaltene is one of the components of crude oil that can cause many problems during oil production. Understanding the asphaltene chemical structure and the conditions at which asphaltene instability was reported is extremely important in avoiding asphaltene related problems. Several experimental researches have been conducted to evaluate asphaltene concentration, particle and aggregate size, elemental content, precipitation, flocculation, deposition, pore plugging, adsorption, and wettability alteration. This research constructs a roadmap on asphaltene instability conditions using data from more than 200 laboratory studies reported on asphaltene instability problems. This research aims to provide a comprehensive and detailed data analysis on asphaltene properties, and the factors affecting asphaltene equilibrium to determine the working conditions at which asphaltene has been studied, and the main properties of asphaltene in crude oil. The data collected included 219 laboratory studies including more than 4000 experiments from countries across the globe. The data analysis involved gathering and cleaning of the data, homogenizing the units, and then analyzing the data using two statistical analysis tools including histograms and boxplots. The figures generated using these two statistical analysis tools include asphaltene properties, heteroatoms concentration, crude oil properties, and thermodynamic conditions. To the authors' knowledge, no comprehensive data analysis has been performed on asphaltene in crude oil, which makes this research significant in terms of determining the lab and field properties that mostly affect asphaltene in crude oil and the working condition affecting asphaltene equilibrium.
Carbon Dioxide Injection Pressure and Reservoir Temperature Impact on Oil Recovery from Unconventional Shale Reservoirs During Cyclic CO2 Injection: An Experimental Study
Authors: Fakher Sherif , Ahdaya Mohamed , Elturki Mukhtar , Imqam Abdulmohsin 
Published: November 2019

Abstract
Carbon dioxide (CO2) injection has recently been applied in unconventional shale reservoirs to increase oil recovery. There are many methods by which CO2 can be injected. One of the most common methods, especially in unconventional reservoirs, is cyclic CO2 injection. This research experimentally investigates the ability of cyclic CO2 injection to increase oil recovery from unconventional shale reservoir, and the impact of reservoir thermodynamics, including pressure and temperature, on the oil recovery potential. The experiments were conducted using a specially designed vessel to mimic the cyclic CO2 injection operation. The shale cores were saturated with crude oil for seven consecutive months at high temperature. The cores were then placed in the huff-n-puff vessel and the experiment was commenced. The pressure and temperature conditions were found to have a strong impact on oil recovery, especially as the injection cycles progressed. The thermodynamic conditions were also found to impact the core integrity greatly, with some cores breaking at some conditions, and the natural fractures being stimulated as well. This research can help illustrate the impact of reservoir thermodynamics on the oil recovery potential from unconventional shale reservoirs during cyclic CO2 injection.