bluuebunny/crossref_metadata_2025_split huggingface dataset:
Islam dan Nasionalisme: Pandangan Pembaharu Pendidikan Islam Ahmad Dahlan dan Abdulwahab Khasbullah
Authors: Setiawan Iwan Setiawan 
Published: January 2018

Sampai hari ini, dikotomi antara “Islam” dan “Nasionalis” masih terjadi. Dikotomi ini menjadikan seorang Muslim merasa tidak nyaman dalam pergaulan di masyarakat, khususnya saat bertemu dengan kelompok yang berbeda agama. Pada akhirnya, dikotomi ini menjadikan sebuah pertanyaan “Apakah menjadi Muslim bisa menjadi Nasionalis”? Artikel akan menjawab pertanyaan diatas dengan melihat sejarah dua tokoh pendidikan Islam dan Pahlawan Nasional. Mereka adalah Ahmad Dahlan dan Abdulwahab Khasbullah, dua pendiri organisasi terbesar di Indonesia, Muhammadiyah dan Nahdlatul Ulama. Dengan meneliti tentang dua tokoh Pendidikan Islam di masa Kolonial Belanda sebelum era kemerdekaan, kita bisa menemukan jawaban atas pertanyaan diatas. Tujuan artikel ini untuk menunjukkan bahwa tokoh Islam bernama Ahmad Dahlan dan Abdulwahab Khasbullah adalah seorang Nasionalis. Penelitian ini merupakan Library Research, dimana sumber pustaka diambil dari buku-buku, jurnal, majalah dan Koran. Library Research juga sering disebut dengan istilah penelitian Kepustakaan.
Dynamic Flow Modeling and Risk Mitigation Enables Optimized Perforation Design in Complex Well Completions
Authors: Satti Rajani , Bale Derek , Gilliat Jim , Hillis Parry 
Published: January 2018

Abstract
In recent years, complex well explorations have moved into more challenging environments (ultra-deep, high-pressure/high-temperature (HPHT), extended reach laterals). These environments require a closely integrated and multidisciplinary process to ensure efficiency and mitigate risk. In particular, the process of perforating has called for careful design, planning and execution to prevent costly failures and maximize productivity over the life of the well. The perforating systems used in these environments can place a large dynamic load on downhole equipment. Predicting the magnitude and transient behavior of such loads is a critical step in developing completion designs that can be executed safely while avoiding damage or destruction to downhole tool strings and production equipment. Further, post-job well production rates often depend strongly on the proper choice of perforating job design parameters relating to formation integrity, tunnel cleanup, underbalance management, subsequent stimulation methods, etc. Predicting the complex interdependencies between these parameters is crucial for a successful job.
The simulation software presented in this work is based on a next-generation, dynamic downhole modeling platform that simulates the dynamic response of a cased or uncased wellbore, its contents, and the porous rock formation to the energy released by gas-generating and stored pressure sources. The software is applied to predict dynamic flow around the wellbore/formation, evaluate cleanup and mitigate gun shock loads. For complex well completions, the software incorporates differentiating algorithms for shock-capturing hydrodynamic solvers, improved thermodynamic closure, fluid dynamics and more importantly, significantly faster turnaround simulation times to enable quick pre-job modeling iterations.
The software is comprehensively validated using a variety of benchmarking examples. The improvements in dynamic predictions as well as computational efficiencies with the next-generation software are clearly demonstrated. Beyond standard benchmark cases, the application of this software is demonstrated using successful design examples from wells in the North Sea, Southeast Asia, etc. The simulations presented here provide insight into the complex fluid dynamics between the formation and wellbore, gun shock loads, and how cleanup is maximized and productivity enhanced by subsequent optimization of wellbore/gun systems. In an environment where downhole measurements or laboratory-based testing is impractical, the dynamic modeling software ensures successful execution through pre-job modeling as well as conducting a comprehensive post-job analysis for future planning.
Modeling the Effectiveness of Diverters for Matrix Acidizing Based on Filter Cake Characteristics
Authors: Tan Xuehao , Payne Courtney , Panga Mohan 
Published: January 2018

Abstract
During acidizing treatments in carbonate reservoirs, a degradable diversion system (DDS) is commonly applied to achieve a more uniform distribution of acid along the wellbore. The effectiveness of a DDS strongly depends on the permeability of the filter cake, which is formed by diverter materials that accumulate inside perforation tunnels or on the rock face. A new DDS with a lower filter cake permeability than a conventional DDS is presented, along with a study based on an acidizing model to show the effect of fiber cake permeability on acid diversion.
An existing acidizing model was applied as a tool to evaluate the diversion effect of a DDS. The model was created by considering fluid flow in the wellbore, fluid distribution among reservoir zones, and predicted wormhole propagation inside the formation. The model also has the capability to simulate the formation of filter cake, either inside perforation tunnels or on the rock face, and redistribute the fluid flow accordingly. To fully understand the role of filter cake permeability on the effectiveness of a DDS, simulation cases were established for both a conventional DDS and the newly-introduced, low permeability DDS. The reservoir permeability contrasts among zones was also varied to understand the applicable range of a given DDS. The DDS effectiveness can be evaluated by comparing the simulated bottomhole pressure response and the acid injection rate into each zone.
The simulation results indicate that the low permeability DDS is significantly more effective than the traditional DDS. In all cases, the use of the low permeability DDS predicts a larger pressure response resulting from the temporary blocking of high permeability zones as well as better acid injectivity in low permeability zones. Based on the flow rate distribution, the effect of filter cake permeability is clearly observed up to a permeability contrast of 50 between reservoir zones. By providing a better flow to low permeability reservoir zones, the new DDS demonstrates better diversion performance than the traditional DDS; this results in a more successful acidizing treatment, especially when the permeability contrast of the reservoir zones is high.
Controlling Proppant Wettability Leads to Increase Flowback Recovery and Flow in Frac-Packs
Authors: Bestaoui-Spurr Naima , Langlinais Kevin , Stanley David , Usie Marty , Li Chunlou 
Published: January 2018

Abstract
Recovery of frac-pack fluids is often poor in offshore operations. Large amounts of stimulation fluids left in the fracture may leak-off into the porous formation or block part of the proppant pack thus impairing hydrocarbon production. A typical frac-pack treatment fluid contains water-wetting surfactants to maximize flow-back fluids. However, the amounts recovered are still low and new methods are needed to improve well cleanup. Using a proppant that is neither oil nor water wet has the potential to solve some of these issues.
Proppant surfaces were permanently modified to a neutral wettability state. Molecules having both hydrophobic and oleophobic properties were covalently bonded to the oxide surfaces, leading to robust engineered interfaces with low surface energy thus potentially improving flow. To support this concept of neutral wettability proppant, laboratory studies were conducted to determine performance under flow and cleanup ability compared to native proppant surfaces. This neutral wettability proppant was also used in several completions in the Gulf of Mexico. Two case histories using the neutral wettability proppant are presented and compared with offset wells as well as performance laboratory data. Flowback data as well as production data are reported.
Laboratory results showed that the neutral wettability enhanced surfaces not only reduce water saturation but also improve oil movement. This demonstrates the ability of these materials to improve clean up and hydrocarbon flow within the proppant pack. When this proppant was applied in frac-pack completions it was observed that flow-back recovery was dramatically increased compared to offset wells that used similar proppant. Cleanup time was reduced allowing first oil to appear more rapidly. Furthermore, production data show that oil flow that the productivity index is higher when the surface of the proppant is neutral. These results demonstrate this material as next generation proppant for improving flow and cleanup in frac-pack completions.
A Flow Laboratory Study of an Enhanced Perforating System Designed for Well Stimulation
Authors: Satti Rajani , White Ryan , Ochsner Darren , Sampson Tim , Zuklic Stephen , Geerts Shaun 
Published: January 2018

Abstract
As the industry looks forward to increasing operational efficiencies and maximizing productivity, there has been increasing interest in perforating systems that can combine perforating and well stimulation in a single operation. For this reason, propellants have a unique place in the perforating community as a stimulation/enhancement tool that can significantly improve productivity and lower operator costs. However, in complex well completions (high angle, doglegs or long horizontal wells), friction ignition and other concerns with traditional propellant methods have led to the advent of a new enhanced perforating system, whereby the energetic materials are deployed within the gun body, requiring specific charge performance, and in specially designed carriers.
The enhanced perforating system has been successfully deployed in the field. In the interest of conducting a quantitative evaluation, this study is focused on developing and demonstrating a fit-for-purpose flow laboratory apparatus to evaluate the benefits of the enhanced perforating system using standard API-RP 19B Section-IV procedures. The experimental apparatus was designed to closely represent the actual gun system, whereby the detonation of the perforating charge initiates a complex, sequentially burning reaction of the energetic material that generates a high-pressure gas pulse. A comprehensive testing program in Berea sandstone using shaped charges in conjunction with these energetic propellant materials at representative downhole conditions was conducted.
The analysis from the experimental tests was not limited to standard measurements, but also included advanced interpretation techniques involving high-speed transient pressure analysis, 3D computerized tomography and productivity analysis. Preliminary analysis of the test data showed promising trends with respect to increased peak pressure, improved clean-up and extended tip-region around the perforation tunnel. Furthermore, the HSE aspects of this enhanced system from a laboratory standpoint were also investigated.
In summary, the above study presents a laboratory study and quantitative evaluation of an enhanced perforating system that combines shaped charges and energetic materials. This system has been field proven to assist in pre-frac treatment. The benefits of the system can be further realized in conjunction with frac-optimized perforating systems, whereby frac-treatments are optimized to enhance productivity.
Openhole Mechanical Packer with Eccentric Shunt-Tube Gravel Pack Assembly Reduces Capex and Accelerates Production in Kaombo Deepwater Development, Angola
Authors: Hernandez J. , Lai B. H. , Bahabanian O. , Goyallon D. , Nordin A. A. , Nwafor C. E. , Taleballah E. Y. , Semin L. 
Published: January 2018

Abstract
Field A is a significant contributor within the Kaombo development project, offshore Angola. The field comprises five stacked sedimentary units (A1 through A5, from top to bottom) requiring openhole gravel packs (OHGP) as the sand control technique, and a commingle strategy was key to reducing well count. Production from reservoir A4 could not be commingled with that from other sedimentary layers due to the risk of asphaltene precipitation, and A3, water bearing in one panel, also required isolation. The openhole mechanical packer (OHMP) with OHGP completion was used in field A to reduce the well count from the originally planned eight oil producers (OP) to six OP; this brought savings in excess of USD 100 million. Well 1 in field A penetrates all five reservoirs; it was successfully completed in December 2016 with two OHMPs isolating reservoir A4. A well in field B was successfully completed in May 2017 with one OHMP to allow future water shutoff (WSO) with potential production acceleration as well as estimated ultimate recovery (EUR) increase of more than one million barrel of oil equivalent (MMboe). Downhole gauge data analysis combined with mass balance indicated that 100% pack efficiency was achieved in both wells with the expected packing sequence in the presence of packers bypassed with shunt tubes.
The OHMP enhances the versatility of OHGP completions with eccentric shunt-tube screen assemblies, which enable applications such as selectivity, zonal isolation, and water shutoff. The robustness of OHGP completions together with the features mentioned earlier will improve the economics for future projects by reducing capital expenditure (capex) and increasing reserves recovery per well. This application was an important contributor to reduce drilling expenditure (drillex) for the Kaombo development project.
Causes and Mitigation of Completion Fluids-induced Formation Damage in High Temperature Gas Wells
Authors: Hamzaoui B. S. , Al Moajil A. M. 
Published: January 2018

Abstract
Conventional brine-based completion fluid are used to control the reservoir pressure after drilling operation. It can be then displaced using HP/HT coiled tubing. Injection of the brine-based completion fluid inside the sandstone formation can significantly reduce the operation expenses. However, depending on the fluid/rock properties and composition, formation damage may occur when the fluid is in contact with sandstone formation. This paper presents laboratory results evaluating the damage that may occur during injection of different completion fluids into sandstone core plugs.
This lab work includes core flood testing to study the effect of injecting the completion fluids on the sandstone rock permeability. XRD was conducted for solid and core plugs analysis. ICP was used to analyze the obtained completion fluid. Zeta potential analysis was performed to assess fluid/rock interactions.
No permeability reduction was observed when completion fluids with pH ≤ 10 were injected into the sandstone core plug. However, a reduction of permeability of 76% was observed after injection of high pH completion fluid no. 3 (pH ≥ 10). Zeta potential experiment showed a stable clay charge and minor disturbance to their structure. Completion fluid no. 3 with polymer-based clay stabilizer caused no damage to the rock.
Integrated Image Processing and Computational Techniques to Characterize Formation Damage
Authors: Ezeakacha C. P. , Rabbani A. , Salehi S. , Ghalambor A. 
Published: January 2018

Abstract
Filtrate and solid invasion from drilling fluids are two key sources of formation damage, and can result in formation permeability impairment. Typically, spurt invasion of mud solids causes the evolution of an external mud cake which tends to reduce further solids and filtrate influx. However, uncontrolled spurt and filtrate invasion are detrimental because they reduce the permeability of the formation. Mud composition, formation rock's permeability and porosity, and temperature can influence both spurt and filtrate invasion. The sizes of mud solids relative to the average pore size of a rock are also important in predicting the extent of mud invasion and permeability impairment.
In this paper, a dynamic modeling approach is presented for mud solids deposition on the pores of rock samples for different lithologies. The modeling results were compared to experimental values. To simulate a close-to-real field mud invasion and damage scenario, rock samples were first subjected to a dynamic-radial fluid loss test under controlled laboratory conditions. The geometry of the simulated drill pipe and inner diameter of the cores allowed for uniform mud cake evolution around the wall of the cores. Three different rock samples (Michigan sandstone, Indiana limestone, and Austin chalk) were investigated. Two water-based mud (WBM) samples were formulated to simulate high and low fluid loss recipes. Next, scanning electron microscopy (SEM) imaging of the dry cores coupled with image processing was used to determine the porosity and pore size distribution of the internal mud cake. The structure of the porous rocks as well as the mud cake were modeled using the bundle of curved tubes approach. In addition, the deposition probability of mud solid particles was considered through filtration theories. Experimental results showed up to 40% reduction in mud invasion and damage to the rocks using the low fluid loss recipe. The model developed in this study closely matched the experimental results. The model revealed a maximum relative error of about 9.6% for one out of the six case studies, and an average relative error of 3.3% for other case studies. The novelty in this study is the quantitative utilization of SEM images by applying watershed segmentation algorithm to detect and measure the size of mud cake pore spaces. This approach can be implemented in the design of drilling fluids that can reduce formation damage.
Multifunctional, Salt-Tolerant Friction Reducer Stabilizes Clay Formations and Minimizes the Alteration of Rock Wettability Under Downhole Conditions after Hydraulic Fracturing
Authors: Xu Liang , He Kai , Ariyaratna Ashley , Ogle James 
Published: January 2018

Abstract
Salt-tolerant cationic friction reducers (FRs) have been successfully used in up to 100% high total dissolved solids (TDS) produced water for hydraulic fracturing applications. Cationic FRs, however, may not be compatible with formation rocks that contain quartz or clay that is typically negatively charged under normal pH. In this study, a new cationic FR formulation is introduced that does not appear to alter rock wettability and that releases a clay stabilizing agent over time under downhole conditions.
Flow loop, capillary suction time (CST), turbidity, and zeta potential (ZP) tests are conducted to demonstrate the benefits of using a multifunctional FR that tends to have minimal formation damage toward formation rocks. Flow loop tests qualify the FR as a robust polymer that is salt-tolerant and enables up to 100% re-use of produced water on location. Both CST and turbidity evaluates the efficacy of the clay stabilizing agent that is released from the FR under downhole conditions. ZP measures the surface charge on the rock's surface and determines whether or not significant wettability alteration occurs in the presence of this FR.
Flow loop results verify that the new FR is extremely salt-tolerant up to 300,000 ppm TDS, which was further demonstrated in the Marcellus Shale formation. Both CST and turbidity results suggest that the performance of the clay stabilizer is equivalent to that of a 4% KCl solution, a common temporary clay stabilizer. ZP indicates that the FR became predominantly negatively charged after releasing the clay stabilizing agent, thereby having minimal effect on the original rock wettability.
A Novel Approach to Constant Flow-Rate Sand Retention Testing
Authors: Fischer Christine , Hamby Heidi 
Published: January 2018

Abstract
Sand retention testing for screen selection in soft-sand completions has become an integral component to verify the screen performance. This paper describes an improved constant flow-rate test method developed for sand retention testing. The improved constant flow rate test method simulates an erosional-type failure of the formation onto the gravel pack or screen. This test methodology allows the sand to be injected at known concentration into the brine stream, eliminating mixing and settling issues.
The constant flow rate test procedure utilizes a concentrated slurry of the formation sand in brine. This slurry is then injected into the brine flow-stream to accomplish the desired solids concentration for the test (typically 0.5-1.0%). The method allows for flexibility both in the brine flow-rate used and in the solids concentration tested. The slurry injection is accomplished in a slot-flow cell and is designed such that the brine stream erodes the particles from the face of the slurry as it is injected. The distance to the screen after the solids injection is minimized to overcome faster settling of larger particles.
The constant rate sand retention test method provides the amount of solids produced through the screen, the size of the solids produced through the screen, the retained permeability of the screen, and the pressure increase over time as the formation is deposited on the screen. Detailed in the paper is a reproducibility study that was included in order to verify the test method. Additionally, a comparison between the constant flow rate and constant drawdown test has been conducted using the new constant flow rate test method. The new constant flow rate test method has been found to have greater reproducibility than the previous method. Additionally, the constant flow rate and constant drawdown test have been found to produce similar test results with known exceptions that are detailed in the finding.
The improved constant flow rate test method provides more consistent, reproducible results to assist in determining the optimal sand control screen for a target completion.
Unveil the Unknown: Combining the Laboratory Study of Fracturing Fluids at High Pressure with a State-of-the-Art Hydraulic Fracturing Simulator
Authors: Vernigora Denis , Olennikova Olesya , Parkhonyuk Sergey , Fedorov Andrey , Belyakova Ludmila , Velikanov Ivan , Konchenko Andrey 
Published: January 2018

Abstract
The fracturing fluid is the essential part of any hydraulic fracturing treatment. A borate-crosslinked guar-based fluid is one of the most commonly used types of fluid. The first mention of guar derivatives crosslinked with boron can be traced back to 1977. Scientific papers that describe boron equilibria as a function of the fluid pH can be trackedback to 1966.
Comprehensive studies of the rheological behavior of borate-based fluids were performed in 1980s and 1990s, and for almost 30 years, it has been considered as a well-known topic.
Recently, a few authors reported a significant decrease in viscosity of the fluid at elevated pressure. This decrease was reversible (i.e., as soon as the pressure values are moved back to the normal, the viscosity is recovers). Such effect can significantly affect the stimulation design and outcome because most of the time the slurry is affected by elevated temperatures and pressures.
Still, many questions remained unanswered. One of them is the effect of crosslinker concentration/composition on the stability of the fluid at highpressure. Another is the comparison of the fluid viscosity under the ISO 13503-1 ramp at standard conditions and elevated pressure. The last one concerns the actual values of the fluid rheological parameters, n and K’, under different pressures.
In this paper, we investigate the fracturing fluid behavior under high pressure. For the first time in the industry, we compare the results of ISO fluid stability testing, and the fluid shear recovery under 400-psi pressure and up to 10,500 psi.
Finally, using a novel hydraulic fracturing simulator, the effect of the pressure-sensitivity of the fluid on the proppant transport, fracture geometry, and, subsequently, well productivity will be demonstrated.
The findings of this paper will have noticeable impact on the design of the hydraulic fracturing treatment where borate-crosslinked fluids are used.