bluuebunny/crossref_metadata_2025_split huggingface dataset:
Aspekte einer evidenzbasierten Therapie klinischer Mastitiden
Authors: Mansion-de Vries E. M. , Hoedemaker M. , Krömker V. 
Published: September 2015

ZusammenfassungDie Mastitis ist eine der häufigsten und kostenintensivsten Erkrankungen der Milchrinder. Die Entscheidung über die Therapie klinischer Mastitiden erfolgt meist ohne Kenntnis der Ätiologie und ist dadurch nur bedingt evidenzbasiert. Die evidenzbasierte Medizin beruht im Wesentlichen auf der Kombination des eigenen klinischen Sachverstands mit Erkenntnissen aus der Wissenschaft. Diese Erkenntnisse sind in der Mastitistherapie meist erregerabhängig, weshalb bei einer evidenzbasierten Therapieentscheidung die Erregeridentifizierung als Basis für die Berücksichtigung wissenschaftlich geprüfter Therapiekonzepte dienen sollte. Die Arbeit gibt auf der Basis einer Literatur-zusammenfassung Hinweise für die evidenzbasierte Therapie klinischer Mastitiden. Die Autoren kommen zu dem Schluss, dass bei der Mastitistherapie unabhängig vom Erreger immer eine antiphlogistische Therapie mit einem nichtsteroidalen Antiphlogistikum durchgeführt werden sollte. Die Wahl der antibiotischen Therapie ist jedoch sehr vom mastitisverursachenden Erreger, dem klinischen Bild und dem Tier abhängig. Grundsätzlich sollte die lokale antibiotische Mastitistherapie bei leichten und moderaten Mastitiden gewählt werden. Zu bedenken ist aber, dass der Nutzen einer antibiotischen Therapie bei Coliformen-Infektionen fragwürdig ist und es bei Kenntnis des Erregers durchaus vertretbar scheint, den Verzicht auf eine Antibiose in Erwägung zu ziehen. Bei schweren, also fiebrigen Mastitiden sollte eine parenterale Antibiose gewählt werden. Eine Verlängerung der antibiotischen Therapie über die in der Regel vom Hersteller empfohlene dreimalige Gabe hinaus erwies sich lediglich bei Streptokokken-Infektionen als sinnvoll. Die Entscheidung über eine verlängerte antibiotische Behandlung sollte deshalb erst nach Kenntnis des mastitisverursachenden Erregers getroffen werden. Bei der Wahl des Wirkstoffs sollte – hinsichtlich der Therapie von Staphylokokken oder Streptokokken – auf Schmalspektrum-Antibiotika aus der Gruppe der Penizilline zurückgegriffen werden.
Learner Inclinations to Study Computer Science or Information Systems at Tertiary Level
Authors: Jacobs C , Sewry D A 
Published: September 2015

After the so-called “dot-com crash” of the Internet in the early 2000s, tertiary level student enrolments in IT-related
subjects began to experience a significant decline both in international countries and South Africa. The paper replicates
research done in the Western Cape, South Africa, by Seymour et al. (2005) [20], in which grade 12 learner inclinations to study Computer Science (CS) and Information Systems (IS) at tertiary level were analysed and underlying factors affecting their interest in the subjects were determined. The study analyses the “misguided” perceptions that learners and students have of these subjects; the implications of the decline in enrolments on students, educational sectors and industry; and determines a set of underlying factors that influence learners in their attitudes toward further degrees in IT, starting from the secondary level of education.

The research compares South African Eastern Cape learner perceptions with those from the Western Cape study and establishes three to four years later, that the reasons behind the decline in IT enrolments are still influenced by an underlying demographic and digital divide.
An exploration of Deaf telecommunication processes and associated social issues in South Africa
Authors: Liebenberg Marisa , Lotriet Hugo 
Published: September 2015

This paper presents the results of an exploratory investigation into telecommunications practices and challenges among the Deaf in South Africa.

Telecommunication products like cell phones, TTY’s, sMessage terminals, e-mail, fax messaging, instant messaging (IM) were
some of the technologies investigated. The research shows that the Deaf considers IM as the most successful technology for both business and social communication. E-mail was rated most often used for business communication, where as e-mail and SMS were rated most used for social communication. The main drawbacks experienced by deaf users of telecommunications technologies related to connecting with and understanding of people.

The research findings indicate that the Deaf would like to see heightened public awareness of deafness and its challenges in
telecommunication.
Efficient Compositional Simulation with Locally Lumped EOS Characterization
Authors: Fleming Graham , Wong Terry 
Published: September 2015

Abstract
Equation-of-state (EOS) fluid characterization is used to model the behavior of hydrocarbon reservoirs when variation in the fluid composition has a significant influence on the recovery of hydrocarbons. Examples are miscible gas-injection processes, where mass transfer between the injected gas and in-situ hydrocarbons can result in the injected fluid developing into a fluid that is miscible with the in-situ hydrocarbons, or gas-condensate fluids, where the liquid yield varies with pressure and composition as the reservoir depletes. For many reservoirs, more than one recovery mechanism is employed. For example, insufficient supply of miscible injectant might result in part of a reservoir employing miscible injection, while part is under waterflood. In such cases, accurate prediction of recovery for the miscible injection area might require an EOS characterization with a large number of components, while the phase behavior in the waterflood area could be modeled with sufficient accuracy with many fewer components. Phase-behavior calculations become much more computationally expensive as the number of components increases, but current commercial reservoir simulators must use the same number of components everywhere in the reservoir model. Thus, the requirement to use a large number of components to model the recovery process in part of the reservoir results in a large computational penalty in regions of the reservoir where a smaller number of components would suffice.
In this paper, we describe a method whereby the fluid can be locally lumped for phase-behavior calculations so that regions that are able to maintain sufficient compositional accuracy with fewer components can use less-expensive EOS calculations. Different lumpings can be used at different times in the life of the reservoir, as compositional effects become more or less important in different regions in the reservoir. Example problems that demonstrate the flexibility, efficiency, and consistency of the method are explored.
Performance Step Change: Optimized PDC Design for Directional Drilling Application Increases ROP by 39% Drilling Difficult Hard/Interbedded Formations in Northern Kuwait
Authors: Al-Khaldy M. D. , Al Failakawi K.. , Al-Mulaifi M.. , AlRashidi A.. , Nair P.. , Hassan S.. , Ghoneim O.. 
Published: September 2015

AbstractConstructing the 12¼” direction hole section through approximately 3000ft of difficult interbedded lithologies (Mutriba-Lower Burgan) in northern Kuwait presents a number of distinct challenges. In the upper portion of the hole section, a PDC bit must penetrate medium to hard carbonate and shale formations with compressive strength ranging between 9-12 kpsi with peaks up to 30kpsi. Next, a challenging abrasive sand with compressive strength between 6-9kpsi requires an RSS/PDC assembly to reach TD. The operator experimented with several different bit designs attempting to efficiently achieve directional objectives and improve borehole quality with limited success. Issues with baseline designs included lack of cutting structure durability and low ROP.To accomplish the operator's objectives, the engineering team analyzed all relevant offset data and concluded an existing 12¼” six-bladed bit with 16-mm cutters would serve as the starting point for an optimization effort. The bit's design data was fed into an FEA-based modeling system. Formation characterization software was then utilized to select the appropriate rock samples to simulate the field formations in the laboratory. Multiple simulations were run to determine the best combination of technologies to achieve the objectives. A new 12¼” directional design (616-type) would include premium cutters that can withstand impact in the interbedded carbonate/shale section and remain sharp while drilling the lower sand formations to TD. The bit also features a torque limiting feature in the blade top and TSP inserts in gauge to ensure hole quality. Next, a series of simulations were preformed to observe how different RPM and WOB values would affect vibration and torque levels. The results were plotted to create a smooth drilling parameter window to maximize the new bit's ROP potential.The new bit design was run on RSS with PDM assist and set a new ROP record of 46 ft/hr, 39% faster than the best offset of 33 ft/hr and 68% higher than the five-well offset average (27.3 ft/hr). The bit met all directional objectives (5-6° DLS) and was pulled in excellent dull condition (0-1-WT). The authors will discuss the bit design and selection process in addition to the HTHP cutter technology which saved the operator 2.5 days of rig-time and associated costs.
Removal of Ilmenite Oil-based Filter Cake under HP/HT Conditions Using Hydrochloric Acid
Authors: Xiao J.. , Nasr-El-Din H. A. , Al-Bagoury M.. 
Published: September 2015

Abstract
Oil-based drilling fluids using a micronized ilmenite (5 µm) as weighting materials are proved to be suitable for HP/HT drilling operations with good rheological properties, low sag tendency, and low filtration volumes, even after heating at 400°F for 16 hours. The objective of this study is to assess the efficiency of hydrochloric acid to remove ilmenite oil-based filter cake, and therefore remediate any damage that might occur during its use in drilling operations.
An oil-based drilling fluid containing micronized ilmenite with 1.9 S.G. was used for filter cake formation. A HP/HT filter press was used for the removal process of ilmenite oil-based filter cake. Prior the acid removal, a mutual solvent (10 vol%) was used to break the oil-based filter cake for 2 hours. The purpose of the use of a mutual solvent is to remove the oil-soluble components and change the wettability of oil-based filter cake. Berea sandstone cores with an average porosity of 18 vol% and an average permeability of 50 md were used. CT scan, XRD, SEM, and chemical analysis were used to examine the reaction characteristics of different concentrations of acid with ilmenite oil-based filter cake. Coreflood tests with different concentrations of HCl were also conducted to provide recommendations on how to remove the internal damage caused by oil-based drilling fluid invasion during drilling operations.
Results showed that ilmenite oil-based filter cake can be successfully removed at 300°F after soaking with 5 wt% hydrochloric acid for 4 hours, even without causing much damage to the core permeability. The filter press test showed that the retained permeability of Berea sandstone cores was more than 90%. In the core flood tests, with the increment of the HCl concentration from 5 to 15 wt%, more internal damage could be removed. There was even some stimulation effect with 15 wt% HCl. This study will provide a complete evaluation of the efficiency of hydrochloric acid in removing ilmenite oil-based filter cake for HP/HT applications.
Overcoming High-Temperature Logging Challenges While Staying Cost-Effective for a Tight Gas Project in the Sultanate of Oman
Authors: Briner Andreas , Ketabchi Iman , Nadezhdin Sergey 
Published: September 2015

Abstract
Data collection throughout the exploration stage is of paramount importance, especially for the unconventional projects. Since a vast amount of data is acquired through the well logging, large logging expenditures are usually incurred. In unconventional projects, marginal economics dictate particularly strict budget strategies, including expenditures for logging activities. A significant component of the logging costs is associated with the tool temperature rating. In northern Oman, the bottomhole static temperatures of the tight sandstone gas formation being explored are 175°C [347°F] or higher, which coincides with the upper limit of the conventional logging tools. It has been observed that the tool failure frequency increases dramatically when this limit is approached, leading to repeated logging jobs or regretted (missed) data. The simple way to increase the temperature rating of logging tools to perform at high bottomhole temperatures is to use ceramic electronic boards. However, the cost of this solution is roughly 10 times higher than standard tools. Slightly less costly is acquiring data with logging-while- drilling techniques; this has its own disadvantages, such as logging tool availability and data resolution. Another possible approach is careful assessment of the bottomhole temperature at particular times during logging to enable using conventional tools with lower temperature ratings. The assessment is a challenge itself. Direct measurements are difficult because the temperature gauges on logging tools are affected by heat from the electronic components. It is possible to simulate borehole conditions, but this requires extensive modeling and involves many variables such as cooling from mud circulation; heat transfer among the formation, annulus, and drillpipe; conversion of mechanical energy from drilling to heat; and the addition of hot cuttings to mud. That latter modeling has been performed and verified with the field data in various conditions: vertical and horizontal geometries and different mud types. The study established the achievable bottomhole circulating temperatures at various operations, duration of safe temperature window for less-expensive logging, and the bottomhole temperature profile in various drilling scenarios. This allowed delineating a road map for logging future high-temperature wells in the field.
Feasibility of Cyclic and Continuous Steam Injections into a Middle-Eastern Heavy Oil Reservoir: A Simulation Approach
Authors: Mongy Mohamed A. , Shedid Shedid A. 
Published: September 2015

Abstract
Steam injection has been applied successfully worldwide. The main objectives of this simulation study are to investigate the influences of steam quality, steam injection rates, well spacing, and well completion on the performance and oil recovery by cyclic and continuous steam injection modes into a Middle Eastern heavy oil reservoir. The ultimate goal of this study is to design a complete steam injection process capable to provide the highest cumulative oil recovery.
Screening criteria has been applied for the reservoir to select the steam injection as the most appropriate enhanced oil recovery (EOR) method. The geological and fluid models were well-established and used with other reservoir rock, fluid, petrophysical data plus production history data to develop the best history matching for the reservoir under development. The effects of different injection injection rates, well completion and well spacing have been investigated. Heat distribution profile at different injection rates is developed plus water cut curves for different time intervals over 20 years. The influence of different types of well completion of open hole and selected perforated zones are also studied for different numbers of injectors and producers. The steam quality is optimized under different conditions for all proposed scenarios.
The results indicated that the application of the open-hole well completion and the increase of steam injection rate increased the attained production rate for different steam quality and different well spacing. The optimum steam quality is determined and used for different proposed combinations of the above-listed factors in this reservoir. The results also indicated that the application of selected perforation well completion is better than open hole completion because it is proven to provide better heat distribution throughout the pay zone.
The results of this study develop a systematic approach for optimization the application of both cyclic and continuous steam processes considering heat distribution, well completion and variable parameters of the reservoir under development.
Innovative Water Control Technique for Horizontal Wells in Isotropic Reservoirs - Successful Case History From Belayim Field
Authors: El Gogary Ahmed. F. , El-Masry Hossam. H. , Kortam Mostafa. M. , El-Rayek Hany. R. 
Published: September 2015

AbstractHorizontal and highly deviated wells are increasingly being used in oilfield developments worldwide. Large-bore horizontal wells can deliver significantly higher oil production rates than conventional completions, reducing field development costs by allowing reserves to be targeted with fewer wellsRudies formation in Belayim Land field is a bottom water-drive reservoir with a strong supporting aquifer. it is characterized by its great isotropy and heterogeneity where based on the analysis of SCAL data, it was found that the vertical permeability is nearly equal to horizontal permeability raising the problem of water coning(cresting), earlier water breakthrough situation and masking the oil production by water due to the great difference in mobilityBased on calculation of the critical coning production rates and water control plots it was concluded that the horizontal wells drilled in Rudies formation which are produced with high production rates suffered from extreme water coning problems that raised the necessity for water shutoff procedure to be consideredField cases presented on this paper explain applications of internal casing packer and blank tubing as a tail pipe in accompanied with downgrading the production rates from horizontal wells for the purpose of zonal water control in the uppermost section of open hole and slotted liner completed horizontal wells in PetrobelIncluded in this paper are two different field cases for uncemented water shutoff in horizontal wells that succeeded in decreasing the water cut in the wells from the range of (90-95 %) to the range of (10-30%) implementing a huge increase in the gained net oil towards achieving the maximum recovery. Technical data including well configuration, production performance and casing string are included in the paper. Field operations and lesson learned from each application are also presentedinthispaper
The Investigation of Tight Reservoir Responses to Induced Hydraulic Fracturing – With the Use of Analytical and Numerical Analysis
Authors: Dahroug Ahmed , Cosgrove John , Bachiri Salim 
Published: September 2015

AbstractTight gas reservoir development has long been affected by 1) complex flow profiles and 2) the impact of very low permeability on reservoir productivity. Where well tests (WT) buildup is very short, interpretation becomes difficult and results often are ambiguous. Most WT of tight, dry gas wells are of short duration; thus, such tests typically lead to multiple interpretations and open-ended conclusions. Adding to the complexity, simulation software packages often fail to adequately model flow in fracture networks.A series of well tests were conducted in tight sandstone, dry gas, naturally fractured reservoirs post-induced hydraulic fracturing. The tests were conducted for long durations: 100 hours in most cases, and 1,000 hours in two extended well-test cases. The WT responses from these tests were ambiguous.We have investigated possible direct causes of the ambiguous results, including wellbore, geology, and specific well conditions. However, because the WT response has been found repeatedly in a variety of regions around the world, it may not be related to any of these.After investigating in multiple manners, including the use of simulation software, we argue that the anomalies in the WT response may reflect a step in the scale-dependent properties of the fracture network.
Oil Shale in Upper Egypt and it’s Economics
Authors: Salam Mahmoud Abdel , AbdulGhaffar Mostafa 
Published: September 2015

Abstract
The term oil shale generally refers to any sedimentary rock that contains solid bituminous materials (called kerogen) that are released as petroleum-like liquids when the rock is heated in the chemical process of pyrolysis. Oil shale was formed millions of years ago by deposition of silt and organic debris on lake beds and sea bottoms. Over long periods of time, heat and pressure transformed the materials into oil shale in a process similar to the process that forms oil; however, the heat and pressure were not as great. Oil shale generally contains enough oil that it will burn without any additional processing, and it is known as “the rock that burns”.
Oil shale can be mined and processed to generate oil similar to oil pumped from conventional oil wells; however, extracting oil from oil shale is more complex than conventional oil recovery and currently is more expensive. The oil substances in oil shale are solid and cannot be pumped directly out of the ground. The oil shale must first be mined and then heated to a high temperature (a process called retorting); the resultant liquid must then be separated and collected. An alternative but currently experimental process referred to as in situ retorting involves heating the oil shale while it is still underground, and then pumping the resulting liquid to the surface.
This work focus on oil shale as energy resource unused in Egypt with about 8 billion bbl oil reserves, require a new technology, not existed in Egypt with high operating costs.
It answers the following questions: is the conditions and oil price suitable for start-up of oil shale project in Egypt to be accepted by Ganope (Holding company related to the Egyptian ministery of petroleum) and the investor. If not, what is the minimum oil price required for the project to be attractive, with which concession agreement terms.
Abu Madi Reservoirs-Evaluation of Level-III Remaining Gas Potential, Abu Madi And El Qara Fields
Authors: Nassar Mohamed , Matresu Justin , Talat Amr , Hasan Motaz 
Published: September 2015

Abstract
Nile Delta Basin is a mature gas producer in Egypt, from the early sixties till present many gas discoveries were made in both on & offshore areas in the Pliocene and Miocene reservoirs. The first gas field, Abu Madi Field, was discovered onshore Nile Delta in 1967, by AGIP (IEOC) with the drilling of the Abu Madi-1 (AM-1) well. The Abu Madi field started to be developed since 1970, it's producing wells increased to 21 and by end-1992, the field had a capacity of 400 MCF/d; being that time the biggest gas field in Egypt. Subsequently of the gas-bearing reservoir discovered in Abu Madi Formation (Late Messinian) - becomes one of the main targets in on and offshore area of Nile Delta. The stratigraphic framework of the Abu Madi Fm., was reveal through years, now a days this formation is considerate as a sedimentary infilling of a fluvial paleovalley characterized by stacked fluvial-deltaic sandstone and shale's. The classical Abu Madi Fm., lithostratigraphic layering comes from the Abu Madi/El Qaraa fields where the reservoirs sandstones levels have been named, starting from bottom, as follows: Level 3 (Lower, Main, Upper and 3A), Lev2 and Lev 1. The recently wells targeting the Lev 3 Main and Lev 3A reservoirs did not achieved the estimated remaining recoverable resources. In this study the new 3D seismic data, production history and petrophysical data were integrated in order to relocate the unachieved residual OGIP and also to find new drilling opportunities for additional potential resources.