bluuebunny/crossref_metadata_2025_split huggingface dataset:
Kültür Kanıtlı Geç Neonatal Sepsis Olgularında Sıklık, İzole Edilen Mikroorganizmalar ve Antibiyotik Direncinin Araştırılması
Authors: GÜMÜŞ Hüseyin , KAZANASMAZ Halil 
Published: October 2018

Amaç: Yenidoğan sepsisine neden olan etkenler ve
antibiyotik dirençleri ünitelere göre farklılık gösterebilmektedir. Bu çalışma yenidoğan yoğun bakım kliniğimizde
sepsis tanısıyla takip edilen bebeklerin
demografik özellikleri, risk faktörleri, etken mikroorganizmaları ve antibiyotik
dirençlerinin araştırılması amaçlanmıştır.Gereç ve Yöntem: Ocak 2015 ile Mart 2018 tarihleri arasında hastanemiz
yenidoğan yoğun bakım ünitesinden mikrobiyoloji
laboratuvarına gönderilen 4156 kan kültürü otomatize kan kültürü sistemi ile
değerlendirilmişti. İzole
edilen mikroorganizmaların antibiyotik duyarlılık testleri Kirby-Bauer disk difüzyon
yöntemi ile yapılmıştı. Kültür pozitif neonatal sepsisli olgular çalışmaya
dahil edildi (n=237). Bu hastalar erken başlangıçlı neonatal sepsis (ENS) ve geç başlangıçlı neonatal sepsis (GNS)
olmak üzere iki gruba ayrıldı. Olgular doğum
ağırlığı ve haftası, cinsiyet, risk faktörleri, klinik ve laboratuvar
bulguları, kan kültürü, etken mikroorganizma ve antibiyotik direnci yönünden
incelendi.Bulgular: Çalışma döneminde sepsis şüphesiyle bakılan 4156 kan kültürünün
237’inde (%5,7) üreme görüldü. Sepsis tanısı alarak
tedavi gören 237 bebek çalışmaya dahil edildi. Olguların 150’i (%63,2) geç
neonatal sepsis, 87’si (%36,7) erken neonatal sepsis tanısı almış olup, 114 olgu (%76) prematüre
idi. Kültürlerde en sık üreyen mikroorganizmalar Klebsiella pneumoniae (%39,3), Koagülaz negatif stafilokok (%14,0),
Escherichia coli (%13,3), ve Acinetobacter baumanii (%10,0) idi.Sonuçlar: Geç başlangıçlı neonatal sepsis
etkenlerinin zaman içinde değişmesi ve dirençli mikroorganizmaların giderek
artması önemli bir sorundur. Bu nedenle her yenidoğan ünitesi geç neonatal sepsis
risk faktörlerini, sık görülen etkenleri ve antibiyotik dirençlerini tespit
ederek, başlangıç ampirik antibiyotik tedavi planının yapılması önemlidir.
THE DETERMINANTS OF HEDGING AND FIRM VALUE: An Empirical Study in Mining Companies Listed on Indonesia Stock Exchange
Authors: Irawanti Garnis 
Published: October 2018

<p class="Keywords">This study aims to determine the determinant factors in the company's hedging decisions and to determine whether the activities of corporate hedging decisions through derivative instruments provide increased value for the company. The sample consisted of 33 mining companies listed on Indonesia Stock Exchange during 2011-2015 period. The method used in this study is logistic regression and independent sample t-test. The result of logistic regression by using variable of financial distress, underinvestment cost, and size showed a positive correlation to corporate hedging decision. Meanwhile, by using an independent sample t-test found that the company's hedging decisions significantly affect the value of firms and the companies with hedging decision activity through derivative instruments have more superior value than companies by using natural hedging decisions.</p><p> </p>
Optimization of two-stage cooling conditions for wire rod diameter 5.5–6.5 mm of low-carbon steel grades in order to ensure the required degree of descaling mechanically before its subsequent processing
Authors: Savinkov V. V. , Kovaleva I. A. 
Published: October 2018

With the aim of obtaining scale with a high degree possibility of mechanical removal under the conditions of the section rolling shop No. 1, at the mill «150» JSC «Belarusian Metallurgical Works – Management Company of Holding «BMC» developed technological modes of production of wire rods made of low-carbon steel grades.The peculiarities of scale formation were studied, namely, the factors influencing the removability, obtaining the optimal thickness and its phase components on the wire rod diameter 5.5–6.5 mm in the cooling process immediately after rolling, intended for wire production.To obtain the necessary ratio of the phase constituents of the scales on the surface of the wire rod, the following factors was taken into account: the temperature of the layout of the turns on the roller table in the air cooling line; (uniformity along the length of the turn), the cooling conditions of the helix of the turns (prevention of the 4FeO = Fe3O4-Fe decay), where the condition of cooling the wire rod from 600 to 250 °С, not exceeding 100 s, must be observed.The results of metallographic studies of scale on the wire surface are presented. The introduced technological regimes provided the optimal thickness and the FeO / Fe3O4 ratio after the experimental rolling of the metal. Exhausted cooling regimes allowed to reduce the consumption of fiber for all types of wire.
Overview of test methods to determine strength and plastic properties of the wire
Authors: Kukharenko M. A. , Mokhoreva V. A. 
Published: October 2018

The article presents various methods for determining the strength and plastic properties of the wire to assess the quality characteristics of the products produced in the steel shops of JSC «BMW – the Management Company of the Holding «BMC».The methods of determining the propensity of a thin wire to laminations by reversing the twisting («Swedish» twist) and unilateral twisting, fixing the length change of the sample with a prefix with the dial indicator are considered. The article describes the procedure and results of research to determine the effect of the ratio of the conditional yield strength to the time resistance of the rupture on the plastic properties of the wire, the type of tensile diagram of the wire fragility.
Community Consensus: Volunteerism - Of Promoters and Promises
Authors: Spady Darcy 
Published: October 2018

President's column
SPE can help small companies navigate financial understanding
Half of my career has been in the producer side of the business and the other half with a service company. The service experience has been with large organizations. It’s rather a nice place to be. My producer experience has been primarily with tiny, small, and intermediate companies.
The experience quite literally has highs and lows. Imagine a cartoon character jumping off a cliff—at first, you feel like a bird but as the ground approaches you are terrified and shortly thereafter you are quite compact, so to speak. I have had moments of pure euphoria as a small producer (usually the 15 minutes after a capital raise or a sale event), but more often it is panic, terror, and a lot of out-of-control times when you wished you had a finance degree or two.
It may not seem intuitive, but engineers need to understand financial matters, and that’s where SPE comes in, with connection opportunities to places other than your technical discipline. There are a lot of us technical types trapped or living in the small cap producer world or technical innovator space. We don’t get much support at technical conferences. We don’t get much time to do technical things. Little producers are very often forgotten. Small technology providers rarely get love, and often they have little time allotted to pitch their idea. I’m going to pay some attention to that group in this column. I’m going to promise some good things in the future.
Early in my career—when the local price of oil was less than $10/bbl and the future was extremely bleak—I was fortunate enough to encounter people who held very lofty positions and took the time to care about this lonely new grad. In the early 1980s, Gerry Maier O.C. (the Order of Canada) was president and CEO of TransCanada Pipelines, a large public company located in an office towering above Toronto’s financial district. I was a struggling new grad working on the periphery of the industry, but Maier took me under his wing. He gave me all the attention I needed to discuss establishing a petroleum engineering chair at the University of Alberta, our alma mater. Even after all these years, Maier has not forgotten that meeting. He has met with other CEOs, Canadian prime ministers, and even royalty, yet Maier remembers that meeting with me.
He has no idea how it kept me going at one of the darkest moments of my career. He remembered the little guy. To this day, I try to pay back that generosity by modeling that behavior.
For example, I hope that Tarun Kumar from UPES in Dehradun, India, is encouraged for life because I took the time to encourage him, after disagreeing strongly with a technical point he made in a student paper competition. Maybe someday he will be involved in a small cap Indian producer listed on the Mumbai exchange.
Guest Editorial: Higher Capability, Lower Costs With Cloud Subsurface Data Management
Authors: Neely Joe , Upadhya Vasuki 
Published: October 2018

Guest editorial
Lower oil prices, lack of experienced personnel, and uncertainty about long-term global oil and gas demand are driving petroleum companies to seek new ways to improve operational capability and lower costs. Cloud subsurface data management has the potential to allow standardized data acquisition, improve data integration and quality, and catalyze data analytics—all at a lower cost than traditional methodologies.
Many challenges are involved in acquiring, analyzing, and managing subsurface data. Why is subsurface data so different from other domains? Subsurface comprises many complicated data types, including well logs, core analyses, geologic interpretations, and more.
Each data type is complex and requires an experienced subject matter expert (SME) to deal with data acquisition, formatting, and managing. In addition, the subsurface data must be aggregated into a business context to be useful to the daily operational business. IT and domain SMEs must collaborate to ensure that data are always correct, integrated, and accessible. To be effective, a subsurface data manager must have a strong blend of domain and technical capabilities.
The minimum level of qualification for a position in data management requires a degree in a relevant discipline such as geoscience, engineering, or information technology. Candidates must capably handle multiple operating systems such as Windows and Linux, and should understand company-specific software at a base level.
The technical requirements of subsurface data management are significant. Candidates should know how to script in AWK, sed, Perl, or Python, and additional scripting languages can’t hurt. Lastly, candidates must under-stand management from both a technical perspective—in understanding quality control and juggling multiple data bases—and from a people perspective, in possessing excellent communication skills and handling team personalities. With so much required of those in subsurface data management, the result is a complicated landscape that changes from one business unit to another and evolves through time.
With the advent of data analytics, the subsurface data manager’s responsibilities have increased. Analytics cannot thrive unless there is good data on which to act. The broadening subsurface workspace, coupled with the large legacy application set and increasing amounts of information, creates a critical problem. Continuing with the same issues and proprietary software is not the answer: A new way of thinking is required.
Why Cloud Platforms Work
Utilizing a cloud platform solution for subsurface data can lower infrastructure and support costs while simultaneously providing a platform for all structured and unstructured data along with a col-lection of best-in-class applications for managing and acting on the data to create business value.
Technology Update: Characterizing a Coal-Seam Gas Reservoir by Interpreting Permanent DTS Data
Authors: Oguche Iko , Konopczynski Michael 
Published: October 2018

Technology Update
In Australia’s Surat Basin, gas is contained in hundreds of coal seams, which have highly variable properties and are grouped into four distinct reservoir zones of similar qualities. Economically producing these wells from multiple reservoir units is generally favored and as a result, understanding the relative contribution to production by different zones at different times in the well’s life—and whether production is dominated by a single zone—adds value to planning future wells.
The well designs are quite simple. An 8.5-in. wellbore is drilled from surface casing through the target coal seams. A 7-in. production casing and preperforated liner with an external casing packer and a cement stage tool is run to total depth. The external casing packer is deployed at the top of the reservoir, and the 7-in. casing is cemented in place through the stage tool above the packer. No external packers are installed between groups of coal seams (zones) to segregate production from each zone through the preperforated liner.
Production tubing is installed in the well, which typically runs to the base of the preperforated liner, and a progressive cavity pump (PCP) is installed in the tubing to lift the water produced with the coal-seam gas (CSG) [dewater the well]. Gas production comes from the coal seams and flows around and through the preperforated liner, then up through the annular space, between the production liner/casing and the production tubing, to surface. The water flows to the bottom of the completion, where it is lifted up the production tubing by the PCP as shown in Fig. 1.
Understanding Zonal Allocation
Normally, production logging tools (PLTs) are run to obtain an understanding of zonal allocation in commingled wells. However, running PLTs in CSG wells can be expensive as it requires the PCP to be pulled out and the well to be lifted with gas. The switch to gas lift at shallow depth is not a normal operating condition and may affect the result.
An additional issue is the unsegregated, openhole completion. With no external packers, neither the PLT tools nor the distributed-temperature sensor (DTS) fibers inside the liner can measure flow in the space between the liner and the sandface.
Technology Focus: New-Frontier Reservoirs I (July 2018)
Authors: Chipperfield Simon 
Published: October 2018

Technology Focus
Recently, a lot of discussion has revolved around the benefits of multilaterals in unconventional reservoirs. But is this truly the next breakthrough for the industry, or is it all hype?
No doubt enormous need exists for a technology such as this to improve reservoir recovery and reduce well cost.
The current modus operandi in many plays is to drill horizontal hydraulically fractured wells. The results, however, continue to show that these well types are not effective at draining the reservoir. This is a result of complex hydraulic-fracture geometries with very short propped heights and lengths. Fracture complexity is a natural phenomenon now proved by coring and is likely caused by reservoir stratigraphy and geomechanics. Completion engineers typically counteract this, to some degree, by pumping more fracture treatments in the horizontals. This ineffective drainage points to the benefits of greater reservoir contact with a multilateral.
As well as improved drainage, multilateral technology also can reduce well cost by avoiding the necessity to drill top hole for the second (or third) lateral and requiring only one completion and one set of surface equipment.
Multilateral technology has been around for many years; however, what has changed in recent times is the reliability of these systems, with more than 98% reliability quoted in a recent publication. Hydraulically fracturing the laterals is now possible as well.
Companies such as Occidental, BP, and ConocoPhillips are evaluating the potential of this technology in onshore unconventional plays. In fact, in the fourth quarter of 2017, Occidental successfully performed its first pilot.
Enormous need for this technology exists, and time will tell whether it is the next major step in subsurface technology to improve the unit cost of production.
Recommended additional reading at OnePetro: www.onepetro.org.
SPE 188231 Modeling Early-Time Rate Decline in Unconventional Reservoirs Using Machine Learning Techniques by Aditya Vyas, Texas A&M University, et al.
SPE 186107 Optimization of Spacing and Penetration Ratio for Infinite-Conductivity Fractures in Unconventional Reservoirs: A Section-Based Approach by S. Liu, Texas A&M University, et al.
SPE 186092 Rate Dependence of Bilinear Flow in Unconventional Gas Reservoirs by M.S. Kanfar, University of Calgary, et al.
Coalbed Methane Prospects in Indonesia
Authors: Carpenter Chris 
Published: October 2018

This article, written by JPT Technology Editor Chris Carpenter, contains highlights of paper SPE 186343, “Review of Coalbed Methane Prospects in Indonesia,” by C. Irawan, D. Nurcahyanto, I.F. Azmy, J.A. Paju, and W.M. Ernata, SKK Migas, prepared for the 2017 SPE/IATMI Asia Pacific Oil and Gas Conference and Exhibition, Bali, Indonesia, 17–19 October. The paper has not been peer reviewed.
In 2005, two companies began studying the potential of seismic operations for the Kutai and South Sumatra basins (Fig. 1). However, the progress of coalbed-methane (CBM) operations has been slow for several reasons. This paper reviews the efforts to exploit CBM resources in Indonesia, the challenges these efforts have faced, and possible solutions that can make operations more efficient and profitable.
Introduction
Despite the current industry climate, operators in Indonesia continue to pursue CBM production opportunities. The Indonesian government has stipulated in its contracts with these companies that current operations must yield production within a set time frame, highlighting the importance of making such operations cost-effective.
Currently, many methods are avail-able to drill CBM wells. In early efforts to exploit CBM wells, contractors used conventional methods to drill a well at a target depth of 500 to 800 m at a high operational cost, but time frames were not met. Of 51 exploration contract areas involving CBM in Indonesia, only 17% of these have fulfilled their commitment. Obstacles that prevent success in these endeavors are often nontechnical in nature, including organizational difficulties (suboptimal financial conditions of operators), land- and permit-acquisition issues, challenges in community relations, gaps in the supply chain, and problems with access and infrastructure. Standard operating procedures (SOPs) are difficult to formulate and implement under these conditions. The CBM well must follow industry operational standards, which, when com-pared with standards involved in the mining industry, for example, involve a higher level of technology and the need for more permits and, thus, a greater cost.
Indonesia CBM Contract Area Indonesian unconventional prospects are essentially divided into two areas, Sumatra and Kalimantan. These areas contain the most abundant coal-seam prospects. However, proved resources do not equal the estimated resources calculated more than a decade ago.
Geologically, target coal seams in the Sumatra and Kutai basins differ only in their depth. The target coal seams in Sumatra are shallower than those in the Kalimantan region. In both basins, the cost per well is high.
Technology Focus: CO2 Applications (July 2018)
Authors: Kokal Sunil 
Published: October 2018

Technology Focus
In my previous features, I discussed the challenges facing carbon dioxide (CO2), both technical and economic. By far the biggest use of CO2 is in enhanced oil recovery (EOR). In this feature, the focus is on overcoming the biggest challenges facing CO2 EOR—gravity override and mobility.
When CO2 is injected into a reservoir, it has a tendency to rise and segregate to the top of the reservoir, thereby bypassing some of the remaining oil. This is primarily because of the density difference between CO2 and reservoir fluids. CO2 also fingers through the oil because of its high mobility and lower viscosity. One way to control CO2 mobility and improve its sweep efficiency (and thus improve the incremental oil recovery) is by injecting a CO2 foam or CO2 emulsion. The foam, because of its high viscosity, diverts the CO2 away from the paths already created and conforms it to previously bypassed areas of the reservoir. It does so by blocking the flow channels, thus improving reservoir sweep.
During the past several decades, and especially the last few years, consider able effort has been made to address this challenge. Most of this research has been in either viscosifying or densifying the CO2. Some of the mobility- and conformance-control methods that have been tried include surfactants that create CO2 foams, direct thickening of CO2 using polymers and gels, and nanoparticle-stabilized CO2 foams.
Some of the leading research on CO2 foams/emulsions is being carried out by, in no particular order,
George Hirasaki’s group at Rice University
Quoc Nguyen’s group at The University of Texas at Austin
Texas A&M University
Delft University of Technology
Robert Enick’s group at the University of Pittsburgh
Arne Graue at the University of Bergen
IFP Energies Nouvelles in France
The papers that follow are meant to be a starting point for understanding this phenomenon and further research. The focus in the coming months and years should be on extending the field deployment of this emerging technology.
Recommended additional reading at OnePetro: www.onepetro.org.
CMTC 486622 Surfactant and a Mixture of Surfactant and Nanoparticles Stabilized CO2/Brine Foam for Gas-Mobility Control and Enhanced Oil Recovery by Z.A. AlYousef, Texas A&M University, et al.
SPE 190176 Fluoroacrylate Polymers as CO2-Soluble Conformance-Control Agents by Robert M. Enick, University of Pittsburgh, et al.