bluuebunny/crossref_metadata_2025_split huggingface dataset:
The Centrioles,Centrosomes, Basal Bodies, and Cilia ofDrosophila melanogaster
Authors: Lattao Ramona , Kovács Levente , Glover David M 
Published: May 2017

AbstractCentrioles play a key role in the development of the fly. They are needed for the correct formation of centrosomes, the organelles at the poles of the spindle that can persist as microtubule organizing centers (MTOCs) into interphase. The ability to nucleate cytoplasmic microtubules (MTs) is a property of the surrounding pericentriolar material (PCM). The centriole has a dual life, existing not only as the core of the centrosome but also as the basal body, the structure that templates the formation of cilia and flagellae. Thus the structure and functions of the centriole, the centrosome, and the basal body have an impact upon many aspects of development and physiology that can readily be modeled in Drosophila. Centrosomes are essential to give organization to the rapidly increasing numbers of nuclei in the syncytial embryo and for the spatially precise execution of cell division in numerous tissues, particularly during male meiosis. Although mitotic cell cycles can take place in the absence of centrosomes, this is an error-prone process that opens up the fly to developmental defects and the potential of tumor formation. Here, we review the structure and functions of the centriole, the centrosome, and the basal body in different tissues and cultured cells of Drosophila melanogaster, highlighting their contributions to different aspects of development and cell division.
Antagonismo de Saccharicola sp., contra fitopatógenos de la raíz de chile jalapeño (Capsicum annuum)
Authors: Uc-Arguelles Ana Karina , Pérez-Moreno Jesús , Ayala-Escobar Victoria , Zavaleta-Mejía Emma 
Published: May 2017

<p>Se evaluó la capacidad antagónica de <em>Saccharicola </em>sp <em>in vitro</em> e invernadero contra <em>Phytophthora capsici</em>, <em>Fusarium oxysporum</em> y <em>Rhizoctonia solani</em>. Mediante confrontaciones duales se evaluó la reducción de crecimiento del fitopatógeno y se registró el número de días en que el antagonista invadió el micelio de los patógenos, se determinó la viabilidad del micelio invadido y la producción de propágulos del fitopatógeno. <em>Saccharicola</em> sp causó reducción de 44.8 % y 45.1 % en el crecimiento de <em>P. capsici</em> y <em>F. oxysporum</em> a los 3 días posteriores a la confrontación (dpc) y en <em>R. solani</em> 36.2 % a los 2 dpc. Para determinar su potencial micoparasítico se realizaron microcultivos. A las 72 h se observó el enrollamiento del antagonista alrededor de <em>P. capsici</em>. En <em>R. solani</em> desde las 24 h se observaron hundimientos en los sitios de contacto con el antagonista. A pesar que en condiciones <em>in vitro Saccharicola</em> sp mostró un efecto negativo contra los fitopatógenos y hubo evidencia de micoparasitismo, en invernadero no redujo la incidencia y severidad de la enfermedad, ni promovió el crecimiento de las plantas.</p>
Geomechanical Assesment of Injection Pressure Constraints for a Waterflood Field Development
Authors: Aamri Mohammed , Al Zadjali Ruqaya , Mahajan Sandeep , Hindriks Cornelius 
Published: May 2017

Abstract
Geomechanic can play a major role in designing successful waterflood operations. The objective of this paper is to discuss the Geomechanic workflow that aims to provide optimal injection pressures which maximize the injected volumes while avoiding the growth and propagation of hydraulic fractures in the reservoir. The success of waterflood development depends on a proper pressure injection design which requires knowledge of formation fracture pressures and rock properties. This paper shows how Geomechanic can be used advantageously to set appropriate injection constraints that can vary from one field to another and even within a field by itself. Within PDO it is now a common development practice to do a geomechanics studies to investigate the maximum allowable injection pressure such that no fractures will develop and grow (matrix injection conditions).
A semi-analytical wellbore equation is used (based on an elasto-plastic model) to predict a range of bottom hole pressures that can be used to avoid fracturing. Further, a Monte Carlo analysis is applied to get probabilistic results. Data from well tests and operational data like Hall plots were analyzed and used in this geomechanics workflow. Also, geomechanical modeling was carried out to estimate the rock properties (from logs) and the orientation and magnitude of the stresses. It is critical to understand the in-situ stresses in the formation, in particular the minimum horizontal stress. Therefore, the derived (estimated) data was complemented by measured data: pore pressure and the minimum horizontal stress (mini-frac data). Results were verified via a rigorous analysis of a number of waterflood campaigns. These confirmed that in general fracturing conditions can be (substantially) higher than the generally assumed minimum stress (gradient) or the minimum stress (gradient) in the formation that is to be injected.
As an example this geomechanics workflow that determines the maximum injection pressure will be applied to a reservoir (in Oman) that consists of carbonate and shale formations. The maximum injection pressures show variations across the formation. Based on the results of the analyses in this study limits for waterflood injection pressure were recommended for the future development and will have a direct impact on the economics of the planned field development in terms of recovery rate.
A New Robust Nonlinear Inversion Algorithm for LWD Resistivity Measurements in High-Angle and Horizontal Wells
Authors: Hu F. X. , Fan Y. R. 
Published: May 2017

Abstract
Logging-while-drilling (LWD) Resistivity Measurements in high-angle and horizontal wells cannot be used for quantitative calculation directly, since they are easily influenced by borehole/formation geometry, surrounding beds and other factors. Although Least-Squares (LS) inversion method is widely used to reconstruct the actual reserve resistivity, it assumes that the measurement data are corrupted with pure Gaussian noise. This assumption makes it cannot work when the measured data are contaminated by non-Gaussian noise. Furthermore, in highly deviated wells, LWD apparent resistivity measurements always show "horns" near the bed boundaries where the resistivity contrastsare high. These "horns" can also decrease the inversion accuracy.
In this paper, we propose a new robust nonlinear inversion algorithm that uses Huber criterion as a solution for handling the measured data mentioned above. Compared with Least-Squares inversion, this method requires one additional parameter, namely, the threshold of Huber criteria, δ. This parameter is very important and must be chosen carefully. By varying δ, Huber inversion method can be divided into two parts. If the absolute error of simulated response (compared to the measured response) is greater than δ, l1 norm inversion is used. Otherwise, l2 norm inversion method is used. This method combines advantages of both l1 and l2 inversion and works best if the resistivity data contains non-Gaussian noises as well as "horns". Meanwhile, during the inversion process, we introduce a new approximate method for computing the Jacobian matrix and desired step, which could improve the calculation results. Besides, since currentmulti-resolution LWD resistivity tools could providemultiple compensated resistivity measurements, a linear optimization combination method of iterative stepsis introduced for multi-resolution resistivity curves. The weights can be adjustedaccording to the LWD resistivity sensitivity for borehole deviation, resistivity contrast at bed boundaries, and the contaminated extent by noise. This optimal procedure could further improve the computation accuracy.
A series of numerical simulations for different conditions are analyzed and discussed, the comparison of LS and Huber inversion shows that Huber algorithm is more robust and stable when the measurements contain both data of "horns" and non-Gaussian noise. Therefore, this method is more suitable for routine petrophysical interpretation and quantitative formation evaluation.
Asphaltene Phase Behavior Modeling for Wells from the Middle East
Authors: Al-Qasim Abdulaziz 
Published: May 2017

Abstract
Production and processing operations of crude oil require a thorough understanding of phase behavior. To model asphaltenes, we need to know more about their phase behavior. The model has to incorporate the interaction of asphaltene and oil in terms of solubility in oil and the suspension characteristics attributed to resin.
This paper reports a comprehensive phase behavior study for five wells from the Middle East was performed as part of an asphaltene precipitation study. The study outlined several important concepts and detailed procedures for modeling asphaltene phase behavior using WinProp, which uses the Nghiem model for asphaltene precipitation
Using NMR T2 to Predict the Drainage Capillary Curves Pc-Sw in Carbonates Reservoirs
Authors: Raheem Oriyomi Nurudeen , Fernandes Martin Olivier , Thomas Nithin Chacko , Hashem Mohamed Hossni , Alfazazi Umar , Sulemana Nuhu Turosung 
Published: May 2017

Abstract
This research work predicts capillary pressure curves at primary drainage from the transverse T2 relaxation times of the NMR pore size distributions with ninety percent accuracy, which could do the trick in reservoir applications. The capillary pressure-water saturation curves are important instructions to reservoir simulators for predicting the dynamic properties of the reservoir as well the fluid saturations at different depths. This study originated from the challenges in forecasting the initial saturations from an NMR logged well. The procedure is a simple and non-damaging construction of capillary pressure curves from plug samples measurements.
Dynamic rock typing was used to assign the capillary pressure data to different layers in the reservoir. Laboratory Nuclear Magnetic Resonance (NMR) equipment has been proven to produce information on pore size distribution and varieties of methods was found in the literature to predict capillary pressure curves from borehole NMR logs. The proposed idea of integrating drainage capillary pressure from centrifuge to T2 distributions from NMR enables rapid synthesis of capillary pressure from plugs and interpretation of logs.
A scaling factor k, is adopted in the T2-Pc conversion. The optimum scaling factors for most research work is built upon the results. Water saturation at certain pressures, is often estimated from capillary pressure curves. It can therefore be argued that the perfect procedure of estimating the best scale factors is to recreate the saturations by the capillary pressure curves developed from NMR. In this research work, the range of pressures and T2 relaxation time was 0 – 500 psi and 1 – 10000 ms respectively. Due to different geological facies usually described by the capillary pressure curves of different formations, the capillary pressure curves of the completely cored reservoir were reconstructed to get the average scaling constant, k of 4 psi.s with a low standard deviation of 0.02. The capillary pressure versus T2 curve tend to fit a power regression with a coefficient of determination of R2= 1, signifying that the regression line analysis fits perfectly with the data for the 18 core samples.
With the T2-Pc conversion established, the capillary pressure data can be predicted continuously in the whole section of the reservoir. The procedure is more accurate compared to others since it takes cognizance of the pore structure from NMR distribution, and it is applicable to T2 distributions estimated at various water saturations. Previous methods are applicable to 100% brine saturated plugs, which nullifies their predicted capillary pressure curves.
Adaptive Approach For Heavy Oil Reservoir Description And Simulation
Authors: Ursegov Stanislav , Zakharian Armen , Taraskin Evgenii 
Published: May 2017

Abstract
The main goal of the reservoir modeling including heavy oil ones by means of any deterministic model is to predict their further development results. A similar problem is solved by decline curves. We propose a new system that combines both approaches. The developed model was called adaptive. The main advantage of the adaptive approach is the possibility to modify the mathematical apparatus of the model, depending on the uncertainty of geological and production data.
The volume of initial information to construct the adaptive model is comparable to the volume of initial information to construct any deterministic model. The structure of the adaptive model also suggests the presence of deterministic geological and hydrodynamic components. However, they are based on different principles than the deterministic models. The mathematical apparatus of adaptive modeling is based on the use of such approaches as a non-parametric statistics, fuzzy logic, numerical solution of differential equations, and intelligent algorithms.
On the basis of the developed approach, the adaptive geological and hydrodynamic models of the Permian - Carboniferous reservoir of the Usinsk field, which is the largest one according to its value of remaining recoverable reserves of heavy oil in the Timan-Pechora region of Russia were created. The main objective of reservoir simulation using the adaptive model is to determine which cells of the model obtained the produced oil and water, and where they remained less, and where the injected water or steam went. For the adaptive hydrodynamic models, the absolute values of reservoir parameters are not important; their diversity between neighboring cells is more significant.
A new approach to the construction of geological and hydrodynamic models of heavy oil reservoirs based on the principle of fully discrete simulation which can be used to solve the most of the known problems associated with the reservoir development and increase of oil recovery on such complex objects including the forecast of efficiency of work-over techniques measures (drilling of new wells, cycle steam stimulation, water shut-off works, etc.).
A New Approach for the Simulation of Fractured Vuggy Carbonate Reservoir with an Application to Upscaling
Authors: Gao Sunhua , Killough John E. , He Jie , Fadlelmula Mohamed M. , Wang F. Yuhe , Fraim Michael L. 
Published: May 2017

Abstract
Numerical modeling of naturally fractured vuggy reservoirs presents many challenges due to the coexistence of three very different kinds of media and their complex interaction on multiple scales. With current computing capabilities, conventional fine-scale single-porosity models are not practical for large-scale reservoir simulation. A multi-continuum reservoir model is presented as an effective approach to modeling fractured vuggy reservoirs on the coarse scale. This model consists of four different porosity systems, i.e. the matrix, fractures, isolated vugs and connected vugs. This study investigates mass exchange between different porosity systems with the final objective of developing new transfer functions that can be used as an application to upscaling fractured vuggy reservoir models.
A well-designed procedure is proposed to obtain the novel transfer functions in multi-continuum fractured vuggy reservoir models. Different realizations of the vug-filled matrix blocks are generated to show the effect of vug fraction, distribution and connectivity on multi-phase fluid flow. For interporosity flow between vugs and the other two media, new formulations of the shape factors that incorporate the effect of vug spatial variation are developed respectively. The dominant mechanisms of multiphase fluid exchange between each two porosity systems (matrix-isolated vugs, fractures-connected vugs) are discussed separately. New transfer functions for multiphase flow in the multi-continuum fractured vuggy model to capture the complex flow mechanisms and emulate the results of the fine-grid model are provided. In addition, a transmissibility multiplier table is introduced as another connection term for the transfer functions to improve the accuracy of upscaling solution. Finally, a new upscaling approach by incorporating the proposed transfer functions into multi-continuum models is presented.
This paper provides a new insight to the complex fluid exchange among three different media in fractured vuggy reservoirs. Results show that the new upscaling methodology helps to reduce the size of simulation model and improve the computational speed significantly, while providing an accurate representation of the fine-scale results.
An Injection Optimization Decision-Making Tool Using Streamline Based Fuzzy Logic Workflow
Authors: BuKhamseen Nader Y. , Al-Najem Abdullah A. , Saffar Ali H. , Ganis Santiago A. 
Published: May 2017

Abstract
Streamlines provide detailed information about dynamic fluid paths and connectivity between injectors and producers. Fuzzy logic can simulate human thinking and handle different categories of information including linguistic, imprecise, approximate, and overlapping to name a few. This paper presents a genuine approach for field injection optimization using a streamline-based fuzzy logic system.
In a previous paper, we presented an adaptive streamline based fuzzy logic system that uses three input parameters namely injection efficiency (IE), water cut (WC), and injection loss to aquifer to assign an injector ranking index (IRI) according to injector performance. In this paper, we enhanced the streamline based fuzzy logic workflow to smartly redistribute water injection by accounting for operational constraints and number of supported producers in a pattern in addition to the IRI. The new workflow examines the low performers (i.e., low and medium IRI categories) and assigns different injection reduction factors for each injector in these categories. Then, the total amount of reduced injection is assigned to high performers (i.e., high IRI) while ensuring no operational constraint is violated, such as BHP and capacity of pumps.
This approach has been tested on a large-scale DPDP simulation model. The area of interest in this field has two rows of injectors: downdip and updip. The updip injectors are the focus of the study. The results of this case study show noticeable improvements in injection efficiency for most wells in the area of interest ensuring better sweep, good pressure support, and improving cumulative oil production.
We believe combining both technologies, namely streamlines and fuzzy logic, can provide reservoir engineers with a robust decision-making tool to attain a more successful field-wide water injection strategy.
Evaluation of Enhanced Oil Recovery Technologies for the Sabriyah Lower Burgan Reservoir Kuwait
Authors: Al-Murayri M. T. , Al-Mayyan H. E. , Faraj A. A. , AlAbdullah M. B. , Pitts M. , Wyatt K. 
Published: May 2017

Abstract
This paper presents the results of a methodical screening and evaluation study on various enhanced oil recovery technologies for potential deployment at the Sabriya Lower Burgan (SALB) reservoir in Kuwait. The EOR technologies that were considered in this study included alkaline-surfactant-polymer, surfactant-polymer, polymer, CO2, N2 and Low Salinity flooding. Initial parametric screening of different EOR technologies was conducted based on reservoir characteristics, and this was followed by laboratory studies to determine the extent to which the initial screening conclusions were valid. Sector model simulations were also used to evaluate and confirm the suitability of the Sabriya Lower Burgan reservoir for the above-mentioned EOR technologies.
Screening and sector model simulations of the Sabriyah Lower Burgan formation indicated that Section A has potential for enhanced oil recovery technologies while the B zone does not, primarily due to the strong water drive in Section B. Chemical flooding, specifically alkaline-surfactant-polymer and surfactant-polymer flooding, low sal flooding, miscible N2 flooding, and CO2 flooding were considered to have potential while polymer flooding, thermal technologies, and immiscible gas flooding were not considered to be viable technologies.
Laboratory studies indicated that alkaline-surfactant-polymer, surfactant-polymer, polymer, and CO2 flooding show potential to recover incremental oil. Alkaline-surfactant-polymer, surfactant-polymer, and polymer flooding technologies recovered up to 35% OOIP incremental oil in dead oil and live oil corefloods. CO2 was miscible at reservoir pressure while N2 was not. In the laboratory, polymer flooding showed incremental oil and Low Salinity flooding did not. These results were not consistent with the original screening observations, thereby emphasizing the importance of laboratory studies.
Improving Reservoir Exploitation Using Fast Geomechanical Modelling Coupled With Surface Displacement Data Assimilation
Authors: Candela T. , Osinga S. , Veer E. F. , Heege J. H. , Fokker P. A. 
Published: May 2017

Abstract
One way to improve our understanding of the reservoir behavior at depth is to analyze the ground surface response during reservoir exploitation. During reservoir exploitation, pressure changes can lead to compaction/dilation at depth resulting in ground surface displacements. Disentangling the information encrypted in the surface displacement data should therefore provide information about the reservoir behavior at depth. In the last decade we developed a workflow imbricating fast geomechanical forward models and a surface displacement data assimilation scheme to improve our (i) understanding of the subsurface processes and (ii) improve predictions of reservoir behavior in terms of reservoir management. Here we present two case studies to illustrate the versatility and robustness of the workflow. The first case study identified undepleted gas compartments in a strongly faulted and compartmentalized reservoir in a Dutch gas field through inversion of combined surface levelling and InSAR data. The second case study constrained spatial variation in aquifer activity around another Dutch gas field by directly employing ascending and descending PS-InSAR line-of-sight data. We also show the benefit of using multiple data assimilation for constraining parameters in forward models that contain non-linearity. Additionally, we present a novel approach for an inversion workflow that includes uncertainties in every step of the inversion process in a single integrated inversion procedure.