bluuebunny/crossref_metadata_2025_split huggingface dataset:
Development of Animation-Based Teaching Material on Explanation Text on XI Grade Students at MAN 2 Aceh Tenggara
Authors: Br Sinulingga Siti Halimah , Jaria Jaria , Barus Efendi 
Published: February 2020

The problem of the research was the effectiveness and feseabilty of animation-based teaching material on explanation text on grade XI students at MAN 2 Aceh Tenggara. This effectiviness was carried out by teachers and students. The product feasibility test was tested by a team of experts, namely lecturers and teachers of bahasa Indonesia. The objective of the research was to develop animation-based teaching material to find out the effectiveness of animation based teaching material, and to find out the feasibility test of animation-based teaching material on explanation text. This research used R&D method. The subjects of research were XI grades students of MAN 2 Aceh Tenggara. This research used non-test and test instruments. The result of the research indicated that the pre-test value was at a “fairly good” category and after using animation on post-test was at a “very good” category. Thus, the development of animation-based teaching material on explanation text is appropriate to be applied.

Keywords: development, teaching material, explanation text, animation

Abstrak
Permasalahan dalam penelitian ini adalah tingkat efektivitas dan kelayakan pengembangan materi ajar teks eksplanasi berbasis animasi pada siswa kelas XI MAN 2 Aceh Tenggara tahun pembelajaran 2018/2019. Uji efektivitas tersebut dilakukan oleh guru dan siswa sedangkan uji kelayakan produk diuji oleh tim ahli yaitu dosen dan guru bahasa Indonesia. Tujuan penelitian ini adalah untuk mengembangkan proses bahan ajar berbasis animasi, untuk mengetahui efektivitas bahan ajar berbasis animasi, dan untuk mengetahui uji kelayakan bahan ajar berbasis animasi pada materi ajar teks eksplanasi. Penelitian ini menggunakan metode R&D. Subjek penelitian ini adalah seluruh siswa kelas XI MAN 2 Aceh Tenggara. Penelitian ini menggunakan instrumen nontes dan tes. Hasil penelitian ini menjelaskan bahwa pengembangan materi ajar teks eksplanasi berbasis animasi menunjukkan bahwa nilai pre-tes berada pada kategori cukup baik dan setelah dilakukan inovasi pembaharuan menggunakan animasi berada pada kategori sangat baik. Dengan demikian pengembangan materi ajar teks eksplanasi berbasis animasi layak digunakan dalam pengembangan bahan ajar.

Kata kunci: pengembangan, materi ajar, teks eksplanasi, animasi
Needs Analysis for Developing of Bahasa Indonesia’s Placement Test at SPK School in Tangerang
Authors: Muliawan Yoanita 
Published: February 2020

This preliminary study aims to confirm the need to develop a bahasa Indonesia placement test for an International Baccalaureate (IB)-based SPK school in Tangerang. The researcher uses the needs analysis method by collecting quantitative and qualitative fata from the entire audiences through interviews, surveys, documentation and field observations. From this study it was concluded that the development of a better Indonesian placement test is needed in terms of test questions, contents and thoroughness of the rubric, and procedures in marking. It is the researcher’s expectation that the results of this study will be of benefit to other IB-based schools in need for a more accurate Indonesian placement test.

Keywords: placement test, Indonesian language, IB

Abstrak
Penelitian ini adalah penelitian pendahuluan yang bertujuan untuk mengonfirmasi kebutuhan pengembangan tes penempatan bahasa Indonesia yang dipakai di sebuah sekolah SPK berbasis International Baccalaureate (IB) di Tangerang. Peneliti memakai metodeanalisakebutuhandengancaramengumpulkan data kuantitatif dan kualitatif dari seluruh audiens melalui wawancara, survei, dokumentasi, dan observasi lapangan. Dari penelitian ini, disimpulkan perlunya pengembangan tes penempatan bahasa Indonesia yang lebih baik dalam hal materi soal, isi dan kelengkapan rubrik, serta prosedur dalam melakukan penilaian. Hasil dari penelitian ini diharapkan dapat membantu sekolah-sekolah berbasis IB yang juga membutuhkan tes penempatan bahasa Indonesia yang lebih akurat.

Kata kunci: tes penempatan, bahasa Indonesia, IB
A Novel Approach to Uniformly Acid Stimulate Carbonate Tight Formation Utilizing Multi Jetting Tool Technology
Authors: Al Binhaji Zaid , Al Ghamdi Abdullah , Sabut Bangkong , Hicks Daryl 
Published: February 2020

Abstract
The foremost purpose of carbonate matrix acid stimulation is to improve near wellbore flow conductivity, induce the desired conduits, and bypass the formation damage. Hydrochloric acid (HCl) is the most predominantly used treatment fluid to treat carbonate formations, enhance permeability, and amplify contact with the formation.
Unlike sandstone acid stimulation, which experiences a relatively uniform acid front, carbonate formations experience a very high surface reaction rate, and so affecting the overall surface area in contact with the acid, which eventually leads to nonuniform distribution of stimulation fluid. The condition gets even more intricate in tight carbonate formations where the formation characteristics are prone to higher heterogeneity. Prominently, the fluid flow will follow the path of the least resistance regions, leaving behind the lower permeability strips unswept.
Therefore, to combat the aforementioned issues with the distribution of stimulation fluid, a patented state of art multi-jetting tool technology was invented and introduced to ultimately boost the acid stimulation efficiency. The multi-jetting tool is deemed to offer deeper, more efficient penetration of injected fluids using a combination of pulsating action and helical flow from jet ports of more than 6" penetration radius with relatively low-risk in cleanout and stimulation operations. This is contrary to other jetting tools that constitute laminar flow patterns which cease its effectiviness 3" penetration radius. It is a very robust jetting tool with minimal failure rates since it has no internal moving parts or seals, which in turn offers high degree of reliability.
This tool was proposed to promote production or injection from noncontributing intervals by selective stimulation treatment while manipulating the pumping rate and pressure to avoid surpassing the fracture gradient of the well.
The multi-jetting tool conveyed on coiled tubing was employed to acid stimulate tight reservoir formation salt water disposal well. It has exhibited numerous advantages. The tool has leveraged its oscillation/agitation features to reach the TD effortlessly without the need to induce friction reducer during the operation. In addition, a reduction in pumping time by 33% was attained since the tool has managed to pump at a noticeably high average rate of 3.2 bpm with a clear reduction pumping pressure from 4,200 to 3,800 psi signifying that the formation has responded to acid treatment.
This paper provides a brief technology overview of this multi-jetting tool and tool operation, and benchmarks its efficiency against the conventional jetting techniques with an emphasis on the distinctive characteristics compared to the existing tool in the industry. The paper presents the tool deployment and acid stimulation trial test execution and results, recapitulates conclusions about the tool performance, and identifies a number of recommendations.
Lost Circulation Material Implementation Strategies on Fluid Loss Remediation and Formation Damage Control
Authors: Yang Mingzheng , Chen Yuanhang 
Published: February 2020

Abstract
The design of lost circulation remediation strategies is complicated in naturally fractured reservoirs. It has been a great challenge for engineers to balance between fracture plugging and formation damage. In this study, experimental investigations and statistical analysis were conducted to explore the effects of LCM implementation strategies in lost circulation remediation and formation damage control.
Different combinations of granular and fibrous LCMs were tested in a permeability plugging apparatus with slotted discs. When LCM particles accumulated at the slots and formed a low-pressure-bearing plug, the injecting pressure was held constant to enable further establishment of the plug through filtration. The effects of LCM soaking time, soaking pressure, and injection rate on plug breaking pressure and total fluid loss volume were investigated. Full factorial experimental design and analysis of variance (ANOVA) were performed to study the statistical significance of each parameter.
For granular LCM mixtures, the soaking pressure and time did not have a significant impact on the ultimate plug breaking pressure and the cumulative fluid loss. For mixtures blended with fibrous LCMs, longer soaking time contributed to increasing the plug breaking pressure and reducing fluid loss. A low LCM pill injection rate reduced the fluid loss volume comparing to a high injection rate upon the establishment of an effective seal. Incorporating fibrous LCMs enhanced the slot sealing effects since the dehydrated mud plug formed not only at the fracture mouth, but also inside the fracture. This prevented the plug from being washed down when drilling resumes.
The results and conclusions from this study provide new insights on the identification of optimal LCM implementation strategy with better formation damage control.
Digitalization of Matrix Stimulation Workflow - Efficient Candidate Screening in a Blink of an Eye
Authors: Mohd Jeffry Suzanna Juyanty , Trjangganung Kukuh , Madon Bahrom , James Berok Sylvia Mavis , Mohd Arifin Azahari , Hermann Roland , Baker Andrew 
Published: February 2020

Abstract
Candidate screening for matrix acidizing has gained attention in recent years due to the importance in driving towards acidizing success rate and efficiency improvement. This paper presents a comprehensive workflow featuring a simple step-by-step method utilizing mainly production and basic reservoir data. The objective of the workflow was to ensure the right candidates were selected, standardized checklist of information being reviewed and time saving to shortlist wells with formation damage issues. Basic production data such as liquid rate (oil and water rates), water cut, gaslift rate and sandcount along with basic reservoir data such as permeability and height were powerful parameters that drive the workflow. Formation Damage Indicator (FDI) and Heterogeneity Index (HI) concepts were introduced to provide the initial screening of the wells. Other subsequent parameters were evaluated according to specific cut-off values. These cut-off values have made the workflow standardized and practical to speed-up the screening of candidates. Once the wells have passed through the workflow, the shortlisted candidates were matured by performing nodal analysis, studying on the detailed formation damage type and skin evaluation, formulating the remedial solution and quantifying the potential gain.
This workflow was tested throughout selected fields in the Malaysia region operated by PETRONAS Carigali, which proved to be efficient in identifying the acidizing candidates. The ultimate aim of the work was to automate the selection of wells with productivity issues using real-time data. The workflow was then brought into an Integrated Operations (IO) environment using the same step-by-step method whereby the required data used for the screening process were pulled from corporate database. The IO environment retrieves data from master and asset databases to perform calculations using various parameters with its cut-off values. Using this method, candidate screening processes were shortened from two weeks to one day. In total, 750 strings were analyzed using this workflow, which resulted in 101 strings shortlisted as stimulation candidates. Twenty-eight strings have been executed from year 2017 until 2018 with a total 6500 bopd gain. Success rate has improved from 55% to 73%.
The additional benefit of the workflow was also the ability to group wells with lifting issues, water production problems and sand production issues. The unique digitalized workflow is now a one-click exercise, which enables engineers to increase their operational efficiency resulting in huge cost and time saving opportunities.
Evaluation of Inorganic-Crosslinked-Based Gelled Acid System for High-Temperature Applications
Authors: AlOtaibi Fares , Dahlan Mohammed , Khaldi Mohammed , AlGhamdi Abdulaziz , Al-Hulail Ibrahim 
Published: February 2020

Abstract
Hydrochloric (HCl) crosslinked gelled acid systems have been extensively used in acid fracturing and matrix acidizing to help achieve acid diversion during stimulation treatments. These systems also help control fluids leakoff and help retard the acid reaction to allow deeper acid penetration. Currently, many in-situ crosslinked gelled acid systems generally consist of polymers, an iron crosslinker, and a breaker agent, in addition to other additives. This paper discusses an alternative crosslinker that provides effective diversion with minimal residuals at temperatures up to 275°F.
A non-iron-based crosslinker has been developed for in-situ high-strength gelled acid systems that vary between 5 to 20 wt% HCl acid. The coreflooding experiments were effectively conducted for permeability ranges of up to 70 md. This system showed a stable fluid at downhole conditions, initially building viscosity between a pH range of 1.5 to 3.0. Then, as acid continues to further react with calcium carbonate and the pH becomes higher than 3, the crosslinked fluid begins to break down and the fluid viscosity decreases. Several experiments were conducted to assess the performance of this novel system. Additionally, corrosion tests were performed to evaluate the treatment fluid corrosion rate at a temperature of 275°F.
The testing results show that the evaluated gelled acid system is stable at temperatures up to 275°F. The system profile as a function of pH showed the ability to provide diversion during different stimulation treatments. Additionally, the coreflood results showed that the new gelled acid is capable of forming wormholes without any significant associated formation damage caused by the gel. The effect of corrosion inhibitors on this system at 300°F, along with other additives, was also investigated.
Manuscript Title: Paraffin/Asphaltene Cleaning Formulations-Lab Design and Case Studies
Authors: Stanciu Cornell , Fernandez Jorge M. 
Published: February 2020

Abstract
Paraffin and asphaltene issues are common throughout the Oilfield, from upstream to midstream and even to downstream, costing the industry billions of dollars every year. They range from near wellbore damage to flow restrictions in the tubulars or in the pipes used to transport the hydrocarbons from the production field to contamination of equipment or means of transportation (trucks, tankers, railcars, boats) and to formation of coke deposits in reactors at the processing facilities.
Mitigating the paraffin/asphaltene issues wherever they appear is of high importance to ensure high production/transportation rates. Given the variety of problems, the wide composition ranges of crudes as well as the many differences between reservoir characteristics in different locations the R&D efforts to find efficient solutions to these complex situations have to be very application specific. In this paper we will present a few examples of formulations that were designed by leveraging the in-house expertise in the area along with simple lab methods and techniques, such as design of experiments (DOE), crude chemical analysis, cold finger instrument analysis, optical microscopy, viscosity measurements, Hegman gauge surface cleaning, porous surface cleaning.
The results show how appropriate combinations of surfactants and solvents, specifically designed for each application, can help mitigating the complex issues posed by paraffin/asphaltene precipitation. The influence of various hydrophobes-in both the non-ionic and the anionic surfactants utilized- on the final performance of the designed formulations will be discussed.
Representative case studies will be emphasized to better illustrate the efficacy of the final products in the application space they were designed for. The solvents and surfactants used in these studies are viable alternatives to existing products on the market by offering better environmental profiles, increased efficiency at comparable or lower dosage, functional benefits over two or more applications or cost savings for the users.
Holistic Approach for a Successful Scale Squeeze Treatment Using Core Flood Data from Other Reservoir
Authors: Sundramoorthy Jega Divan , Ibrahim Mohamed Farouk , Nordin Nur Fauzan , Abd Rahim Mohd Adam , Wan Ismail Wan Akmal 
Published: February 2020

Abstract
This paper describes field experience of designing a successful scale squeeze program for an oil well. This was done utilizing an adsorption isotherm derived from a core flood data from other reservoir. Correlation and reliability of the adsorption isotherm with actual field flow back data after squeeze treatment for a period of 18-month are given. Moreover, utilizing the knowledge generated, a bespoke multilayer adsorption isotherm was optimized for a treated well for more efficient squeeze design for next treatment.
In order to achieve our objective, an adsorption isotherm from other reservoir core flood was first generated. With the knowledge not limited to current candidate well production rates, well properties, perforation height, number of zones and other essential parameters, a 18-month squeeze treatment program was designed. Water chemistry 18-month data was utilized to validate the scale squeeze design. An improved multilayer adsorption isotherm bespoke for this well was generated.
In conjunction with flow-back production data, a scheduled sampling program and water analysis utilizing Inductively Coupled Plasma (ICP) for post treatment Scale Inhibitor (SI) residuals data was collected to validate the adsorption isotherm derived from other reservoir. As predicted by the model for post treatment monitoring, the SI residual concentration; back calculated from SI chemistry utilized for the treatment are found to have an excellent correlation with the adsorption isotherm derived from a different reservoir. Hence, the 18-month squeeze design derived from a different reservoir was a great success. The slight difference between real flow back data and the adsorption isotherm generated from other reservoir become a benchmark to derive an improved adsorption isotherm to optimize the scale inhibition protection than the current treatment.
In summary, parameters such as mineralogy study, porosity, permeability, crude properties and dynamic scale loop (DSL) study are the utmost important information to be analyzed prior using other reservoir core flood data as reference. As results shown, these are the best way to generate squeeze design with limited information had in hand.
Engineered Reservoir Drilling Fluid Help Maximize Production in Gulf of Mexico Deepwater Horizontal Well
Authors: Wallace Shawn , Beeson Jeremy , Dalton Ferrill , David Elliot , Henry Ivan 
Published: February 2020

Abstract
A major operator in the Gulf of Mexico (GOM) desired to increase oil production to meet growing energy demand. To meet this challenge, the operator explored an alternate completion design to mitigate reservoir damage observed in previous producing wells and collaborated with the fluids provider to design a solution to address this concern. The design and solution ultimately applied resulted in "negative skin" with production rates far exceeding historical field rates. Additionally, the operator realized significant cost savings with this change in completion approach by eliminating traditional steps.
The development field had its unique challenges with ongoing depletion, wellbore instability risks, and compartmentalization in the reservoir, making access to thinner oil reservoirs challenging to develop. The standard completion approach was to drill with a synthetic-based fluid, perforate the casing, and perform a frac-pack completion. Using technology from another region, the operator elected to change the traditional cased hole frac-pack approach to drilling horizontally through the reservoir, run production screens, and perform an open hole gravel pack completion. In the fluids design phase, the fluids provider performed hydraulics modeling and laboratory testing on multiple formulations, including brine compatibility with formation water; formation response testing; high-pressure/high-temperature (HPHT) rheology and fluid loss; static age testing for intervals of 16 hours, 3 days, and 5 days; and contamination testing with solids, synthetic-based mud, and cement.
This paper discusses the methodology used in the design phase required to engineer a reservoir friendly fluid to meet the challenges faced with this complex well.
Performance Comparison of Novel Chemical Agents for Mitigating Water-Blocking Problem in Tight Gas Sands
Authors: Huang Hai , Babadagli Tayfun , Chen Xin , Li Huazhou , Zhang Yanming 
Published: February 2020

Abstract
Water-blocking can be a serious problem, causing a low gas production rate after hydraulic fracturing; a result of the strong capillarity in the tight sandstone reservoir aggravating the spontaneous imbibition. Fortunately, chemicals added to the fracturing fluids can alter the surface properties and thus prevent or reduce the water-blocking issue. We designed a spontaneous imbibition experiment to explore the possibility of using novel chemicals to both mitigate the spontaneous imbibition of water into the tight gas cores and measure the surface tensions between the air and chemical solutions. A diverse group of chemical species has been experimentally examined in this study, including a cationic surfactant (C12TAB), two anionic surfactants (O242 and O342), an ionic liquid (BMMIM BF4), a high pH solution (NaBO2), two nanofluids (Al2O3 and SiO2), and a series of house-made deep eutectic solvents (DES3-7, 9, 11, and 14). Experimental results indicate that the anionic surfactants (O242 and O342) contribute to low surface tensions, but cannot ease the water-blocking issue due to yielding a more water-wet surface. The high pH solution (NaBO2), ionic liquid (BMMIM BF-4), and brine (NaCl) significantly decrease the volume of water imbibed to the tight sand core through wettability alteration, and the cationic surfactant (C12TAB) leads to both surface tension reduction and an oil-wet rock surface, helping to prevent water-blocking. The different types of DESs and nanofluids exhibit distinctly different effects on expelling gas from the tight sand cores through water imbibition. This preliminary research will be useful in both selecting and utilizing proper chemicals in fracturing fluids to mitigate water-blocking problems in tight gas sands.