bluuebunny/crossref_metadata_2025_split huggingface dataset:
Regulation of CTP Synthase Filament Formation During DNA Endoreplication in Drosophila
Authors: Wang Pei-Yu , Lin Wei-Cheng , Tsai Yi-Cheng , Cheng Mei-Ling , Lin Yu-Hung , Tseng Shu-Heng , Chakraborty Archan , Pai Li-Mei 
Published: October 2015

Abstract
CTP synthase (CTPsyn) plays an essential role in DNA, RNA, and lipid synthesis. Recent studies in bacteria, yeast, and Drosophila all reveal a polymeric CTPsyn structure, which dynamically regulates its enzymatic activity. However, the molecular mechanism underlying the formation of CTPsyn polymers is not completely understood. In this study, we found that reversible ubiquitination regulates the dynamic assembly of the filamentous structures of Drosophila CTPsyn. We further determined that the proto-oncogene Cbl, an E3 ubiquitin ligase, controls CTPsyn filament formation in endocycles. While the E3 ligase activity of Cbl is required for CTPsyn filament formation, Cbl does not affect the protein levels of CTPsyn. It remains unclear whether the regulation of CTPsyn filaments by Cbl is through direct ubiquitination of CTPsyn. In the absence of Cbl or with knockdown of CTPsyn, the progression of the endocycle-associated S phase was impaired. Furthermore, overexpression of wild-type, but not enzymatically inactive CTPsyn, rescued the endocycle defect in Cbl mutant cells. Together, these results suggest that Cbl influences the nucleotide pool balance and controls CTPsyn filament formation in endocycles. This study links Cbl-mediated ubiquitination to the polymerization of a metabolic enzyme and reveals a role for Cbl in endocycles during Drosophila development.
Pengadilan Khusus KDRT “Implementasi Gagasan Sistem Peradilan Pidana Terpadu Penanganan Kasus-Kasus Kekerasan Terhadap Perempuan (SPPT-PKKTP)”
Authors: Helmi Muhammad Ishar 
Published: October 2015

Abstract: Court For Domestic violence. Court For Domestic violence is a new idea of the Integrated Criminal Justice System Handling Cases of Violence Against Women (SPPT- PKKTP) to provide justice to the victims of domestic violence, especially women. Given the complexity of issues related to domestic violence led to the need for this institution was formed. Act No. 23 of 2004 on the Elimination of Violence Against Domestic generally can back up women in getting their legal rights, but the implementation of the Act turns instead of criminalizing women victims of violence, especially because law enforcement officials do not consider the relationship between husband, wife and children, in applying this Act. As a result, women victims of violence do not get their rights. Abstrak: Pengadilan Khusus KDRT. Pengadilan Khusus Kekerasaan Dalam Rumah Tangga merupakan sebuah gagasan baru dari Sistem Peradilan Pidana Terpadu Penanganan Kasus-Kasus Kekerasan Terhadap Perempuan (SPPTPKKTP) dalam memberikan keadilan kepada para korban kekerasan dalam rumah tangga khususnya perempuan. Adanya kompleksitas permasalahan terkait kekerasan dalam rumah tangga menyebabkan perlunya lembaga ini dibentuk. Undang-Undang Nomor 23 Tahun 2004 tentang Penghapusan Kekerasan Terhadap Rumah Tangga yang secara umum dapat memback up kaum perempuan dalam mendapatkan hak-hak hukumnya, namun dalam implementasinya ternyata undang-undang tersebut justru mengkriminalisasi perempuan korban kekerasan, terutama karena aparat penegak hukum tidak mempertimbangkan hubungan antara suami, istri dan anak, dalam menerapkan undang-undang ini. Akibatnya, perempuan korban kekerasan tidak mendapatkan hak-haknya. DOI: 10.15408/jch.v1i2.1471
Quality of the bottom sediments in the area affected by mining activities
Authors: Holub Marian , Balintova Magdalena , Singovszka Eva 
Published: October 2015

The remains of human activities may be seen in several places of the landscape in positive or negative form. Probably the most common phenomenon that fundamentally impacts the country is mining activity. The environmental problems caused by mining have attracted a great deal of research attention and led to development of numerous sediment heavy metal contamination assessment methods, including the index method, the dynamic method, the synthesis methods in chemistry, ecology and toxicology, etc.
This research was undertaken in order to determine and analyze selected heavy metals present in sediment samples collected from different sampling localities inside and around water reservoir Ruzin, Slovakia. Reservoir and its inflows are located in the vicinity of region with historical Cu, Fe, Ag, Au-deposit, which was exploited from the 14th century to 1990 and currently causing environmental burden. For the determination of sediments quality different methods (XRD and XRF analysis) have been used.
Based on the obtained data of analysis, potential ecological risk indices were used to study the pollution status of heavy metals in sediments and assess their potential ecological risk to environment.
The calculated potential ecological risk indicates the level of water environment pollution by heavy metals in the sampling localities in the studied area.
Effects of physical treatment of hemp fibers on fiber structure and biocomposite properties
Authors: Schwarzova Ivana , Stevulova Nadezda , Singovszka Eva , Terpakova Eva , Junak Jozef 
Published: October 2015

This article concerning natural cellulose fibers as reinforcement in composite materials in civil engineering. In this paper, the attention is given to industrial hemp specifically to the woody part of hemp plant called hemp hurds. The properties of natural fibers are mainly determined by the chemical and physical composition, such as structure of fibers.
The objective of presented research is to characterize raw and physically treated hemp fibers using Fourier transform infrared spectroscopy method. These natural fibers were used as filler into biocomposites and MgO-cement was used as alternative binder. Physico — mechanical properties (compressive strength, thermal conductivity, absorbability) of prepared composites were determined.
A Comprehensive Study of b-Values for Proven Reserve Estimation Using Hyperbolic Decline for Vertical Commingled Gas Producers in Deep Basin Area of WCSB
Authors: Yu Shaoyong 
Published: October 2015

Abstract
Since its discovery in the 1970's, more than 30,000 dry gas wells (over 90% of them vertical producers) have been drilled within the Deep Basin area of the Western Canada Sedimentary Basin (WCSB). Typically these wells produce from tight to medium-tight formations such as the Paddy, Cadotte, Notikewin, Falher-A, Falher-B, Falher-C, Bluesky, Cadomin and Nikanassin. The permeability of these formations ranges from about 0.001mD to 1.0mD.
In an effort to maximize value, over half of the vertical wells within the Deep Basin have been commingled, producing gas from multiple formations. Every year, reservoir engineers evaluate the Proven (PDP) and/or Proven plus Probable (2P) reserves of these wells using Arps' traditional Decline Curve Analysis (DCA). In regards to hyperbolic declines, many questions frequently arise concerning the choice of b-values. Specifically, some those questions are:What b-value should be selected for wells producing from multiple formations with similar permeabilities?What b-value should be selected for wells producing from multiple formations with differing permeabilities?What is the impact on b-values if the producing layers have different pressure gradients?What is the impact on b-values if the producing layers have different drainage areas?What is the impact on b-values if the producing layers are completed differently?
In the early 90's, Fetkovich had conducted an extensive study on b-values for conventional reservoirs to answer the aforementioned questions. In his study, however, the reservoir permeability that was investigated ranged from 1mD to 1000mD. This paper will discuss a comprehensive study extending Fetkovich's work to much tighter reservoirs with permeability ranging from 0.001mD to 0.1mD. This study has been conducted by simulating the annual reserve review process (using hyperbolic declines to match synthetic data from a commercial reservoir simulator) and has been further validated through practical well examples.
Most importantly, a new formula has been developed to derive b-values for hyperbolic declines. This formula is especially applicable to tight gas reservoirs and will assist in answering the aforementioned questions.
Gas Injection EOR Optimization Using Fiber-Optic Logging with DTS and DAS for Remedial Work
Authors: Fitzel Steve , Sekar BK , Alvarez Domingo , Gulewicz Dale 
Published: October 2015

Abstract
The evaluation of in-flow performance for all stages in pumping, multi-stage fractured horizontal (MSFHW) oil wells is challenging with conventional production logging tools. The successful deployment of fiber-optic sensing technology has been influential in diagnosing gas breakthrough in producing wells of a gas injection EOR project by providing real-time, full well in-flow profiling. The integrated operation of a multi-disciplined team and the outcomes will be described.
An operator commenced a tertiary dry gas injection enhanced oil recovery (EOR) in the Bakken Formation of southeast Saskatchewan, Canada. The pilot project was designed as a 1:8 toe-heel injection pattern, with a one mile horizontal in-fill well supporting eight perpendicular producers. The offset producers are monitored using regular production data and gas breakthrough has been found in certain fracture stages that are in communication with the injector. A program was developed to use real-time fiber-optic DTS and DAS to identify the stages with gas channeling in the producer for corrective action.
Distributed Temperature Sensing (DTS) utilizes the Joule-Thompson (J-T) cooling principle as the gas enters the frac port and expands into the liner, while Distributed Acoustic Sensing (DAS) captured the amplitude and frequency of acoustics from the fluid flow. Simultaneous measurements of DTS and DAS were taken using a hybrid fiber/electric wireline inside coiled tubing. The artificial pumping system was pulled out of the producer and coiled tubing was run to the bottom of the well. Real-time pressure and temperature sensors were run on the end-of the coil and a memory gauge at the bottom of the swab string. The well was stabilized overnight before swabbing and monitoring. A service rig was used to swab the well and establish a draw-down. Live down-hole DTS, DAS and pressure data were logged and monitored at the surface and remotely.
Post-processed data interpretation from three wells in the EOR project will be discussed that shows DTS and DAS logging is a valuable technique in detecting injected gas channeling. The results were effective in making decisions about shutting off the problem stages. DTS was most effective since gas has a higher J-T coefficient compared to oil and water. The DAS data supplemented and confirmed the DTS data. Having real time downhole pressure measurements allowed for regulating the swabbing rates to obtain the desired drawdown pressure.
Gas injection EOR projects can be optimized using fiber-optic sensing while swabbing. It provides a new and effective tool in identifying gas breakthrough for remedial work.
Modeling Production Decline in Liquid Rich Shale (LRS) Gas Condensate Reservoirs
Authors: Khanal A. , Khoshghadam M. , Makinde I. , Lee W. J. 
Published: October 2015

Abstract
Conventional DCA methods, developed for boundary dominated flow (BDF), yield unrealistic values for expected ultimate recovery (EUR) when used for unconventional reservoirs with long-duration transient linear flow. Moreover, the developed model parameters are not functions of reservoir properties and flow mechanisms. Although new models have been developed over the years to predict the linear flow, there is still no good way to forecast long-term performance of gas condensate reservoirs.
In this study, we use decline curve analysis, reservoir simulation and statistical analysis to understand the flow of hydrocarbons in LRS reservoirs and to estimate the ultimate recovery in LRS gas condensate reservoirs accurately. Initially, a synthetic reservoir model was constructed to replicate a limited case history available for the Eagle Ford Shale. Various sensitivities on reservoir parameters and operating conditions were performed to understand their effect on oil and gas EUR's after 30 years of production using design of experiments (DOE) and response surface modelling (RSM). Various decline curve methods were applied to the synthetic data obtained by using pressure normalized diagnostic plots. Results from this study shows that pressure normalization could potentially be used to identify the flow regimes in LRS reservoirs, which is especially true for rate restricted fields. We also observed that the production characteristics of LRS gas condensate reservoirs are highly variable, possibly due to the change in composition via liquid dropout. The approach of using two or more models with different production parameters by isolating the parameters provides a good fit to the data and a realistic estimate of the EUR. Statistical analysis of the reservoir parameters and the EUR shows that there is some relationship among them. Our study shows that these statistically developed co-relations are accurate for the reservoir studied and EUR for other wells in the same field can be obtained with variation of parameters.
We present a methodology which uses empirical decline curve analysis, physics based reservoir simulation and statistical analysis to forecast EUR based on limited production data in LRS gas condensate reservoirs. This study provides considerable insight into the long-term production behavior in LRS gas condensate reservoirs.
Sorption-Dependent Permeability of Shales
Authors: Lopez Bruno , Aguilera Roberto 
Published: October 2015

Abstract
Shale gas reservoirs are fine-grained, organic-rich rocks with a well-developed pore network structure within the organic matter (kerogen). Organic pores in shale reservoirs exhibit small radii in the range of 0.5 to 100 nanometers, which indicate that non-Darcy flow mechanisms are present in these rocks in addition to viscous flow. Gas adsorption/desorption and gas diffusion from solid kerogen are some other important flow mechanisms in shales. Therefore, consideration of these phenomena is crucial for quantification of permeability of shales. A numerical procedure to calculate permeability of shales that accounts for all the above factors is introduced in this work.
During shale's depletion, organic pore radius can change or remain approximately constant depending on the rates of adsorption and desorption. Previous investigations suggest that organic pore radius increases as desorption takes place, which in turn also increases the space available for free gas and reduces the amount of adsorbed gas. This phenomenon thus increases shale permeability. This paper goes further and indicates that pore diameter can increase, decrease or remain approximately constant with time depending on the on-going desorption, adsorption and diffusion from solid kerogen. The effects on pore radius and permeability of all these mechanisms, viscous flow and Knudsen diffusion are addressed in this paper with the development of a ID radial simulation model. Two independent methods, which approximately corroborate each other, are presented for calculating changes in pore radius.
Results show that considering pore radius changes due to sorption and diffusion have a significant impact on estimation of shale permeabilities. The effects on permeability vary under different reservoir conditions. The importance of solid kerogen as a gas source and its effect on gas flow is highlighted. The solid kerogen feeds organic pores affecting the rate of adsorption. Consequently the organic pore radius does not necessarily increase during production; it can decrease or even remain approximately constant. It is concluded that ignoring viscous flow, Knudsen diffusion and changes in pore radius lead to erroneous permeabilities. Gas diffusion from solid kerogen can be quite significant in shale reservoirs and should be taken into account.
The main contribution of this paper is the development of a numerical method for calculating sorption- dependent permeability of shales. The calculations include Darcy and diffusive flows, and changes in organic pore radius due to adsorption/desorption and diffusion from solid kerogen. This is the first time all the aforementioned mechanisms are analyzed in a single study.
Going from Conceptual to Analytical Drilling/Completions/Reservoir Guided Model of a Cased Uncemented Multi-Fractured Horizontal Well in the Canadian Horn River Basin
Authors: Virues Claudio , Lypkie Kevin , Pyecroft James , Zafar Hammad , Lehmann Jurgen , Hendrick Jason 
Published: October 2015

Abstract
This paper outlines a drilling, completions reservoir guided analytical model to assess cased uncemented (CUC) multi-fractured horizontal wells (MFHW) in the Canadian Horn River Basin. The typical Horn River shale gas development involves drilling and hydraulically fracturing multiple horizontal wells from a single surface pad location. The wells are hydraulically fractured in a sequential manner from the toe to the heel of the horizontal section, alternating from well to well. This manner of hydraulic fracturing allows concurrent operations that maximize operational efficiency and reduce completion costs. Microseismic (MS) data shows that hydraulic fracture stimulation results in a very complex stimulated reservoir volume (SRV). Surveillance data including MS as well as proppant and fluid tracer data shows that hydraulic fractures reactivate the natural fracture system and can extend beyond inter-well distances. Production analysis however indicates that the effective drainage volume, post stimulation is significantly smaller than what is observed with MS.
The objective of the cased uncemented MFHW was to achieve improved productivity over the standard cased cemented horizontal well design. The hypothesis was that the CUC wellbore would have improved connection to the reservoir and the natural fracture system existing within the target shales. In addition, the CUC well would benefit by increased reservoir contact and connection to fractures created from offset wells on the pad. The first experimental well was drilled on Nexen's 18 well pad, completed in 2012. A swellable packer system was conveyed as part of the casing string to isolate each hydraulic fracture stage. A second generation cased uncemented well with mechanical packers was tested in 2013.
This paper will discuss how the conceptual model of this new technology can be translated into an analytical model by guiding the workflow with drilling, completions and reservoir understanding and how the surveillance data such as MS, production logs, and tracers validate the process along the way.
This approach allows generating production forecasting and reserves estimates of this new technology allowing economics to be run and decision to go forward to be made. Some of the design considerations and production indications will be addressed, concluding with a discussion of the results.
Understanding Fracture Geometry of the Canadian Horn River Shale Gas via an Unconventional Complex Fracture Propagation Model in Multi-Staged Pad with 9 Horizontal Wells
Authors: Virues Claudio , Shimamoto Tatsuo , Kuroda Shintaro 
Published: October 2015

Abstract
Hydraulic fracturing in shale gas reservoirs has often resulted in complex fracture network growth, as evidenced by microseismic monitoring. The nature and degree of fracture complexity must be clearly understood to optimize stimulation design and completion strategy. Unfortunately, the existing single planar fracture models used in the industry today are not able to simulate complex fracture networks.
A recently developed unconventional complex fracture propagation model is able to simulate complex fracture network propagation in a formation with pre-existing natural fractures. Multiple fracture branches can propagate simultaneously and intersect/cross each other. This paper presents an integrated operator, non-operator and service provider's approach to optimize future hydraulic fracture design by fully integrating all the data captured in the Canadian Horn River shale.
Based upon insight from the study, which was initiated by the non-operator, continued by the operator and supported by the service provider in two different countries, the operator and non-operator needed to make more informed design decisions and understand the interaction between the shale, the hydraulic and pre-existing natural fracture network and reduce costs.
Data were captured from reference vertical wells and a multi-well pad. The data incorporated into the study included geophysical, geological, petrophysical, geomechanical and engineering such as dfit (small volume of water pumped into target formation) derived fracture closure pressure, production and pressure data from the horizontal wells in the pad. A generation of 2D natural fracture network is also included in the paper by defining natural fracture parameters such as length, orientation, spacing, friction coefficient, cohesion, and toughness which are almost entirely validated using lab data and geomechanical interpretation.
The complex hydraulic fracture simulation results calibrated with microseismic and fracturing treatment data were incorporated into a shale gas, numerical simulator and further calibrated with current production history of the candidate multi-wells. The results of the hydraulic fracture, natural fracture and reservoir models were utilized to understand the fracture propagation mechanism in the Canadian Horn River shale gas formation.
As a result of the project, the team is now able to run different hydraulic fracture design scenarios and assess the impact that each key design parameter has over the candidate well's long term production using a numerical simulator with a unique gridding process. Based on these findings, the operator and non-operator now have an insightful tool that could be used as the building block for future optimization of the fracture design