bluuebunny/crossref_metadata_2025_split huggingface dataset:
Exploring the Philosophy of the Local Wisdom of “Gusjigang” for Understanding Zakat and Tax Compliance
Authors: Budiman Nita Andriyani , Nurkamid Mukhamad , Sriyana Jaka , Afandi Akhsyim , Gunawan Budi , Mulyani Sri 
Published: October 2023

<em>Zakat and tax play a crucial role in fostering the development of a country. Zakat is an obligation for Muslims, while tax is an obligation for all citizens. Therefore, this research aims to explore the prevailing local wisdom in the Kudus community, in order to gain insights into how these obligations are observed and complied with. The local wisdom philosophy of the Kudus community, known as ‘Gusjigang’, originated from the esteemed heritage of Holy Sunan. It embodies the values of good behavior, studiousness, and tenacious trading (entrepreneurship). Grounded by this philosophy, this study aims to comprehend the motivations behind the adherence of local entrepreneurs to zakat and tax using a case study approach. Following this, in order to gather relevant data, qualitative open-ended interviews and document analysis were employed as the primary source of data collection. Through this process, it was found that the prioritization of zakat over tax stems from the religious regulations and laws, which take precedence over the mandates of fellow human beings. It is also important to note that from the perspective of the zakat administration, the distribution of zakat was considered more transparent and fairer as evidenced by the insights gleaned from the interviews. </em>
Microemulsions in the Oil and Gas Industry: A Review
Authors: Gangwar Aayushi Jagat , Maitra Sthitadhi 
Published: October 2023

Abstract

Objectives/Scope
Drilling fluids are crucial to the oil and gas industry, and so is the removal of filter cake formed by them. Pertaining to this, new improvisations are being made to achieve better rheology along with some other favorable properties. One of these advancements is the use of microemulsions as drilling fluids or as cement pre-flush. Novel microemulsion flushing fluids have been constructed for the effective removal of mud cake. The use of drilling fluids also creates the inevitable problem of formation damage, wherein the drilling fluid penetrates the formation and causes a decrease in permeability. Microemulsions have been used effectively to combat such damage caused by drilling fluids.

Methods, Procedures, Process
The main aim while preparing a drilling fluid is to obtain optimum rheology. And this is where microemulsions helped. The chemical/physical properties and damage mechanism of the formation were analyzed using several experimental methods, including X-ray diffraction, scanning electron microscopy, core inhibition test, etc. To develop an environmentally friendly drilling fluid, the main microemulsion system was constructed using an aqueous phase (water-glycerol solution 1:1), an oil phase (pine vegetable oil), and varying nonionic surfactants (Tween 80, nonylphenol ethoxylates 100 and 150). Two types of clays (filtration control) were used in the formulation of fluids, Brasgel PA and Cloisite 20 A, in the presence of a viscosifier (xanthan gum), a weighting agent (baritone), a sealant (calcite), and dispersant (water). For the effective removal of mud cake, the microemulsions for the flushing fluid were prepared with vegetable castor oil, 2%wt KCl as an aqueous phase, and a nonionic surfactant (Ultranex NP40). Various tests were performed to evaluate the performance of the flushing fluid formed.

Results, Observations, Conclusions
The use of microemulsion systems has led researchers to develop economical, environment-friendly, thermally stable, non-toxic drilling fluid or cement pre-flush that has low solid content, and low fluid loss. Microemulsions-based drilling fluids have also been used successfully to combat the problem formation damage in the Sulige gas field, in China.

Novel/Additive Information
This paper will review the numerous ways in which microemulsion systems are being incorporated into the oil and gas industry, particularly in drilling. It can help a drilling engineer come up with the Most Unexceptional way to prepare a microemulsion suitable for his needs, after going through the various methods and the properties achieved by them.
A New Effective Method for Complex Fracture Evaluations in Fractured Sandstone Reservoirs
Authors: Jia Tingting , Wang Chao , Jin Wenqi , Zhao Xudong , Li Jun , Tang Bo , Yue Lu , Wen Kaifeng , Jiang Tingting , Dong Peng 
Published: October 2023

Abstract
Ultra-deep fractured low-porosity sandstone gas reservoir is the most realistic unconventional oil and gas resource to be developed in China. However, reservoir is naturally fractured, non-homogeneous and artificially fractured, which makes the traditional analytical well test analysis method not applicable. To address this problem, the fractures are classified and characterized into small, medium and long scales according to practical understanding. A multi-scale fracture characterization method is developed utilizing a dual-porosity model to depict uniformly developed small fractures, while a discrete fracture model is employed to characterize medium and long fractures. Further, a numerical well-testing model for ultra-deeply fractured low-porosity sandstone reservoirs is established, namely a multi-scale dual porosity dual-zone composite model. Results show that the flow regimes can be classified as: wellbore storage and skin effect, acid-fracture influence, inner zone influence, transition flow, outer zone influence, and boundary effect. Based on the established numerical well-testing model, sensitivity analysis of the parameters is performed and well-test curve plates are drawn. It is observed that an increase in the number and length of natural fractures resulted in a deepening of the "depression" in the pressure derivative curve and a decrease in pressure losses within the test well. The curve characteristics in the early stages are predominantly influenced by acid-fracture parameters, whereas the degree of "depression" and its manifestation is impacted by the storage ratio and interporosity-flow coefficient. Finally, field applications are carried out to verify the reliability of the model. Notably, the target blocks are characterized by well-developed yet heterogeneous natural fractures. The results show that our numerical well testing analysis method has demonstrated greater accuracy and effectiveness in analyzing and interpreting such reservoirs.
Graphene Nanoplatelets for Extended Lifetime of Scale Inhibitor Squeeze Treatment in High Temperature Reservoir
Authors: Zainal Suzalina , Razali Norzafirah , Rodzali Mohamad Azmeer 
Published: October 2023

Abstract
Scale inhibitor squeeze (SISQ) treatment is an established method for offshore fields which allows an extended effectiveness of the scale inhibitors in preventing scale deposition over time. Some of the main issues in SISQ campaign is the short squeeze lifetime being less than 1 year which may be contributed by operational and well integrity issues as well as ineffective design of the pre-flush system.
This study proposed graphene nanoplatelets as pre-flush system to extend the lifetime of a conventional scale inhibitor squeeze treatment. This carbon-based nanomaterial known for its high specific surface area provided an excellent pre-coating on the rock matrix, allowing an enhanced adsorption of the phosphonate-based scale inhibitor.
Special attention was given to the study on stability of the graphene nanoplatelets (GNP) in high divalent injection water and its functionalization with biopolymer to provide good dispersibility in the seawater at high temperature condition. This paper focuses on the compatibility evaluations of GNP in seawater, its dispersion and thermal stability assessment up to 96oC temperature, followed by an innovative static adsorption experiment using Berea crushed cores which served to establish the improvement in scale inhibitor adsorption at different GNP concentrations. For in-depth performance evaluations in downhole porous media, injectivity and adsorption-desorption scale squeeze treatment coreflooding experiments using Berea and reservoir native cores at high temperature conditions were then tmperformed. Finally, prediction on the field squeeze lifetime were simulated using Place-iT™ software.
Results shown that the scale inhibitor's adsorption increased by more than 100% when 200 ppm of modified GNP was used as pre-flush compared to conventional pre-flush system. Good injectivity profiles, showing Residual Resistance Factor (RRF) of less than 3, coupled with slower desorption rate of scale inhibitor were observed from the coreflooding results. The simulated scale squeeze lifetime improved up to additional 14 months compared to baseline. Graphene nanoplatelets have demonstrated its versatility as nanocoating agent in enhancing scale inhibitor squeeze lifetime, extending its application as downhole high temperature production enhancement chemical.
Kuwaiti Carbonate Reservoir Oil Recovery Prediction Through Static Wettability Contact Angle Using Machine Learning Modeling
Authors: Al-Sayegh Saleh , Flori Ralph , Al-Bazzaz Waleed Hussien , Al-Saedi Hasan , Al-Kaouri Mostafa , Qubian Ali 
Published: October 2023

Abstract
The objective of this study is to predict EOR efficiencies through static wettability contact angle measurement by Machine Learning (ML) modeling. Unlike conventional methods of measuring static wettability contact angle, the unconventional digital static wettability contact angle is captured and measured, then (ML) modeled in order to forecast the recovery based on wettability distribution phenomenon. Due to success in big data collection from reservoir imaging samples, this study applies data science lifecycle logic and utilizes Machine Learning (ML) models that can predict the recovery through wettability contact angles and thus identify the treatment of oil recovery for a candidate reservoir.
Using developed morphological driven pixel-data and transformed numerical wettability contact angle data are acquired from Scanning Electron Microscope Backscattered Electron (SEM-BSE) for 27 fresh core samples from top to bottom of the reservoir. These samples are properly sequenced and then images are selected. Big data from imaging technology have been processed in a manner to train, and test the model accuracy. Applied Data Science Lifecycle technique, such as data mining, is utilized. Data Exploration Analysis (DEA) is implemented to understand and review data distribution as well as relationships among input features. Different supervised ML models to predict recovery are utilized and an optimal model is identified with an acceptable accuracy. The selected prediction model is applied to model the optimal recovery practice.
Extreme Gradient Boosting (XGBoost) algorithm is utilized and found as a best-fit model for this Kuwaiti reservoir case practice. Moreover, decision tree and Artificial Neural Network (ANN) models could provide acceptable accuracy. Other supervised learning models were attempted and were not promising to provide feasible accuracy for this carbonate reservoir.
The novel of this unique solution of the data-driven ML model is to predict recovery based on static wettability contact angles (θ°). The static wettability contact angles (θ°) and pore morphological features introduce an insights method to support reservoir engineers in making value-added decisions on production mechanisms and hydrocarbon recovery for their reservoirs. Hence, it improves the field development strategy.
Optimizing the Carbon Footprint of Polymer Injection Utilizing a Deep Learning Log Interpretation Framework
Authors: Katterbauer Klemens , Al Shehri Abdallah , Hassan Saleh , Yousef Ali 
Published: October 2023

Abstract
The world of energy industries is exhibiting tremendous efforts to ensure the sustainability of its operations and reduce its carbon footprint. These efforts include optimizing field operations to be more sustainable while maintaining production levels. The 4th Industrial Revolution is having enormous impact on the oil and gas industry, also allowing better analysis of carbon footprint reduction opportunities. Modern logging technologies are able to accurately characterize the formation and measure its production behavior. Polymer injection technologies have the potential to significantly reduce water cut, thereby helping to optimize the carbon footprint. We evaluated the impact of various polymer injection strategies on the Volve field with several production and injection wells to simulate the impact of injecting polymers on the fluid production rates. The injection of polymers helps in reducing the water production rates from the reservoir, thereby reducing the carbon footprint related to the handling of the produced water and injection of water. Various scenarios were evaluated in order to determine the overall impact on carbon emissions and based on a probability-likelihood framework the overall carbon footprint was determined. While the optimal injection strategy may depend on various factors, polymers demonstrate the ability to reduce significantly the overall carbon footprint while increasing hydrocarbon production.
Learning from Water Injection Pilot in a Low Permeability Reservoir Developed with Hydraulically Fractured Horizontal Wells – ABH Field Case Study
Authors: Singh Ranjeet , Agarwal Prashant , Saurav _ , Gupta Sumit , Mandapati Suresh Kumar 
Published: October 2023

Abstract
Aishwariya Barmer Hill (ABH) is a Porcellanite oil reservoir located in the northern part of Barmer Basin in India. The formation has low permeability of ~1mD, an average porosity of 25% and has in-situ oil viscosity of ~3 cP. The ABH field has been developed with long horizontal wells with multistage hydraulic fracturing under depletion drive. The current estimated RF is 10-12% on depletion drive. To improve the RF, water flood was evaluated as the next stage of development. This paper discusses the results of water injection pilot within a complex setting with hydraulically fractured producer (observation) wells and impact of injection below and above frac pressure.
Two short term injectivity tests and one long term injection pilot have been conducted in ABH field. Concepts like injection above and below frac pressure and injection in a hydraulic fractured well and a non-hydraulic fractured well were tested.
The long-term injection pilot comprised of a vertical injector and two hydraulically fractured horizontal producers on it's either side. As the injection pressure was above frac pressure, data like time lapse Pressure Fall Offs (PFOs) was acquired to understand waterflood induced frac parameters. Production logging and bottom-hole pressure surveys were also conducted to understand injection profiles.
Minimal injectivity was attained below frac pressure but good injectivity with sustained rate was observed above it. PTA analysis shows that fractures are induced due to water injection and time lapsed PFOs were analyzed to estimate the induced fracture parameters. Some unique signature of frac closure was also observed in PTA. Increase in water cut of one of the producer well was observed, however most of the injected water was getting imbibed into the reservoir. Role of injection water quality was also evaluated which may cause drop in injectivity and continuous frac growth. Numerical simulation was carried out to history match the observed injection performance. This indicated changes in effective permeability during injection and shut-in periods.
Careful consideration of injection pressure, well design and pattern selection is critical for designing water flood in a low permeability reservoir with hydraulically fractured wells and this pilot was able to answer many questions related to it. The pilot suggested that below frac pressure injection may be required in on-trend well pattern. Poor quality injection water can cause growth of induced fracture. Response time on producer is a key consideration impacting project economics. Improving recovery from tight field development is a key area of focus and ABH pilot results will help to understand /solve some of the key considerations related to it.
Physical Simulation and Improved Numerical Simulation Method of Non-Condensable Gas Co-Injection in SAGD Process
Authors: Liang Guangyue , Liu Yang , Xie Qian , Xia Zhaohui , Liu Shangqi , Zhou Jiuning , Bao Yu 
Published: October 2023

Abstract
There are great differences about the distribution of non-condensable gas (NCG) in steam chamber between field observations and numerical simulations. Field observations show that the process could reduce steam consumption significantly but no evidence of impairment to oil production especially in mid to late SAGD life. However, this point isn't consistent with current numerical simulations. Therefore, this paper presents an improved numerical simulation method of non-condensable gas co-injection to validate the physical simulation results.
Solubility experiments of methane, nitrogen and carbon dioxide in oil phase at different pressure and temperature were conducted to analyze the interface properties, and 1D core experiments to understand the displacement characteristics. On the basis, 3D physical simulations were conducted with each gas in SAGD process. These results were inconsistent with conventional numerical simulations. In order to narrow the gap, sensitivity analysis was conducted by using CMG STARS software considering different grid size, solubility or K-value in oil and water phase, rate-dependent dissolution and ex-solution of NCG in oil. Non-equilibrium dissolution and ex-solution behavior and reaction equations were incorporated to successfully improve the numerical simulation results.
The experimental tests indicate that the solubility and compressibility of methane fall in between nitrogen and carbon dioxide. Then 3D visualized physical simulations with methane, nitrogen or flue gas co-injection and shale interlayer existence were conducted to analyze the law of NCG distribution, steam chamber growth and SAGD performance. NCG tends to accumulate at the top rather than the drainage edge of steam chamber, decrease the temperature of reservoir top by about 30°C, reduce heat loss to the cap rock and improve steam to oil ratio (SOR). Compared with other gases, carbon dioxide decrease oil viscosity most and achieve higher displacement efficiency. Also, it succeeds in improving the flow characteristics of steam chamber front, maintaining pressure, stabilizing or slightly lowering oil production and reducing steam injection significantly by co-injection with these NCG at increasing proportion, when steam chamber reaches the top of reservoir. Particularly, NCG can penetrate thin shale interlayer, allow steam passing through and help accelerate vertical steam chamber growth. Finally, the parameters were optimized using improved field-scale model such as solvent type, co-injection concentrations and timing, etc.
The novelty of this paper is successfully revealing NCG distribution law in steam chamber by visualized physical simulations. Particularly, it also captures the phenomenon that the existence of NCG can help steam chamber penetrate the shale interlayer. The findings narrow the gap among field observations, physical and numerical simulation and can guide NCG co-injection optimization.
Simple Sidetrack to Remediate Wells with Mechanical Downhole Problem: A Case Study of Open Hole Gravel Pack Well Intervention
Authors: Pramesty Denissa Pramesty , Monhendri Riko Monhendri , Pambudi Deny Eva Tri , Wijanarko Iwan Wijanarko 
Published: October 2023

Abstract
DF field is first steam flood project in Indonesia and one of the biggest steam flood oil fields in the world. The field has shallow reservoir and unconsolidated sand formation. There are several oil well completion types but majority production wells are open hole completion with gravel pack as sand control. Over time, some wells have sand control equipment failures and result unwanted formation sand production that cause oil production restriction and artificial lift failures. To remediate the problem, well intervention (which named as revise liner) jobs are required to pull out failed screen liner then replace with the new one. Basic procedure consists of pull-out existing pump, pull out lead seal, wash over the screen to remove gravel pack sand and continue with screen liner retrieval. Reaming job is required to clean out the open hole section before running new screen assembly and be gravel packed. The job will be ended by running in hole new pump.
However, several workover jobs could not be completed as planned due to downhole mechanical problems as results of aging wells and steam injection factors. In 2022, 7 of 23 screen replacement jobs were unsuccessful and majority due to failure to wash-over and recover old screens. A common solution to recover production from these problem wells is to plug & abandon the failed wells and drill new replacement wells. Even that so, this solution required significant time and cost that impede project economic.
Increasing number of loss oil production (LOP) due to sand control failure has triggered team to identify alternative solutions that economically feasible. This aligned with management strategy to increase oil production by minimizing LOP. Analyzing several alternatives, team came up with an idea to recover the screen by cutting it above free point at open hole section. Having sufficient open hole section below casing shoe will allow reaming job to open hole section in adjacent to existing hole.
Having conducted thorough risk assessment, team decided to execute first trial. The first job was deemed successful as it was able to reach target depth similar to existing hole. Screen liner assembly can be installed, and gravel sand can be packed without significant issue. This successful trial has encouraged the team to execute more wells with some refined procedure based on lessons learned from the first well. As of to date, total 3 wells have been completed successfully using this new method. Gravel pack logging also confirmed that gravel pack quality was not compromised.
This new practice has now become new method to recover production on wells having mechanical down hole problem in DF field. This practice is part of revise liner job conducted by workover rig with lower cost compared to conventional side track or drilling new wells.