bluuebunny/crossref_metadata_2025_split huggingface dataset:
Pewarisan Karakter Fenotip Melon (Cucumis melo L. ‘Hikapel Aromatis’) Hasil Persilangan ♀ ‘Hikapel’ dengan ♂ ‘Hikadi Aromatik’
Authors: Daryono Budi Setiadi , Nofriarno Nugroho 
Published: January 2018

This research aims to develop cultivars with superior phenotypes of melon and high level of productivity. This research used the individual results of crossing between melon ♀ ‘Hikapel' with ♂ 'Hikadi Aromatik'. The research included qualitative and quantitative phenotype characterization test. The research was conducted in Center of Agrotechnology Innovation University of Gadjah Mada (PIAT-UGM), Kalitirto, Berbah, Sleman, Yogyakarta and Laboratory of Genetics Faculty of Biology UGM on December 2016 until March 2017. Quantitative data analysis used ANOVA testing through PKBT-STAT 2.02 software with Random Complete Block Design (RCBD) method at significance level of 1% and 5%. Melon 'Hikapel Aromatik' has several advantages including oval shape, without net, without lobes, crispy texture, skin-collored yellow RHS (6A), has a 7-14 brix, has volatile aromatic compound and transposon influenced. Based on the results of recapitulation of variance, the characters of 'Hikapel Aromatik' was not uniform.
DETERMINAN STRUKTUR MODAL DAN PENGARUHNYA TERHADAP RETURN SAHAM PADA INDUSTRI BARANG DAN KONSUMSI YANG TERDAFTAR DI BEI
Authors: Sunarko Bambang 
Published: January 2018

This research entitled determinant of capital structure and the impact of stock return on consumer goods industry that listed in Indonesia Stock Exchanged. The purpose of this research was to examine influence between profitability is measured by return on asset (ROA), liquidity is measured by current ratio (CR), cash holding, non-debt tax shield and asset growth on capital structure is measured by debt to equity ratio (DER) and influence on stock return. This research was conducted during the period 2011-2015. This research is quantitative research that used associative studies to determine the relationship or influence between two or more variables.
Population in this research is all of consumer goods industry that listed in Indonesia Stock Exchange during the period of research. Data collective method used purposive sampling method, with result 21 companies. Data analysis technique of this research used multiple regression analysis and simple regression analysi. Testing the hypothesis by using the coefficient of determination, F-test statistics and t-test statistics.
These conclution of this research indicate that profitability (ROA) positive influencing toward capital structure, liquidity (current ratio) and cash holding negative influencing toward capital structure, non-debt tax shield and asset growth not influencing toward capital structur, and capital structure not influencing toward stock return.
ANALISIS FAKTOR-FAKTOR YANG MEMPENGARUHI PEMBIAYAAN MURABAHAH DAN PENGARUHNYA TERHADAP RETURN ON ASSET (ROA)
Authors: Romadhona Firmansyah 
Published: January 2018

This research is an analysis on Sharia Rural Banking (BPRS) Listed on Otoritas Jasa Keuangan website (www.ojk.go.id) during Year 2012 – 2015. The research entitled “Analysis variables that influence Murabahah Financing and influence to Return on Asset (Study on Sharia Rural Banking on Indonesia during Year 2012 – 2015)”.
The purpose of this research is to analyze the influence of non performing financing, wadiah savings, financing to deposit ratio, operating expenses operating income toward murabahah financing and influence to return on asset. This research used panel data regression analysis as model to test the hypothesis. The population in this research was Sharia Rural Banking (BPRS) on Indonesia during Year 2012 – 2015 consisting of 168 banks. While the samples of this research were taken by purposive sampling method which were 25 banks.
The result of this research showed that: (1) non performing financing has no effect toward murabahah financing, (2) wadiah savings had positive effect toward murabahah financing, (3) financing to deposit ratio has no effect toward murabahah financing, (4 operating expenses operating income had negative effect toward murabahah financing, (5 murabahah financing had positive effect toward return on asset.
Implication based on result of this research was the management need to increase wadiah savings and need to decrease operating expenses operating income because it can increase the murabahah financing. The management also needs to increase murabahah financing, because it is in this research is proven to increase the return on asset.
Fracture Effect Limitation on Residual Oil Saturation: Aperture Shrinkage
Authors: Canbolat S. , Parlaktuna M. 
Published: January 2018

Abstract
Oil production in the fractured reservoirs shows, varying saturation values through the reservoir. This is due to the microscopic fissures and heterogeneity of the fractured environment that could not have been well swept. Higher, production/injection rates also empower the fingering effect by passing the unswept oil in the reservoir. In order to get rid of/minimize this effect, a polymer gel application is applied to fractured cores to decrease the residual oil saturation and increase the oil production.
In this study, naturally and artificially fractured cores were used. Analytical calculations were done in different environments, for the experimental flow rates using cubic law under laminar flow for equivalent fracture aperture calculations for all experiments. Cubic law is verified with the fractured cores flow definition whereas not for homogeneous cores.
There is a direct relation between fracture permeability with equivalent fracture aperture. The compared experiments with different environments (initially oil saturated and water saturated) in the cores, with calculations of equivalent fracture aperture and fracture permeability, showed similar results (minor deviation due to rate and saturation environment).
The effect of polymer gel conformance to increase recovery by decreasing/plugging equivalent fracture aperture was proven. The calculated fracture permeability decrease was observed with decreasing equivalent fracture aperture in the core#3, #5 and #7 respectively.
A case study was prepared for Polymer Gel Injection operations in R#17 and R#18 wells. Equivalent fracture apertures were calculated analytically for the field application of polymer gel injection, verified in laboratory study. It was obviously seen that before and after the polymer gel treatments in both wells, analytical calculations for the equivalent fracture aperture, were represented with the cubic law.
Successful Application of Clean Fracturing Fluid Replacing Guar Gum Fluid to Stimulate Tuffstone in San Jorge Basin, Argentina
Authors: Hai Qu , Liancheng Ren , Wenhao He , Tingxue Jiang , Yiming Yao 
Published: January 2018

Abstract
Hydroxypropyl guar (HPG) fluid, which is widely used in San Jorge Basin due to it is inexpensive and able to carry high concentration proppants, has more residue to damage matrix. As the permeability of tuffstone is very low, fracturing fluid that are low-damaging to the proppant pack and formation are becoming important. This paper presents the development of a low damage fracturing fluid instead of HPG and the results of successful field applications.
This clean fracturing fluid uses a low-residue polymer crosslinked with zirconium having a pH of less than 10 to minimize damage and residue encountered using other fluids. The fluid was tested for rheological properties and retained permeability which was used to evaluate the compatibility of two types of fracturing fluids with formation cores at reservoir temperature. The use of regain permeability was evaluated fluids. In addition, broken fluids were tested to figure out the amount of residue.
The clean fracturing fluid was expected to generate low damaging effects on tuffstone in order to increase reservoir productivity. During development, the fluid remained stable for approximately 2 hours at 120°C with a gel loading of 5 kg/m3. The target reservoir temperature ranges from 90°C to 120°C. Additional testing optimized gel loading at 4 kg/m3. The viscosity of crosslink fluids after 1 hour shear was stable about 60mPa·s at 170 sec−1, which was much lower than HGP with 200mPa·s. The fluid suspended the proppant for approximately 2 hours. Less than 120 mg/L residue concentration was formed after fluid breakdown, which was much lower than the residue generated by HPG. A regained permeability of 88% was obtained from a sandstone core, which demonstrates the low-damaging nature of the fluid. However, the regained values of HPG were below 50% that means more than half of fracture conductivity and matrix permeability surround fracture will be lost, even HPG could carry higher concentration proppant into fracture. Four vertical wells in same work area were designed and executed successfully to compare two fluids. The well stimulated by low damage fluid got very good production, which was 2-8 times of adjacent wells.
This work provides critical insights into understanding the performance of using clean fracturing fluid to mitigate formation damage in tight formations. It is an excellent candidate for fracturing operations and can help operators maintain low costs per barrel of oil equivalent.
Estimating Sand Production Through Gravel Packs
Authors: Wu Chu-Hsiang , Sharma Mukul M. , Fuller Michael J. , Mathis Steve 
Published: January 2018

Abstract
A new approach for estimating sand production through gravel packs is presented in this paper. The approach involves two steps: (a) evaluating the pore throat size distribution (PoSD) of a gravel pack and (b) estimating sand production through the gravel pack using an analytical model. Results of the analytical model are compared with sand production data obtained from lab experiments and Monte Carlo simulations.
The PoSD of a gravel pack is evaluated using the discrete element method (DEM). The process includes generating a random close packing of gravel based on the gravel particle size distribution (PSD) and evaluating the pore throat size distribution (PoSD) in each layer of the gravel pack. The evaluated gravel pack PoSD is then used to compute the filter efficiency of the pack for various formation sand sizes. Sand production through the gravel pack is predicted analytically by applying the filter efficiency data to any given formation PSD under the assumption that straining is the dominant sand-retention mechanism for a gravel pack.
Results from DEM simulations show that the smallest and largest pore throats in a gravel pack are typically sized around 1/9 and 1/4.8 to 1/5.5 of the effective gravel diameter (Deff), respectively. These observations suggest that any formation sand grains larger than 1/5.5 Deff will be retained near the sand-gravel interface, i.e. within 10 layers of gravel from the sand-gravel interface. Furthermore, the gravel pack alone cannot retain any formation sand smaller than 1/9 Deff for a typical thickness of the gravel pack. A secondary pack formed by retained formation sand is essential for effective sand retention in such cases. Increasing gravel packing thickness primarily improves the retention of sand sized between 1/5.5 to 1/9 Deff, and the effect is insignificant for sand out of this size range. Finally, the analytically estimated sand production using DEM-evaluated PoSDs agrees reasonably well with sand production data obtained from lab experiments and Monte Carlo simulations.
The proposed approach provides a time and cost-efficient way to predict the effectiveness of a gravel pack for any given formation sand size distribution. The approach accounts for the gravel particle size distribution and the thickness of the annular gravel pack. Application of this new approach can improve the reliability of sand control completions by better justifying a gravel design, specifically in reservoir sands with poor uniformity (i.e., high-fines).
The Real World isn't Perfect: An Investigation into Wellbore Clean-Up with Non-Uniform Filtercake Exposure
Authors: Fischer Christine 
Published: January 2018

Abstract
Soft sand wells are typically more expensive completions due to the need for sand control. The cost of the wells makes the completions more high-risk and increases the need for laboratory testing to validate the screen or gravel pack sizing as well as drill-in fluid selection and filtercake cleanup. Dynamic drill-in fluid clean-up testing provides a state of the art methodology for determining the least damaging drill-in fluid and / or the most effective clean-up treatment for the filtercake. However, the test method to date, referenced in SPE 112497 and SPE 179024 has used a 100% uniform clean-up treatment approach. This approach has assumed that all of the clean-up treatment uniformly contacts and treats the filtercake. In the actual well, it is unlikely that 100% uniform clean-up exists. It is possible in the wellbore to encounter selective clean-up treatment leakoff due to permeability differences or variable filtercake thickness. This paper investigates the results when a less uniform clean-up environment is encountered.
The dynamic drill-in fluid testing utilizes designed-for-purpose slot flow cells which allow soft sand formations to be confined and tested while still exposing the face of the formation directly to the drill-in fluid or clean-up treatment during the test. The well conditions are received from the client and the shear rate at the formation face is calculated and matched in the laboratory. The test simulates wellbore conditions as closely as possible including annular shear rate during filtercake deposition, overbalance pressure, temperature and multiple clean-up flushes. In this study, the amount of filtercake clean-up treatment fluid loss was modified to simulate multiple effective clean-up scenarios. Additionally, testing was completed on aloxite discs in a standard HPHT fluid loss cell in order to provide a comparison between the dynamic and static tests.
The dynamic fluid loss testing has been designed to match treatment volumes and conditions in the actual wellbore as closely as possible. The assumption that 100% uniform application of the clean-up treatment contacting the filtercake has always been the basis for the testing. However, changing the previous assumptions to allow for non-uniform application of the clean-up treatment during the testing provides another opportunity to challenge our perceptions and simulate the actual well more completely.
The modification of the standard test procedure to allow the simulation of non-uniform clean-up of the filtercake in the wellbore adds further to our understanding of the actual wellbore clean-up. The relationship of the results between the static and dynamic fluid loss provides an opportunity for pre-screening work to be conducted and related to the final results achieved in the dynamic fluid loss test.
A New Tool for Formation Damage Management
Authors: Restrepo A. , Romero R. D. , Calle J. M. , Espinosa K. Y. , Mejía J. M. 
Published: January 2018

Abstract
Formation damage is one the most frequent problems governing well productivity. An adequate workflow for data management and surveillance of the well, and specialized tools for damage mechanisms diagnosis becomes mandatory for reservoir and productivity engineers. This paper presents the software application IFDM (Integrated Formation Damage Model), a web platform for reservoir surveillance in order to manage formation damage including specialized modules for statistical and analytical damage characterization and discretization, data management, and geovisualization tools.
The IFDM platform is developed under the framework Laravel taking advantage on its web characteristics. A centralized database is used to integrate the specialized modules with data management module increasing the knowledge base in order to make more accurate analysis in wells and fields of interest. Specialized modules are based on statistical and analytical approaches for the purpose of disaggregate formation damage in its different components and calculates formation damage caused by organic scales and fines migration. In addition, data management and geovisualization modules use real-time interaction with users for trends identification in specific areas.
The IFDM application provides the tools for a complete analysis of the condition of wells and fields in real time. Furthermore, data management and geodata visualization modules ease decision-making process in order to prevent and intervene the fields and wells in a prompt and accurate manner. The IFDM application has driven formation damage study in several Colombian fields. Such tool has facilitate managing the assets of the company by promoting a culture of data management and the quality assurance of critical data. In addition, the web application extends its database automatically by the interaction with multiple users storing and analyzing historical petrophysical, chemical and production data for earlier identification of threats that might affect the productivity of the well. This is important in reservoir surveillance because of an early intervention could optimize and increase the crude oil productivity in Colombian fields.
The novelty of the IFDM web application is in the possibility of characterize and discretize formation damage in a centralized manner. The IFDM application provides an increasing database allowing more accurate analysis based on real-time interaction with the platform. In addition, due to its web characteristics and adaptable architecture, the IFDM eases its usage and implementation in companies worldwide.
Geochemical and Geomechanical Alterations Related to Rock-Fluid-Proppant Interactions in the Niobrara Formation
Authors: Iriarte Jessica , Tutuncu Azra N. 
Published: January 2018

Abstract
Fracture conductivity degradation results from damage mechanisms and fluid interactions that occur during and after hydraulic fracturing treatments. Rock softening and associated proppant embedment are among the damage mechanisms affecting this degradation. The aim of this research study is to understand the physico-chemical interactions between fracturing fluid and formation to investigate the associated geomechanical property changes taking place in the Niobrara shale, a calcium carbonate rich formation, during and after hydraulic fracturing treatments.
Experimental tests were carried out on Niobrara core samples to investigate the effects of chemical interactions between the formation, fracturing fluid, and proppant along with static and dynamic geomechanical property changes. The samples were characterized using X-Ray Diffraction (XRD), X-Ray Fluorescence (XRF), and Field-Emission Scanning Electron Microscopy (FESEM). Two sets of experiments were conducted: fluid chemical interactions with crushed rock and proppant, and geomechanical property variations in intact core samples. In the first set of experiments the changes in the composition of the solution were monitored as a function of saturation time. In the second set, the variations in the dynamic and static mechanical properties were examined in intact core plugs before and after they were saturated. Best practices for hydraulic fracturing fluid selection are established by incorporating the impact of the fracturing fluid on geochemical composition and geomechanical property changes in the formation.
This study provides an insight into how each selected fluid formulation yields unique interactions with the mineral composition of the formation. Distilled water shows to be more prone to dissolve elements affecting the strength of the rock, whereas 2% brine solutions, especially 2% KCl, dissolve elements that could be the source of scales, fines migration, other types of undesired precipitations, as well as elements related to organic matter in the reservoir rock. A comparison of the dynamic and static elastic moduli and fluid chemistry data obtained pre- and post- treatment indicate that there is a correlation between softening of the formation and the chemical interactions taking place in the rock. FE-SEM images further support this interpretation.
Hydraulic fracture treatment effectiveness in tight reservoirs can be improved by integrating multidisciplinary data. This study provides detailed geomechanical and geochemical analyses capturing associated changes in the rock and the fluid composition when they interact with each other. It also introduces a correlation between mineralogy and the mechanical properties of the rock proposing a simple approach to improve the fluid selection in hydraulic fracturing operations.
Influence of Transport Conditions on Optimal Injection Rate for Acid Jetting in Carbonate Reservoirs
Authors: Ridner Dmitry , Frick Taylor , Zhu Ding , Hill A. Daniel , Angeles Renzo , Vishnumolakala Narendra , Shuchart Chris 
Published: January 2018

Abstract
Acid jetting occurs as a result of pumping acid through limited entry liner completions, causing high velocity streams to impinge against the wellbore wall. The dissolution effect of jetting differs significantly from conventional matrix acidizing. Acid jetting causes cavities to be formed at the points of contact of the jet with the rock, with wormholes forming beyond the cavity. Jetting has been shown to be an effective technique for placing acid along extended reach laterals, removing filter cake, and enhancing wormhole propagation.
The velocity of the impinging jet and its standoff distance from the rock causes some of the acid to penetrate the formation and some to flow back in the annular space of the liner. Two types of dissolution mechanisms occur: surface dissolution forming the cavity, and matrix dissolution forming the wormholes. These dissolution mechanisms are highly dependent on acid injection rate, velocity of the jet, temperature, and permeability of the formation. The differences between the matrix dissolution mechanism of acid jetting and that of conventional matrix acidizing are most obvious at low acid injection rates.
Experiments were performed with the intention of quantifying the difference in pore volume to breakthrough between acid jetting and matrix acidizing, as well as determining the effect of increased temperature, rock permeability and acid concentration on this value with respect to acid injection rate. Baseline parameters of room temperature, 15% HCl and 2-4 mD Indiana limestone were individually compared with experiments run at 180°F, 28% HCl, and Indiana limestone cores of 30, 60 mD, and 140 mD. The effect of jetting velocity was also investigated by changing the diameter of the orifice from which the stream exits. Direct comparison with conventional matrix acidizing was made by eliminating the jetting effect of the stream through mechanical dispersion.
Acid jetting creates a point of heightened interstitial velocity at the contact of the acid and the rock, causing wormhole propagation to happen at a faster rate than it would in conventional matrix acidizing at that injection rate. This effect is especially pronounced as jetting velocity is raised above that of matrix acidizing, and tapers off at progressively higher jetting velocities.