bluuebunny/crossref_metadata_2025_split huggingface dataset:
Corn Nitrogen Management Influences Nitrous Oxide Emissions in Drained and Undrained Soils
Authors: Fernández Fabián G. , Venterea Rodney T. , Fabrizzi Karina P. 
Published: November 2016

To date, no studies have evaluated nitrous oxide (N2O) emissions of a single versus a split‐nitrogen (N) fertilizer application under different soil drainage conditions for corn (Zea mays L.). The objective of this study was to quantify season‐long cumulative N2O emissions, N use efficiency, and soil N dynamics when corn received a recommended N rate as single or split‐N application in Minnesota soils with and without tile drainage over two growing seasons. Preplant urea was broadcast incorporated, and in‐season split‐N was broadcast as urea plus urease inhibitor. Tile drainage reduced N2O emissions during periods of excess moisture but did not affect grain yield or other agronomic parameters. Conversely, when precipitation was adequate and well distributed, tile drainage did not affect N2O emissions, but it did enhance grain yield. Averaged across years, the undrained soil emitted 1.8 times more N2O than the drained soil (2.36 vs. 1.29 kg N ha−1). Compared with the Zero‐N control, the Single Preplant and Split N applications emitted 2.1 and 1.6 times more N2O, produced 1.4 and 1.3 times greater grain yield, and resulted in 1.5 and 1.4 times more residual soil total inorganic N, respectively. Per unit of grain yield, the Split application emitted similar amounts of N2O as the Zero‐N control. Averaged across years and drainage, the Split application emitted 26% less N2O than the Single Preplant application (1.84 vs. 2.48 kg N ha−1; P< 0.001) with no grain yield differences. These results highlight that soil drainage can reduce N2O emissions and that a split N application may be a feasible way to achieve N2O reduction while enhancing grain yield.Core Ideas
Undrained soils increased N2O emissions relative to drained soils.
N fertilization increased N2O emissions regardless of drainage.
N2O emissions per unit of grain‐yield were similar for the Split and 0‐N control.
Split‐N vs. single application reduced N2O emissions with no impact on grain yield.
Estimating Soil Saturated Hydraulic Conductivity using the Kostiakov and Philip Infiltration Equations
Authors: Su Lijun , Wang Quanjiu , Shan Yuyang , Zhou Beibei 
Published: November 2016

Core Ideas
We analyzed the relationships between the parameters of the Kostiakov and Philip infiltration equations.
A new method was proposed to estimate the Ks by parameters in Kostiakov equation.
Effect of soil hydraulic parameters on a new method was discussed.
Direct measurement of saturated hydraulic conductivity (Ks) is time and labor consuming, so Ks is often estimated by mathematical models describing soil–water infiltration. The Kostiakov infiltration equation is widely used to estimate soil–water infiltration rate (i) with only two empirical parameters m and n, which are highly dependent on Ks. The objective of this study was to develop a new method to estimate Ks using the parameters of the Kostiakov equation for short infiltration times. The new method is based on the relationship between the Kostiakov equation and Philip's two‐term equation. We used infiltration data of one‐dimensional vertical water absorption simulated by Hydrus‐1D to evaluate the applicability of the new method. The parameters of Philip's equation were applied to estimate the parameters of the Kostiakov equation with relative errors for m and n <1.15 and 4.20%, respectively. The estimated Ks agreed closely with the parameters of the Kostiakov equation, and the optimal depth of the wetting front (zf) was used as an indicator to confirm the infiltration time in the one‐dimensional vertical water‐absorption simulation. The inverse of the air‐entry value, the saturated hydraulic conductivity, the pore‐size distribution index, and the initial water content had significant effects on zf, which could be described as a power function of these parameters, with an R2 of 0.9717. The parameters of the Kostiakov equation can thus be used to calculate Ks for most soils when the depth of the wetting front is approximately 20 ± 5 cm.
PENGEMBANGAN MULTIMEDIA PEMBELAJARAN AKUNTANSI PAJAK DENGAN PENDEKATAN QUANTUM LEARNING DI SMK
Authors: Yuniarti Fitria , Sofyan Herminarto 
Published: November 2016

Penelitian ini bertujuan untuk: (1) menghasilkan produk multimedia pembelajaran akuntansi pajak dengan pendekatan quantum learning, (2) mengungkapkan kualitas kelayakan multimedia pembelajaran akuntansi pajak, (3) mengungkapkan keefektivan multimedia pembelajaran akuntansi pajak di Kelas XI SMK Negeri 1 Depok Yogyakarta. Multimedia pembelajaran ini dikembangkan dengan pendekatan quantum learning yang dikembangkan menggunakan software Adobe Flash CS6. Studi ini merupakan penelitian dan pengembangan (R&D) dengan prosedur pengembangan yang mengadopsi model pengembangan Alessi dan Trollip, yaitu perencanaan, desain, dan pengembangan. Validasi produk dilakukan pada tahap uji alpha yang melibatkan dua ahli media dan dua ahli materi. Sementara uji beta melibatkan tiga orang siswa. Produk yang dikembangkan telah layak digunakan dengan perolehan skor hasil validasi ahli media 4,1 dengan kategori baik, validasi ahli materi 4,0 dengan kategori baik, dan penilaian siswa pada uji beta 4,5 dengan kategori sangat baik. Multimedia pembelajaran akuntansi pajak dinilai efektif karena dapat meningkatkan hasil belajar kognitif siswa dengan nilai rata-rata pretest 59,8, dan nilai rata-rata posttest85,6. Terjadi peningkatan pencapaian sebesar 25,8% dari 30 orang siswa hanya satu orang siswa yang tidak tuntas dalam proses pembelajaran.Kata kuci: multimedia, akuntansi pajak, quantum learning DEVELOPING MULTIMEDIA FOR TAX ACCOUNTING TEACHING WITH THE QUANTUM LEARNING APPROACH AT VOCATIONAL HIGH SCHOOLAbstractThis research aims to: (1) develop a multimedia product for tax accounting teaching with the quantum learning approach, (2) reveal the feasibility quality of the developed multimedia for tax accounting teaching, (3) reveal the effectiveness of the developed multimedia for tax accounting teaching to the 11th grade students of State Vocational High School 1 Depok, Yogyakarta. This learning multimedia was developed by the quantum learning approach using Adobe Flash CS6 software. This study is research and development (R & D) with the procedure on the development adopted from Alessi and Trollip models, namely planning, design, and development. The validation of the product was conducted in the alpha test phase involving two media experts and two material experts. Meanwhile, the beta test involved three students. The developed product is proper to be used with the validity score of 4.1 by the media experts (good category), by experts’ validation material 4.0 of (good category), and assessment of students in the beta test of 4.5 (very good category); (3) the multimedia for tax accounting teaching is effective because it can increase students' cognitive learning outcomes. This is evidenced by the average score of 59.8 on pretest and posttest average score of 85.6. There is an increase by 25.8% of the 30 students, and only one student do not achieve the standard mastery.Keywords: multimedia, tax accounting, quantum learning
Microemulsion Modeling for Surfactant Optimal Salinity Prediction in Chemical EOR Design
Authors: Yee Hon Vai , van Male Jan , Handgraaf Jan-Willem , Culgi B. V. , Hsia Ivy Chai Ching , Fauzi Noor 'Aliaa Amira M 
Published: November 2016

Abstract
The knowledge of the relationship between the molecular structure of surfactants and their ability to form a single phase solution for water and oil has been expanded enormously over the last two decades, primarily because the use of microemulsion solutions for EOR are promising. The qualitative trends and sensitivities between the characteristic of microemulsion solutions and the phase behavior of mixtures of oil, water and surfactants are often obtained from experiment. The experiments are simple but laborious especially when it often involves a wide range of surfactant choice. In this paper, we demonstrate a complementing molecular chemistry modeling method to assist in reducing the huge experimental test matrix in shortlisting promising surfactants for a chemical EOR design.
Application of molecular chemistry modeling for optimal microemulsion formation in chemical EOR application is a niche technology within the oil and gas industry. The modeling approach used in our simulation is based on the physical chemistry of an optimal microemulsion interface which is planar with zero surface tension and torque. The approach is implemented using the framework of Dissipative Particle Dynamics (DPD) technique. The simulation system comprises of oil, brine and surfactant in the form of coarse-grain (CG) beads. Atomistic parameters for both bonded and non-bonded CG beads are determined to simulate the molecular interactions within the system. This setup enables the computation of surface tension and torque as a function of the distance across the interface. Optimal salinity for for-mation of optimal microemulsion is determined from the profile of torque versus salinity at zero torque. The simulation results for various surfactants are compared with optimal salinity determined experimen-tally. The simulation results are in good agreement with the experimental data.
Avoiding Perforating High Permeability Water-Bearing Sands Within a Stacked Sand Oil Bearing Section Using Multi-DOI MR Fluid Mapping, a Case Study from a Recently Developed Field in the Gulf of Thailand
Authors: Platt C. J. , Shi Z. G. , Lerdsuwankij T. 
Published: November 2016

Abstract
Fresh formation waters in the Wassana field, Gulf of Thailand, with water salinity as low as 1000 ppm NaCl equivalent, present a challenging environment in which to make perforation decisions based on the deterministic petrophysical interpretation from triple combo logs alone. To address the uncertainties on reservoir quality and fluid typing, NMR with multi-frequency and multiple depth of investigation (DOI) was planned early on in the development drilling. The Magnetic Resonance Fluid characterization (MRF) maps at three DOIs characterized the signature of synthetic oil base mud (SBM) filtrate invasion. The SBM invasion also facilitates the water signal identification and assists in quantifying the native oil viscosity.
In an early development well in Wassana field, 3 out of the four sands exhibit similar characteristics on logging while drilling (LWD) logs . The third sand has obviously higher resistivity than other three. The high resolution NMR depth logs shows the three sands at bottom have similar permeability, as high as 1 Darcy. Without knowing fluid type, a commingled production for those sands could potentially create huge problems requiring surface water treatment, particularly severe at the early stage of the field development.

MRF maps at multi-DOIs reveal the second sand from top has a mobile water phase. At the shallowest DOI, the bound water, free water and SBM signals are observed on the map, as DOI increases, free water volume increases. The fluid characters on the maps are very similar to the maps acquired for a known water bearing sand just above the targeted "oil bearing" sands.
An integrated petrophysical interpretation shows that the other three sands in this sequence are oil bearing. SBM filtrate signals are observed at the shallowest DOI, as the DOI increases, the fluid signal shifts slightly to the left side of the SBM filtrate signal, at the deepest DOI, which is 4 inch from the borehole wall, the native oil signal dominates. Those three oil bearing sands were perforated with confidence, this well came on production at 790 BOPD and free of water.
Deepest Gas Sand Discoveries in North Malay Basin: Integration of Geophysical Applications and Well Data Leading to an Effective Evaluation for a Robust Development Plan, Malaysia-Thailand Joint Development Area
Authors: Adnan M. Mohd , Ismail W. Wan , Setiawan A. S. 
Published: November 2016

Abstract
Integrated geophysical applications and well datasets play an important role in understanding reservoir distribution and decision making for a robust development plan. A technical assessment was completed in a gas field in the North Malay Basin to describe the reservoir heterogeneity in the Early Miocene to Late Oligocene reservoir intervals. The field is a North-South oriented plunging anticline with stratigraphic trap configuration, discovered in 2007 by Well-X1. The assessment has resulted in a proposal of an appraisal well in 2014, Well-X2ST to delineate the northern hydrocarbon extent and to assess the hydrocarbon potential in the exploration interval of deeper sequences. The new well datasets were acquired and the results were utilized to further evaluate the field.
This paper focuses on the deepest reservoir sequence, DS12, encountered by the appraisal well in the eastern flank of the Malaysia-Thailand Joint Development Area (MTJDA). Rock physics modeling and seismic attribute datasets with well log and pressure data integration were utilized to better understand sand distribution for the upcoming development planning. Due to the thinly bedded nature of the reservoirs, the seismic could not be fully utilized to evaluate internal stacking geometries. This was further complicated by attenuation from the overlying thick shale. However, attribute analysis was effective to determine overall sand presence where the bed thickness ranges from 10 to 15 meters and the seismic detection limit is approximately 8 meters.
Rock property analysis was performed to calibrate both acoustic impedance and Vp/Vs to gamma ray for indication of sand presence. The Vp/Vs derivative was used instead of acoustic impedance because of the extra information obtained in both the elastic and AVO domain. In addition, rock physics modeling was performed to differentiate gas from wet sand and shale. The seismic datasets were used to qualitatively condition a geologic model to better distribute sand presence for well planning optimization. Development wells are planned to target good quality sands to maximize recovery efficiency
The success of proving the deepest reservoir sequence in the eastern flank of MTJDA, utilizing geophysical application and well data integration, have resulted in an improved understanding to outline deep reservoir distribution in the surrounding area and mitigate uncertainties in the development plan.
Simultaneous Solution of Three-Phase Formation Fluid Saturations Using Triangulation of Multidetector Pulsed Neutron Measurements
Authors: Kim Y. , Chace D. 
Published: November 2016

Abstract
The delineation of three-phase reservoir fluid saturation is important to operators as fields mature. The understanding of multiphase reservoir fluid distribution determines the operator's subsequent reservoir management and production strategies such as infill drilling and reentry planning for bypassed hydrocarbon access, perforation or squeeze interval selection, injection planning, etc.
Pulsed neutron well logging technology enables acquisition of useful data for saturation identification in cased hole environments. Interpretation of pulsed neutron data in three-phase formation fluid conditions has historically involved the use of empirical correlations or corrections to carbon/oxygen (C/O) and pulsed neutron capture (PNC) sigma measurements. However, a robust interpretation technique to provide reliable and quantitative three-phase fluid saturation results under any reservoir conditions (including fresh, saline and variable or unknown formation water environments) has not been available.
This paper presents a new patented interpretation method to quantify three-phase formation fluid saturations using pulsed neutron logging data. The principles of pulsed neutron logging and nuclear physics remain the same; however, the application of a multidetector pulsed neutron tool measurements and an innovative data analysis approach enabled the development of the new interpretation technique. The method combines two measurements recorded by a multidetector pulsed neutron logging tool and integrates Monte Carlo modeling responses to quantitatively determine formation water, oil and gas saturations.
Application case studies from sandstone and carbonate reservoirs are demonstrated. The technique successfully generated multiphase formation saturation profiles in various reservoir scenarios. In addition, the delivered solutions have enabled operators to understand current reservoir fluid saturations and perform subsequent well and reservoir management activities to maximize hydrocarbon production.
Multistage Fracturing Optimization for the Successful Development of a Complex Tight-Gas Reservoir in Western India: Case Study
Authors: Abdelaziz Sherif , Singh Aman , Deshpande Mayur , Tiwari Shobhit , Goyal Rajat , Sidharth Punj , Anand Surabh 
Published: November 2016

Abstract
For decades, the oil and gas exploration industry evaluated assets and screened them for future development based on certain characteristic requirements/pay cutoffs such as shale percentage, water saturation, and porosity. Reservoirs that did not meet these specific requirements were considered uneconomical and not considered for further development. Currently, as the demand for energy is continuously rising, those reservoirs that were considered uneconomical in the past because of a lack of original hydrocarbon flow capacity and were overlooked are attracting significant attention for development globally, and now a considerable percentage of the world hydrocarbon production is coming from these emerging unconventional reservoirs, such as shale gas, tight gas, and coalbed methane. The challenge in developing these unconventional assets is that they cannot produce at economic rates without an effective stimulation treatment. To achieve the required reservoir stimulation effectiveness, a coherent understanding of the subsurface characteristics of the reservoir is necessary, such as depositional environment, structural and lithological characteristics, rock mechanics, and geomechanical properties. This thorough evaluation of the reservoir is needed not only to determine the best stimulation approach but also to aid in deciding the most suitable well architecture—trajectory, azimuth, and completion concept—to maximize the benefit of the planned stimulation concept. Whereas the stimulation treatment design was usually only considered later in the life of the reservoir, for these formations, it is considered during a much earlier stage in the planning phase, moving from a drill-to- produce to a drill-to-stimulate and late-produce concept. Hydraulic fracturing is the most effective and widely used stimulation concept in modern times and was vital for making the shale gas plays in North America economic assets. Lately, it has attracted much attention, and a significant amount of scientific/engineering efforts are being exerted to develop a better understanding of how rocks will behave under hydraulic fracturing conditions. Understanding rock major behavioral characteristics, such as failure mechanisms, fracture growth patterns, and fracture height containment, is crucial for identifying the fracturing strategy, rate requirement, treatment volumes, and, more importantly, the number of stages required to maximize the stimulated reservoir volume (SRV) and hence a single well's deliverability.
Model Fracture Formation in Mechanical Layers During Basin Burial Effects of Mechanical Properties Stress Fields Pore-Pressure and Layer Thickness
Authors: Fukunari T. , Gudmundsson A. 
Published: November 2016

Abstract
The aim of this paper is to provide analytical solutions of stress fields in mechanical layers which consist of stiff and soft or compliant layers. The paper examines possible geological conditions of mode I (extension) fracture development on the basis of the analytical calculations with various layer thicknesses, Young's moduli, Poisson's ratios, external stress fields and pore-fluid pressure. Linear elastic model with two different mechanical layers is assumed for the calculations. Fluid-driven fractures, hydrofractures, are discussed in detail elsewhere and are not considered here. Layer-parallel stresses in the model caused by external stresses and pore-fluid pressure are mathematically calculated for both stiff and soft layers. Relative Young's modulus and relative thickness between the two types of layers are applied to simplify the associated equations. Poisson's ratio v is assumed to be same between the two. This is because the possible variation of Poisson's ratio between rocks is much smaller than those of the other parameters. The calculated ratio of minimum to maximum principal stresses within each layer is used to estimate fracture type which can develop under various geological conditions. The results indicate extension fracture preferably develop in stiff layer. Stress conditions in the model are primarily controlled by relationship among external horizontal stress σXX, vertical stress σZZ and pore-fluid pressure Pf: no tensile fracture forms when σXX &gt; Pf + v(σZZ - Pf)/(1 - v); tensile fractures can form only in stiff layers in soft-layer-dominant system when Pf + v(σZZ - Pf)/(1 - v) &gt; σXX &gt; Pf; tensile fractures form in stiff layers in both stiff-layer-dominant and soft-layer-dominant systems when Pf &gt; σXX &gt; 4Pf/3 - σZZ/3; tensile fracture can form in both stiff and soft layers in soft-layer-dominant formation with small relative Young's modulus when 4Pf/3 - σZZ/3 &gt; σXX. Only shear fractures can form in soft layers, except the rare geological condition of 4Pf/3 - σZZ/3 &gt; σXX with very small relative Young's modulus. The results of analytical calculations provide potential criterion to estimate when and where layer-scale extension fracture network develops in relation with geological history. One implication of the results is that extension fracture formation is not necessarily related to regional tensile stress field but ratio among horizontal stress, vertical stress and pore-fluid pressure. This implies that extension fracture network can form in mechanical layers not only during crustal uplift/exhumation but also during basin-burial in which horizontal stress, vertical stress and pore-fluid pressure are increasing.