bluuebunny/crossref_metadata_2025_split huggingface dataset:
PENGEMBANGAN KOMIK DIGITAL BERKONTEKS LAHAN BASAH PADA MATERI BIOTEKNOLOGI UNTUK MELATIHKAN LITERASI SAINS PESERTA DIDIK
Authors: Zahra Suziana Az , Irhasyuarna Yudha , Yulinda Ratna 
Published: April 2024

Penelitian ini merupakan pengembangan komik digital berkonteks lahan basah pada materi bioteknologi untuk melatihkan literasi sains peserta didik. Tujuan penelitian ini untuk mendeskripsikan validasi, kepraktisan dan keefektifan media pembelajaran yang dikembangkan. Metode pengembangan yang digunakan pada penelitian ini adalah model ADDIE dengan lima tahapan, yakni analysis, design, development, implementation, dan evaluation. Penelitian ini memperoleh hasil validitas materi 99,04% dengan kategori sangat valid, validitas media 84,26% dengan kategori sangat valid, nilai kepraktisan yang didapatkan sebesar 95,5% dengan kategori sangat praktis, dan nilai keefektifan yang didapat sebesar 0,735 dengan kategori tinggi. Berdasarkan hasil penelitian, maka dapat disimpulkan bahwa media pembelajaran yang dikembangkan sangat valid, sangat praktis dan memiliki keefektifan yang tinggi. Oleh karena itu, produk dari penelitian ini dapat digunakan dalam pembelajaran IPA pada materi bioteknologi.Kata kunci: Keefektifan, Kepraktisan, Pengembangan, Validitas. This research is a development of digital comics in the context of wetlands on biotechnology materials to train students' science literacy. The purpose of this study is to describe the validation, practicality and effectiveness of the learning media developed. The development method used in this study is the ADDIE model with five stages, namely analysis, design, development, implementation, and evaluation. This study obtained the results of 99.04% material validity with a very valid category, 84.26% media validity with a very valid category, a practicality value obtained of 95.5% with a very practical category, and an effectiveness value obtained of 0.735 with a high category. Based on the results of the study, it can be concluded that the learning media developed are very valid, very practical and have high effectiveness. Therefore, the products of this research can be used in science learning on biotechnology materials.Keywords: Effectiveness, Practicality, Development, Validity.
Analisis Aktivitas Senyawa Antioksidan Pada Berbagai Daun Tanaman Herbal dengan Metode DPPH
Authors: Asrifaturofingah Asrifaturofingah , Listiowati Eni , Matsna Fadhila Uzlifati , Putriliana Salsabila Zulfa , Ulya Nur Afni Himmatul 
Published: April 2024

Radikal bebas dapat berpengaruh terhadap kesehatan manusia, maka diperlukan senyawa antioksidan yang mampu menangkal radikal bebas. Penelitian ini memiliki tujuan mengidentifikasi senyawa antioksidan yang terdapat pada berbagai daun tanaman menggunakan metode DPPH. Metode penulisan literatur review menggunakan penelusuran jurnal dari Google Scholar, dan Publish or Perish yang dipublikasi pada tahun 2014 – 2022 dengan berbagai kata kunci. Berdasarkan hasil literatur review diperoleh 10 jurnal, dengan variasi daun tanaman antara lain daun kersen (Muntingia calabura L.) daun afrika (Vernonia amygdalina Del.), daun salam (Eugenia polyantha), daun sirsak (Annona muricata L.), daun kesambi (Schleira oleosa), daun patikala (Etlingera elatior (Jack) R.M.Sm), daun putri malu (Mimosa pudica Linn), daun gedi hijau (Abelmoschus manihot (L.) Medik), daun ciplukan (Physalisan gulata L.), daun mangga (Mangifera indica L.). Hasil antioksidan yang paling kuat ditemukan pada daun kersen (Muntingia calabura L.) dengan nilai IC50 6,82 ppm dan 9,01 ppm melalui proses ekstraksi maserasi. Adapun aktivitas antioksidan dengan kategori terlemah yaitu daun Afrika (Vernonia amygdalina Del) dengan nilai IC50 371,98 ppm dan 557,058 ppm melalui proses ekstraksi maserasi. Kata Kunci: Daun Kesambi, Daun Kersen, Daun Sirsak, Daun Afrika, Daun Salam Free radicals can affect human health, so we need antioxidant compounds that can counteract free radicals. This study aims to identify antioxidant compounds found in various plant leaves using the DPPH method. The literature review writing method uses journal searches from Google Scholar, and Publish or Perish which were published in 2014 – 2022 with various keywords. Based on the results of the literature review, 10 journals were obtained, with various types of plant kersen leaves (Mangifera indica L.), African leaves (Vernonia amygdalina Del.), salam leaves (Eugenia polyantha), soursop leaves ( Annona muricata L.), kesambi leaves (Schleira oleosa), patikala leaves (Etlingera elatior (Jack) R.M.Sm), putri malu leaves (Mimosa pudica Linn), gedi hijau leaves (Abelmoschus manihot (L.) Medik), ciplukan leaves ( Physalis gulata L.), mango leaves (Mangifera indica L.). The strongest antioxidant results were found in kersen leaves (Muntingia calabura L.) with IC50 values of 6.82 ppm and 9.01 ppm through the maceration extraction process. The antioxidant activity in the weakest category was African leaf (Vernonia amygdalina Del) with an IC50 value of 371.98 ppm and 557.058 ppm through the maceration extraction process.
A Data-Based Continuous and Predictive Viscosity Model for the Oil-Surfactant-Brine Microemulsion Phase
Authors: Talapatra Akash , Nojabaei Bahareh , Khodaparast Pooya 
Published: April 2024

Abstract
This study presents a computationally produced data-based model/correlation that can accurately estimate the magnitude and predict the peaks of microemulsion viscosity at dynamic reservoir conditions. Equilibrium molecular dynamics (MD) simulation is used on a decane-SDS-brine interfacial system to generate a dataset of viscosity values as a function of different temperatures, surfactant concentrations, and salinities. The viscosity testing and training data are computationally measured using the Einstein relation of the Green-Kubo formula. Several machine learning (ML) based regression algorithms, including K-nearest Neighbors (KNN), Support Vector regression (SVR), Multivariate Polynomial Regression (MLPR), Light Gradient Boosting Machine (LGBM), and Decision Tree (DT), are used to train the model. The SVR regression provides the best performputaance for our model compared to other methods with an R2 (0.978 and 0.963 for train and test data, respectively) and mean absolute error value (0.059 and 0.072 for train and test data, respectively). The chosen model is then used to predict microemulsion viscosity for different reservoir conditions. The proposed model aims to accurately estimate microemulsion viscosity at dynamic reservoir conditions with variable input parameters such as pressure, temperature, brine salinity, and surfactant concentration, enabling accurate estimation and prediction of the transport properties of reservoir fluids and present phases at reservoir conditions, which is key to achieving maximum recovery during chemical EOR.
Surfactant Huff n Puff Field Trials in Eagle Ford Shale – A Treatment Design Comparative Analysis
Authors: Ataceri I. Z. , Haddix G. W. , Schechter D. S. , Brock V. A. , Raney K. H. , Strickland C. W. , Morris G. R. , Nasrabadi H. 
Published: April 2024

Abstract
This investigation focuses on contrasting surfactant huff ‘n’ puff (HnP) treatments in two Eagle Ford Shale wells, specifically examining the influence of a polylactic acid (PLA) diverter used in the second. This work demonstrates surfactants as an effective enhanced oil recovery (EOR) strategy and highlights how the treatment design can impact the recovery outcome.
This work presents an in-depth field analysis with supporting laboratory experiments and statistical modeling to evaluate the surfactant's performance in both wells. Laboratory tests assessed surfactant efficacy in altering wettability and facilitating spontaneous imbibition in the presence of the PLA diverter and with different Eagle Ford samples. Post-stimulation monitoring of produced water for total dissolved solids (TDS) and surfactant concentration demonstrates the extent of treatment dispersion to the formation. A statistical model established performance expectations in the absence of surfactant treatment as a basis for evaluating the effectiveness and uncertainty of EOR uplifts.
Both field trials demonstrated significant improvements to oil recovery, uplifting oil rates from two to five times the production rates before treatment. 95% of the injected surfactant remained adsorbed within the reservoir leading to improvements persisting with a continued recovery uplift extending beyond two years and incremental recoveries ranging from 2,200 to 4,000 barrels of oil. The implementation of a polylactic acid (PLA) diverter in the second trial succeeded in dispersing the treatment throughout high and low-conductivity fractures. This tailored approach led to a more moderate but sustained incremental oil recovery, highlighting the diverter's strategic impact for future stimulation designs. Additional laboratory results underscored that local variations in Eagle Ford reservoir characteristics and the altered fluid dynamics introduced by the PLA diverter did not substantially impact surfactant performance.
Crucially, this research elucidates the PLA diverter's impact on surfactant HnP treatment outcomes, expanding on design strategies for EOR in unconventional reservoirs. Despite limited improvements with diverter for this specific treatment, these findings indicate potential benefits of controlled diversion for larger treatments and higher producing wells. This contribution is pivotal for refining EOR methodologies, and optimizing surfactant treatments for effective and efficient recovery strategies tailored to the unique challenges of unconventional reservoirs.
Chemical EOR Field Support Including Surfactant Blending Studies and Quality Control for Shale and Tight Assets
Authors: Pinnawala Gayani W. , West Scott , Nizamidin Nabi , Alexis Dennis A. , Dwarakanath Varadarajan 
Published: April 2024

Abstract
One of the key components of surfactant related chemical EOR is the surfactant formulation package. After developing a surfactant formulation, delivering it to a target field and assuring similar or better performance is challenging. Since most surfactant formulations contain multiple components, delivering these surfactants as a blend rather than as individual components helps to maintain the correct ratio of components in the surfactant formulation and reduces potential for error during mixing and injection. Thorough quality assurance and quality control (QA/QC) processes support the surfactant blend product performing as designed in field applications. These fundamental steps were applied when deploying surfactant technology which optimizes fracturing fluids for stimulation of shale and tight formations. This paper describes two surfactant formulations developed by Chevron Upstream Labs and successfully deployed in the field. We discuss blending methods, laboratory QA/QC experiments results, field compatibility and aqueous stability test results of mainly two surfactant blends. The paper also describes critical assurance activities that were used to ensure execution excellence.
Modeling Phase Behaviour of Solvents/Water/Heavy Oil Systems Under Reservoir Conditions with the PC-SAFT Equation of State
Authors: Li Yunlong , Huang Desheng , Dong Xiaomeng , Yang Daoyong 
Published: April 2024

Abstract
As for conventional cubic equations of state (CEOSs), they find their limits in precisely predicting phase behaviour in systems featuring a broad spectrum of molecular sizes, especially liquid densities. Based on the perturbation theory, the statistical associating fluid theory (SAFT) has been used as a standard approach to describe how complex fluids and fluid mixtures with a substantial disparity in molecular sizes behave; however, its application is still limited in heavy oil-associated mixtures due to fundamental and technical challenges. In this work, a perturbed-chain (PC) SAFT equation of state (EOS) has been developed to characterize heavy oil-associated systems containing polar components (e.g., dimethyl ether (DME) and water) and non-polar components (e.g., CO2 and N2) with respect to their phase behaviour and physical properties. Experimentally, constant composition expansion (CCE) tests were meticulously conducted to measure saturation pressure (Psat), phase volume, and phase compositions for CO2/heavy oil, N2/heavy oil, and DME/heavy oil systems in the absence and presence of water, spanning a range of pressure up to 20 MPa and temperature up to 433.2 K. Theoretically, a PC-SAFT EOS model together with temperature-independent binary interaction parameters (BIPs) is integrated to reproduce the measured Psat and other physical properties of the aforementioned systems. It is experimentally found that addition of water into each of the aforementioned systems will increase its Psat compared to that without water. By characterizing heavy oils as four pseudocomponents (PCs), the density (ρ) of the aforementioned systems can be accurately predicted with the root-mean-squared relative error (RMSRE) of 1.84%. Then, the BIPs for each binary pair of the aforementioned systems are obtained by minimizing the discrepancy between the measured Psat and the calculated ones. The proposed model shows its superior performance over the widely used CEOS (i.e., Peng-Robinson EOS) with an RMSRE of 2.93% for the predicted Psat of the aforementioned systems. The theoretical model proposed in this study excels to reproduce the experimentally measured phase behaviour and physical properties under reservoir conditions, allowing us to accurately evaluate and optimize the hybrid steam-solvent processes in a heavy oil reservoir.
Establishing Target Oil in a Major Oil Field Under Gas Assisted Gravity Drainage
Authors: Valdez R. , Pennell S. P. 
Published: April 2024

Abstract
Technical analysis and data gathering methods are presented for establishing the lowest depth of development in a shallow, highly fractured San Andres dolomite field currently being developed under Gas Assisted Gravity Drainage (GAGD). Expanding development deeper is critical for extending the field life and managing long term drilling and CO2 injection. The field underwent a first phase of GAGD from 1992 through 2000 restoring the oil-water contact down to the discovery depth of +1050 feet above sea level (ASL).
Several steps were taken to quantify the transition zone target for expansion including field wide data gathering, areal performance analysis, and a dedicated pilot or demonstration project. Data gathering included saturation logging of several existing open-hole observation wells. Pilot hole drilling and logging prior to horizontal well re-drills was also utilized. Dimensionless performance analysis and modeling were used to compare both areal and vertical variations in development. Finally, an extensive pilot project was initiated in 2021 which included a de-watering test, sponge coring and & laboratory analysis, horizontal drilling and repeat saturation logging to demonstrate the feasibility and commerciality of deeper development.
Logging showed oil saturations as high as 50% down to a range of depths from +1000 to +990 feet ASL and rapid declining saturation to the imbibition free water level of +960 ASL. Deeper rock properties also showed similar reservoir porosity, permeability and fracture intensity as the shallower horizons. Performance analysis showed varied oil response closely tied to fracture intensity and oil column thickness (OCT). The demonstration pilot had several key findings: 1) de-watering of the reservoir to expand the GAGD process and gas cap could be established within several months, 2) the lowest depth of mobile (or target) oil is +990 feet ASL, 3) horizontal wells drilled to a depth of +990 feet ASL showed two distinct oil responses: a) oil production from reconnecting the oil column plus additional drained oil from contact lowering and b) 100% water production for several months prior to oiling in from contact lowering. The two distinct responses also coincided with OCT in the fractures and oil-water contact level prior to deepening. The combined response was observed in the Eastern part of the pilot with 20 foot OCT and OWC at +985 feet ASL versus the Western part of the pilot at 5 foot OCT and OWC varying from +1005 to +990 feet ASL.
Prior to field testing development deeper into the transition zone, GAGD core laboratory experiments showed remaining oil saturation as low as 15% could be achieved. The intensive data gathering and field demonstration showed incremental reserves could be achieved. This has resulted in extending the drilling program several more years, lowering of the contacts further and additional oil recovery.
The Effect of Polyethylene Oxide on Residual Oil Saturation of Low Permeability Carbonates
Authors: Laudon S. , Balhoff M. , Mohanty K. 
Published: April 2024

Abstract
The objective of this paper is to investigate the transport and incremental oil recovery associated with Polyethylene Oxide (PEO) compared to Hydrolyzed Polyacrylamide (HPAM) through a series of corefloods in low permeability carbonate cores for use in enhanced oil recovery (EOR). Recent studies have brought attention to PEO's improved injectivity in low permeability carbonate reservoirs compared to acrylamide-based polymers offering a promising alternative (Mejia et al., 2022a; Mejia et al., 2022b; Trine et al., 2022). Five two-phase experiments were conducted in Indiana limestone cores (permeability &lt;100 mD) with PEO and HPAM of similar molecular weights (4 MM Dalton) and viscosity; they were designed to measure incremental oil recovery for both polymers. Tracer tests were completed to determine heterogeneity. Brine was displaced by a 50-cP oil, and initial oil saturations averaged 55.8%. The oil was displaced initially with a waterflood for 3-5 pore volumes. The waterflood, on average, recovered 60.7% of original oil in place (OOIP). Oil cut was consistently zero at the conclusion of the waterflood suggesting the cores were at or near residual oil saturation. The polymer flood followed the waterflood for three pore volumes or until oil cut was zero. HPAM was injected in the first two experiments, and PEO was injected in the final three. When HPAM was injected, oil production in terms of OOIP from the polymer flood was minimal (average 2.2%) which was expected since oil saturation was presumed near residual. However, in the experiments when PEO was injected, oil production from the polymer flood averaged 13.5%, suggesting that residual oil saturation was decreased by the polymer. PEO was consistently shown to produce more oil compared to HPAM. This work suggests that PEO may result in higher oil recoveries and reduced residual oil saturation under certain conditions.
Investigating Imbibition Rate and Oil Recovery Mechanisms from Fractured Formations by Hybrid EOR Approaches
Authors: Kashiri Razieh , Bukayev Azamat , Pourafshary Peyman 
Published: April 2024

Abstract
Enhanced Oil Recovery (EOR) methods play a crucial role in producing significant volumes of trapped hydrocarbons within fractured oil-wet reservoirs. These methods aim to modify the fluid-rock interactions, reduce interfacial tension, and alter the wettability of the reservoir to increase the total oil recovery. Imbibition is the fundamental mechanism for fluid transport between matrix and fracture within fractured formations. Different EOR mechanisms affect the imbibition by altering capillary-related parameters such as wettability and interfacial tension. The rate of spontaneous imbibition is different during different EOR techniques, such as surfactant flooding, low salinity water injection, and hybrid methods. The effect of the type of capillary modifications on the imbibition rate was studied in this work.
This study delves into a series of spontaneous imbibition tests aimed at scrutinizing imbibition rates across diverse EOR strategies: low salinity water flooding, surfactant flooding, and hybrid EOR approaches for fractured reservoirs. The effect of parameters such as pH was also investigated. The oil recovery due to the alteration in capillary force during the spontaneous imbibition was recorded, and the imbibition rate was analyzed based on recovery/square root of time data. Furthermore, an array of parameters, including interfacial tension, ion composition, and pH, were measured and studied to investigate the mechanisms behind varied imbibition rates. The impact of imbibition rates on the forced imbibition process was also assessed, striving for a comprehensive understanding of imbibition dynamics during EOR strategies.
The results showed a significant difference in imbibition rates between standalone low salinity water flooding imbibition and surfactant solutions. Our studies demonstrated that the rate of capillary pressure alteration due to changes in interfacial tension surpasses the rate of alteration caused by shifts in the wettability state. Application of the hybrid method enhances the imbibition rate, which affects the oil recovery from a fractured formation. Under high pH conditions, the imbibition rate exhibited a low initial rate, followed by substantial increases by the injected water dilution. Conversely, under acidic conditions, the trend was reversed due to the activation of different low salinity water-related recovery mechanisms.
The significance of this investigation goes beyond the laboratory setting, extending its impact to the practical realm of designing processes within fractured reservoirs. By illuminating the complicated interplay between pH, water salinity, capillary, and imbibition rates, this study serves as a vital base for designing hybrid approaches that optimize EOR techniques tailored to fractured reservoirs’ complexities.
Evaluation of Electroassisted Carbonated Water Injection (ECWI) in a Tight Reservoir: Outstanding Performance of Enhancing Oil Recovery and CO2 Storage Capacity
Authors: Jia Zejiang , Ning Zhengfu , Lyu Fangtao , Yang Daoyong 
Published: April 2024

Summary
Traditionally, carbonated water injection (CWI) finds its low injectivity in a tight reservoir with a low efficiency and slow effectiveness. By combining a direct current (DC) electric field with the CWI, i.e., the electroassisted CWI (ECWI), we conducted a series of experiments to evaluate the ECWI performance in a tight reservoir and identify the key underlying recovery mechanisms. Experimental results show that early adopting the ECWI in a tight sandstone reservoir results in the highest oil recovery up to 61.9%, compared to those of 51.2% for the CWI and 41.3% for the conventional waterflooding. During an ECWI process, a voltage of 10 V achieves the highest oil recovery, but that of 15 V has the best water injectivity and CO2 storage capacity. It is found that the underlying recovery mechanisms result from both electroosmosis and enhancement of carbonized water-rock reactions induced by a DC electric field. For a tight reservoir, the ECWI has the advantages of significantly increasing water injectivity, oil production rate, and CO2 storage capacity. By introducing two new indicators to respectively evaluate the water injection performance and energy consumption, the ECWI is found to perform moderately well at a low voltage in an energy-saving and financially viable manner.