Energy Geoscience最新文献

{"title":"Advancements in hydrogen storage technologies: Integrating with renewable energy and innovative solutions for a sustainable future","authors":"Yasin Khalili ,&nbsp;Sara Yasemi ,&nbsp;Mohammadreza Bagheri ,&nbsp;Ali Sanati","doi":"10.1016/j.engeos.2025.100408","DOIUrl":"10.1016/j.engeos.2025.100408","url":null,"abstract":"<div><div>Hydrogen storage plays a crucial role in achieving net-zero emissions by enabling large-scale energy storage, balancing renewable energy fluctuations, and ensuring a stable supply for various applications. This study provides a comprehensive analysis of hydrogen storage technologies, with a particular focus on underground storage in geological formations such as salt caverns, depleted gas reservoirs, and aquifers. These formations offer high-capacity storage solutions, with salt caverns capable of holding up to 6 TWh of hydrogen and depleted gas reservoirs exceeding 1 TWh per site. Case studies from leading projects demonstrate the feasibility of underground hydrogen storage (UHS) in reducing energy intermittency and enhancing supply security. Challenges such as hydrogen leakage, groundwater contamination, induced seismicity, and economic constraints remain critical concerns. Our findings highlight the technical, economic, and regulatory considerations for integrating UHS into the oil and gas industry, emphasizing its role in sustainable energy transition and decarbonization strategies.</div></div>","PeriodicalId":100469,"journal":{"name":"Energy Geoscience","volume":"6 2","pages":"Article 100408"},"PeriodicalIF":0.0,"publicationDate":"2025-04-04","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"143839331","PeriodicalName":null,"FirstCategoryId":null,"ListUrlMain":null,"RegionNum":0,"RegionCategory":"","ArticlePicture":[],"TitleCN":null,"AbstractTextCN":null,"PMCID":"","EPubDate":null,"PubModel":null,"JCR":null,"JCRName":null,"Score":null,"Total":0}

{"title":"Physics-integrated neural networks for improved mineral volumes and porosity estimation from geophysical well logs","authors":"Prasad Pothana,&nbsp;Kegang Ling","doi":"10.1016/j.engeos.2025.100410","DOIUrl":"10.1016/j.engeos.2025.100410","url":null,"abstract":"<div><div>Accurate estimation of mineralogy from geophysical well logs is crucial for characterizing geological formations, particularly in hydrocarbon exploration, CO₂ sequestration, and geothermal energy development. Current techniques, such as multimineral petrophysical analysis, offer details into mineralogical distribution. However, it is inherently time-intensive and demands substantial geological expertise for accurate model evaluation. Furthermore, traditional machine learning techniques often struggle to predict mineralogy accurately and sometimes produce estimations that violate fundamental physical principles. To address this, we present a new approach using Physics-Integrated Neural Networks (PINNs), that combines data-driven learning with domain-specific physical constraints, embedding petrophysical relationships directly into the neural network architecture. This approach enforces that predictions adhere to physical laws. The methodology is applied to the Broom Creek Deep Saline aquifer, a CO₂ sequestration site in the Williston Basin, to predict the volumes of key mineral constituents—quartz, dolomite, feldspar, anhydrite, illite—along with porosity. Compared to traditional artificial neural networks (ANN), the PINN approach demonstrates higher accuracy and better generalizability, significantly enhancing predictive performance on unseen well datasets. The average mean error across the three blind wells is 0.123 for ANN and 0.042 for PINN, highlighting the superior accuracy of the PINN approach. This method reduces uncertainties in reservoir characterization by improving the reliability of mineralogy and porosity predictions, providing a more robust tool for decision-making in various subsurface geoscience applications.</div></div>","PeriodicalId":100469,"journal":{"name":"Energy Geoscience","volume":"6 2","pages":"Article 100410"},"PeriodicalIF":0.0,"publicationDate":"2025-04-04","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"143816086","PeriodicalName":null,"FirstCategoryId":null,"ListUrlMain":null,"RegionNum":0,"RegionCategory":"","ArticlePicture":[],"TitleCN":null,"AbstractTextCN":null,"PMCID":"","EPubDate":null,"PubModel":null,"JCR":null,"JCRName":null,"Score":null,"Total":0}

{"title":"Microscopic pore-throat structure and fluid mobility of tight sandstone reservoirs in multi-provenance systems, Triassic Yanchang formation, Jiyuan area, Ordos basin","authors":"Quanpei Zhang ,&nbsp;Chen Yang ,&nbsp;Ye Gu ,&nbsp;Yu Tian ,&nbsp;Hui Liu ,&nbsp;Wen Xiao ,&nbsp;Zhikun Wang ,&nbsp;Zhongrong Mi","doi":"10.1016/j.engeos.2025.100407","DOIUrl":"10.1016/j.engeos.2025.100407","url":null,"abstract":"<div><div>The tight sandstone reservoirs in the first sub-member of Chang 7 member (Chang 7₁) of Triassic Yanchang Formation in the Jiyuan area, Ordos Basin, show significant variations in microscopic pore-throat structure (PTS) and fluid mobility due to the influences of the northeast and northwest dual provenance systems. This study performed multiple experimental analyses on nine samples from the area to determine the petrological and petrophysical properties, as well as the PTS characteristics of reservoirs in different provenance-controlled regions. On this basis, the pore-throat size distribution (PSD) obtained from high-pressure mercury injection (HPMI) was utilized to convert the NMR movable fluid <em>T</em>₂ spectrum, allowing for quantitative characterization of the full PSD and the occurrence characteristics of movable fluids. A systematic analysis was conducted on the primary controlling factors affecting fluid mobility in the reservoir. The results indicated that the lithology in the eastern and western regions is lithic arkose. The eastern sandstones, being farther from the provenance, exhibit higher contents of feldspar and lithic fragments, along with the development of more dissolution pores. The reservoir possesses good petrophysical properties, low displacement pressure, and high pore-throat connectivity and homogeneity, indicating strong fluid mobility. In contrast, the western sandstones, being nearer to the provenance, exhibit poor grain sorting, high contents of lithic fragments, strong compaction and cementation effects, resulting in poor petrophysical properties, and strong pore-throat heterogeneity, revealing weak fluid mobility. The range of full PSD in the eastern reservoir is wider than that in the western reservoir, with relatively well-developed macropores. The macropores are the primary space for occurrence of movable fluids, and controls the fluid mobility of the reservoir. The effective porosity of movable fluids (EPMF) quantitatively represents the pore space occupied by movable fluids within the reservoir and correlates well with porosity, permeability, and PTS parameters, making it a valuable parameter for evaluating fluid mobility. Under the multi-provenance system, the eastern and western reservoirs underwent different sedimentation and diagenesis processes, resulting in differential distribution of reservoir mineral components and pore types, which in turn affects the PTS heterogeneity and reservoir quality. The composition and content of reservoir minerals are intrinsic factors influencing fluid mobility, while the microscopic PTS is the primary factor controlling it. Low clay mineral content, well-developed macropores, and weak pore-throat heterogeneity all contribute to the storage and seepage of reservoir fluids.</div></div>","PeriodicalId":100469,"journal":{"name":"Energy Geoscience","volume":"6 2","pages":"Article 100407"},"PeriodicalIF":0.0,"publicationDate":"2025-04-02","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"143816085","PeriodicalName":null,"FirstCategoryId":null,"ListUrlMain":null,"RegionNum":0,"RegionCategory":"","ArticlePicture":[],"TitleCN":null,"AbstractTextCN":null,"PMCID":"","EPubDate":null,"PubModel":null,"JCR":null,"JCRName":null,"Score":null,"Total":0}

{"title":"Dominant performance parameter and technical limits of surfactants for oil displacement","authors":"Yabing Guo ,&nbsp;Youqi Wang ,&nbsp;Zengmin Lun ,&nbsp;Maolei Cui","doi":"10.1016/j.engeos.2025.100406","DOIUrl":"10.1016/j.engeos.2025.100406","url":null,"abstract":"<div><div>In chemical flooding, emulsification and interfacial tension (IFT) reduction are crucial for enhanced oil recovery (EOR). However, the dominant performance parameter and technical limits of surfactants for oil displacement remain underexplored. This study investigated the relationship between the emulsification capability and IFT. Accordingly, the dominant performance parameter and the technical limits of surfactants were determined using oil displacement experiments. Specifically, an analysis of 74 sets of experimental results revealed a shift in the significant correlation between <em>EI</em> (a quantitative measure of emulsification capability) and <em>σ</em> at an <em>σ</em> value of 8.5 × 10⁻² mN/m (i.e., critical value <em>σ</em>_c). For <em>σ</em> &lt; <em>σ</em>_c, emulsification capability and IFT function as independent performance parameters. The oil displacement experiments using two surfactants with contrasting <em>EI</em> and <em>σ</em> values demonstrate that emulsification capability, rather than ultra-low IFT, is the dominant performance parameter. This study determined the technical limit of <em>EI</em> using oil displacement experiments via in-situ emulsification. The experimental results indicate strong correlations of <em>EI</em> with oil displacement and recovery efficiencies. The incremental displacement and recovery efficiencies were employed to quantify the potential of surfactants to enhance oil displacement and recovery efficiencies, respectively. The incremental displacement and recovery efficiencies versus <em>EI</em> curves revealed a critical <em>EI</em> (<em>EI</em>_c) value of 0.53. When <em>EI</em> &lt; <em>EI</em>_c, the incremental displacement and recovery efficiencies increased significantly with <em>EI</em>. In contrast, when <em>EI</em> &gt; <em>EI</em>_c, their increasing rates slowed down markedly. Therefore, the technical limits of the emulsification capability and IFT of surfactants used in this study are determined at <em>EI</em> ≥ 0.53 and <em>σ</em> ≤ 8.5 × 10⁻² mN/m, respectively.</div></div>","PeriodicalId":100469,"journal":{"name":"Energy Geoscience","volume":"6 2","pages":"Article 100406"},"PeriodicalIF":0.0,"publicationDate":"2025-04-01","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"143799396","PeriodicalName":null,"FirstCategoryId":null,"ListUrlMain":null,"RegionNum":0,"RegionCategory":"","ArticlePicture":[],"TitleCN":null,"AbstractTextCN":null,"PMCID":"OA","EPubDate":null,"PubModel":null,"JCR":null,"JCRName":null,"Score":null,"Total":0}

{"title":"A data-driven approach to predict fracture intensity using machine learning for presalt carbonate reservoirs: A feasibility study in the Mero Field, Santos Basin, Brazil","authors":"Eberton Rodrigues de Oliveira Neto ,&nbsp;Fábio Júnior Damasceno Fernandes ,&nbsp;Tuany Younis Abdul Fatah ,&nbsp;Raquel Macedo Dias ,&nbsp;Zoraida Roxana Tejada da Piedade ,&nbsp;Antonio Fernando Menezes Freire ,&nbsp;Wagner Moreira Lupinacci","doi":"10.1016/j.engeos.2025.100404","DOIUrl":"10.1016/j.engeos.2025.100404","url":null,"abstract":"<div><div>Predicting fracture intensity is essential for optimising reservoir production and mitigating drilling risks in the Brazilian pre-salt layer. However, previous studies rely excessively on conceptual models and typically do not integrate multiple types of data to perform such task. Moreover, to date, no feasibility-like studies have assessed the reasonableness of such approaches. We propose a data-driven approach that utilises upscaled well logs (Young's modulus, Poisson's ratio, and silica content) alongside seismic attributes (curvature, distance to fault) to predict fracture intensity. The distance to fault is measured using the fault probability volume estimated by a pre-trained convolutional neural network (CNN). We evaluate the effectiveness of this data-driven approach employing two tree-ensemble models, eXtreme Gradient Boosting (XGBoost) and Random Forest, to estimate the volumetric fracture intensity (P32) in the wells. Regression and residual analyses indicate that XGBoost outperforms Random Forest. Results from feature importance methods, such as permutation importance and Shapley Additive explanations (SHAP), highlight curvature as the most important feature, followed by distance to fault, Young's modulus (or P-Impedance), silica content, and Poisson's ratio. The approach has been validated with rock sampling information and two blind tests. Consequently, we believe this workflow can be applied to other wells in nearby fields. The study offers a valuable tool for quantitatively estimating fracture intensity in pre-salt reservoirs. Future research may use this study as a reference for estimating fracture intensity within a seismic volume. The predicted fracture intensity estimates can enhance the reliability of reservoir porosity models and serve as a geohazard indicator to mitigate drilling risks.</div></div>","PeriodicalId":100469,"journal":{"name":"Energy Geoscience","volume":"6 2","pages":"Article 100404"},"PeriodicalIF":0.0,"publicationDate":"2025-03-29","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"143816084","PeriodicalName":null,"FirstCategoryId":null,"ListUrlMain":null,"RegionNum":0,"RegionCategory":"","ArticlePicture":[],"TitleCN":null,"AbstractTextCN":null,"PMCID":"","EPubDate":null,"PubModel":null,"JCR":null,"JCRName":null,"Score":null,"Total":0}

{"title":"Optimizing the development plan for oil production and CO2 storage in target oil reservoir","authors":"Xiliang Liu ,&nbsp;Hao Chen ,&nbsp;Yang Li ,&nbsp;Weiming Cheng ,&nbsp;Yangwen Zhu ,&nbsp;Hongbo Zeng ,&nbsp;Haiying Liao","doi":"10.1016/j.engeos.2025.100405","DOIUrl":"10.1016/j.engeos.2025.100405","url":null,"abstract":"<div><div>Carbon dioxide enhanced oil recovery (CO₂-EOR) technology is used for oil production and CO₂ storage in reservoirs. Methods are being constantly developed to optimize oil recovery and CO₂ storage during the CO₂ displacement process, especially for low-permeability reservoirs under varying geological conditions. In this study, long-core experiments and trans-scale numerical simulations are employed to examine the characteristics of oil production and CO₂ storage. Optimal production parameters for the target reservoir are also proposed. The results indicate that maintaining the pressure at 1.04 to 1.10 times the minimum miscible pressure (MMP) and increasing the injection rate can enhance oil production in the early stage of reservoir development. In contrast, reducing the injection rate at the later stages prevents CO₂ channeling, thus improving oil recovery and CO₂ storage efficiency. A solution-doubling factor is introduced to modify the calculation method for CO₂ storage, increasing its accuracy to approximately 90 %. Before CO₂ breakthrough, prioritizing oil production is recommended to maximize the economic benefits of this process. In the middle stage of CO₂ displacement, decreasing the injection rate optimizes the coordination between oil displacement and CO₂ storage. Further, in the late stage, reduced pressure and injection rates are required as the focus shifts to CO₂ storage.</div></div>","PeriodicalId":100469,"journal":{"name":"Energy Geoscience","volume":"6 2","pages":"Article 100405"},"PeriodicalIF":0.0,"publicationDate":"2025-03-28","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"143768353","PeriodicalName":null,"FirstCategoryId":null,"ListUrlMain":null,"RegionNum":0,"RegionCategory":"","ArticlePicture":[],"TitleCN":null,"AbstractTextCN":null,"PMCID":"OA","EPubDate":null,"PubModel":null,"JCR":null,"JCRName":null,"Score":null,"Total":0}

{"title":"Quantitative analysis of pore evolution and its application in basin simulation:A case study of Chang 6 reservoir in Heshui area, Ordos Basin, NW China","authors":"Ting Shang ,&nbsp;Meijuan Chu ,&nbsp;Xiaolei Zhang ,&nbsp;Bin Wang ,&nbsp;Jihong Li ,&nbsp;Huiruo Zhang ,&nbsp;Zhongyi Zhang ,&nbsp;Xin Liu","doi":"10.1016/j.engeos.2025.100403","DOIUrl":"10.1016/j.engeos.2025.100403","url":null,"abstract":"<div><div>In recent years, fueled by significant advancements in oil exploration technologies within the Ordos Basin, an increasing number of low-permeability or ultra-low-permeability reservoirs have been identified. Elucidating their reservoir characteristics and formation mechanisms has become a critical priority for sustainable hydrocarbon development. The study focused on the Chang 6 Member of the Upper Triassic Yanchang Formation in the Heshui area of the Ordos Basin, systematically investigating its petrological features, porosity and permeability characteristics, diagenesis, and diagenetic evolution sequence. By integrating core observation, thin-section identification, and physical property measurements, a comprehensive quantitative evaluation of reservoir pore evolution was performed. These analytical outcomes were subsequently applied to simulate hydrocarbon migration and accumulation. These research results will provide a scientific basis for in-depth quantitative study of the pore evolution in ultra-low-permeability oil reservoirs and accurately constructing basin models. As indicated, the reservoir lithology in the study area predominantly comprises siltstone interbedded with mudstone or argillaceous siltstone, characterized by low porosity and permeability. Through diagenetic characteristics-based reconstruction constrained by the existing porosity data, pore evolution during diagenesis was quantitatively modeled. The simulated pore evolution aligns with actual geological observations, validating the reliability of the methodology. Furthermore, the quantified pore evolution results were applied to simulate hydrocarbon migration using <em>PetroMod</em> software, showing that hydrocarbon charging in the basin began at the end of the Late Jurassic (J₃), peaking in hydrocarbon generation, expulsion, and accumulation by the end of the Early Cretaceous (K₁) and maintaining high accumulation rates until the late Cretaceous, though significantly decreasing at the present stage. The simulation results were verified by comparison with actual drilling data, which confirms their reliability and applicability to other analogous oilfields.</div></div>","PeriodicalId":100469,"journal":{"name":"Energy Geoscience","volume":"6 2","pages":"Article 100403"},"PeriodicalIF":0.0,"publicationDate":"2025-03-27","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"143844046","PeriodicalName":null,"FirstCategoryId":null,"ListUrlMain":null,"RegionNum":0,"RegionCategory":"","ArticlePicture":[],"TitleCN":null,"AbstractTextCN":null,"PMCID":"","EPubDate":null,"PubModel":null,"JCR":null,"JCRName":null,"Score":null,"Total":0}

{"title":"A preliminary evaluation of carbon dioxide sequestration in coal seams at the Mae Moh mine, northern Thailand: A review","authors":"Piyaphong Chenrai","doi":"10.1016/j.engeos.2025.100402","DOIUrl":"10.1016/j.engeos.2025.100402","url":null,"abstract":"<div><div>The Mae Moh lignite-fired power plant is the only lignite-fired power plant and is the main point source of CO₂ emissions in Thailand. This power plant uses lignite supplied from the Mae Moh lignite open-pit mine in the same vicinity. Carbon dioxide sequestration technologies can play a crucial role in reducing carbon emissions in the energy sector, particularly in coal-fired power plants. This case study provides the first assessment of the potential for geological CO₂ storage in coal seams at the Mae Moh coal mine in northern Thailand based on literature reviews. The Mae Moh Basin is a rift basin with a complex normal fault and contains coal seams at different depths separated by claystones. The geological setting potentially offers favorable conditions for the geological storage of CO₂ in the coal seams through a combination of physical and chemical trapping mechanisms. The findings suggest that the Mae Moh coal mine is suitable for geological CO₂ storage, especially in K and Q coal seams. However, leakage risks, storage capacity, and CO₂-water-coal reactions could be problematic. Thus, more subsurface studies should be carried out, and more detailed criteria should be considered before CO₂ sequestration is undertaken in the Mae Moh coal mine.</div></div>","PeriodicalId":100469,"journal":{"name":"Energy Geoscience","volume":"6 4","pages":"Article 100402"},"PeriodicalIF":3.6,"publicationDate":"2025-03-26","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"145157949","PeriodicalName":null,"FirstCategoryId":null,"ListUrlMain":null,"RegionNum":0,"RegionCategory":"","ArticlePicture":[],"TitleCN":null,"AbstractTextCN":null,"PMCID":"","EPubDate":null,"PubModel":null,"JCR":null,"JCRName":null,"Score":null,"Total":0}

{"title":"A comprehensive review of factors affecting wellbore integrity in CO2 injection wells","authors":"Faysal Ahammad,&nbsp;Saman Azadbakht","doi":"10.1016/j.engeos.2025.100401","DOIUrl":"10.1016/j.engeos.2025.100401","url":null,"abstract":"<div><div>The preservation of the integrity of CO₂ injection wells holds immense significance for the efficacy of Carbon Capture and Storage (CCS) projects. This is attributable to the fact that a wellbore exhibiting robust mechanical and flow integrity substantially diminishes the likelihood of CO₂ leakage into the overlying aquifer or release to the atmosphere, thereby curtailing associated risks. Given the potential hazards and repercussions stemming from the failure of CO₂ injection wells, encompassing environmental catastrophes, financial implications, and health risks, it is imperative to earnestly address these challenges through adept management and monitoring protocols. This study aims to advance the current understanding and enhance the management of wellbore integrity issues in CO₂ injection wells. Accordingly, this review paper undertakes a thorough exploration of the primary factors influencing wellbore integrity in CO₂ injection wells. Furthermore, it delineates a pressing necessity for more exhaustive investigations regarding the influence of CO₂ injection rate, CO₂ purity, and wellbore geometry on wellbore integrity.</div></div>","PeriodicalId":100469,"journal":{"name":"Energy Geoscience","volume":"6 2","pages":"Article 100401"},"PeriodicalIF":0.0,"publicationDate":"2025-03-24","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"143739141","PeriodicalName":null,"FirstCategoryId":null,"ListUrlMain":null,"RegionNum":0,"RegionCategory":"","ArticlePicture":[],"TitleCN":null,"AbstractTextCN":null,"PMCID":"OA","EPubDate":null,"PubModel":null,"JCR":null,"JCRName":null,"Score":null,"Total":0}

{"title":"Linking energy consumption to ecological footprint in sub-Saharan Africa with education as a moderator","authors":"Solomon Prince Nathaniel ,&nbsp;Risikat Oladoyin Dauda ,&nbsp;Kazeem Bello Ajide","doi":"10.1016/j.engeos.2025.100398","DOIUrl":"10.1016/j.engeos.2025.100398","url":null,"abstract":"<div><div>Low levels of environmental education, energy consumption, and other anthropogenic factors strongly contribute to the rising temperature in the world's atmosphere. As such, this study reveals how energy consumption and education affect the ecological footprint (<em>EF</em>) and also determines the education thresholds for <em>EF</em> sustainability in sub-Saharan Africa (SSA). The estimation methods in this study are strictly second-generation econometric techniques because of the problems of slope heterogeneity and cross-sectional dependence discovered in the preliminary analysis. The results confirm cointegration, warranting the need for long-run parameter estimators. The Augment Mean Group estimator suggests that natural resources, non-renewable energy consumption (<em>NRE</em>), and economic growth increase the <em>EF</em>. Although renewable energy consumption (<em>REN</em>) and globalization reduce the <em>EF</em>, these indicators are insignificant. The results of the Method of Moment Quantile Regression (MMQR) reveal that <em>REN</em> exacts an indirect effect on the <em>EF</em> via education. Furthermore, the education thresholds required for ecological sustainability have been established. In line with these outcomes, it is proposed that the region redesign its energy policy to encourage eco-friendly consumption by leaning more on pro-environmental strategies and tightening environmental regulations.</div></div>","PeriodicalId":100469,"journal":{"name":"Energy Geoscience","volume":"6 2","pages":"Article 100398"},"PeriodicalIF":0.0,"publicationDate":"2025-03-17","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"143705527","PeriodicalName":null,"FirstCategoryId":null,"ListUrlMain":null,"RegionNum":0,"RegionCategory":"","ArticlePicture":[],"TitleCN":null,"AbstractTextCN":null,"PMCID":"OA","EPubDate":null,"PubModel":null,"JCR":null,"JCRName":null,"Score":null,"Total":0}