Energy Geoscience最新文献

{"title":"Fault sealing effect on hydrocarbon accumulation in the Yuquan area of the Xihu Sag, East China Sea Basin","authors":"Zhongcai Zhang ,&nbsp;Jingdong Liu ,&nbsp;Jianjun Huang ,&nbsp;Shaohua Wang ,&nbsp;Jianjian Zhuang ,&nbsp;Qihang Zhang ,&nbsp;Hai Yang","doi":"10.1016/j.engeos.2025.100466","DOIUrl":"10.1016/j.engeos.2025.100466","url":null,"abstract":"<div><div>This study examines the effect of fault sealing on hydrocarbon accumulation in the Xihu Sag where NE- and NNE-striking faults within the sag prevent the escape of trapped oil and gas. Analyses like the shale gouge ratio (<em>SGR</em>), shale smear factor (<em>SSF</em>), and fault lateral sealing coefficient (<em>F</em>_h) are used for a quantitative evaluation of the lateral sealing capacity of faults in the Yuquan area of the Xihu Sag. Paleo-structural sections reconstructed using cross-section balancing techniques are used to analyze the evolutionary characteristics of fault sealing. The results indicate that the lateral sealing capacity of faults is mainly controlled by fault throw, clay content, and sand–shale distribution characteristics; in the Yuquan area, fault segments exhibit good lateral sealing when the <em>SGR</em> exceeds 0.5, the <em>SSF</em> is less than 2.5, and the <em>F</em>_h is greater than 10.5. The methodology for evaluating fault sealing evolution, established using structural reconstructions during key geological periods, shows that fault sealing capacity increased gradually over time; in the Xihu Sag, effective sealing of the main hydrocarbon-bearing intervals began during the Liulang period. Evaluating fault sealing capacity is also crucial for estimating the rate of hydrocarbon accumulation, and typically shows a positive correlation with gas (oil) column height. In the Yuquan area, the volume of hydrocarbons sealed by the faults increased progressively over time, with a relatively high overall fault sealing capacity during the second hydrocarbon accumulation period. This study provides valuable insights into the evaluation of fault sealing capacity as well as an investigation of the relationship between faults and hydrocarbon migration–accumulation in the Xihu Sag and analogous geological settings.</div></div>","PeriodicalId":100469,"journal":{"name":"Energy Geoscience","volume":"6 4","pages":"Article 100466"},"PeriodicalIF":3.6,"publicationDate":"2025-12-01","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"145048442","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":"Delineation of depth to basement and subsurface structures beneath the Gerad Graben, western Sirt Basin, Libya, from gravity and aeromagnetic data","authors":"Abdelhakim Eshanibli ,&nbsp;Nur Azwin Ismail ,&nbsp;Hussin B. Ghanush ,&nbsp;Abdullatif Dugdug ,&nbsp;Osagie Abel Uyimwen ,&nbsp;Nabil Khalifa ,&nbsp;Abed Alrauf M. Aushah ,&nbsp;Khiri A. Khalf","doi":"10.1016/j.engeos.2025.100468","DOIUrl":"10.1016/j.engeos.2025.100468","url":null,"abstract":"<div><div>This study integrates gravity and aeromagnetic datasets to delineate basement depth and characterise the subsurface structural framework of the Gerad Graben in the western Sirt Basin, Libya. Techniques including high-pass filtering, Centre for Exploration Targeting (CET) edge detection, Source Parameter Imaging (SPI), and Euler Deconvolution (ED) were applied to residual gravity and residual reduced-to-pole (RTP) magnetic data to enhance fault mapping and basement morphology. Tests of various cutoff wavelengths show that 10 km for gravity and 15 km for magnetic data provide optimal resolution of shallow structures while preserving deeper trends. Forward 2D GM-SYS modelling and Werner Deconvolution further constrained the geometry and depth of intrusive bodies and fault systems. Results reveal a structurally complex graben with NE-SW, NW-SE, ENE-WSW, and N-S trending faults, indicating multiphase tectonic deformation. Graben-bounding faults show displacement values of 600–4290 m, and basement depths in the central depocenter reach 4275–4300 m, validated by well NTF-50. Magnetic anomalies indicate intrusive igneous bodies, including NW-SE-trending sills and dikes, associated with the Tibesti and Al Haruj volcanic provinces. These intrusions likely caused localised heating, uplift, and fault reactivation. The integrated interpretation supports a tectono-magmatic evolution involving successive rifting phases from the Paleozoic to Cenozoic, influenced by inherited Precambrian structures. These features, coupled with substantial sediment infill and magmatic activity, enhance the hydrocarbon potential of the Gerad Graben, suggesting the presence of structural and stratigraphic traps within the broader of Sirt Basin petroleum system.</div></div>","PeriodicalId":100469,"journal":{"name":"Energy Geoscience","volume":"6 4","pages":"Article 100468"},"PeriodicalIF":3.6,"publicationDate":"2025-12-01","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"145120943","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":"Key geological and engineering technologies and research directions for shale gas exploration and development in western Hubei Province, China","authors":"Guangyou Zhu,&nbsp;Jineng Jin,&nbsp;Qilin Xiao,&nbsp;Lei Wang,&nbsp;Guanglong Sheng,&nbsp;Jun Tang,&nbsp;Jianghui Meng,&nbsp;Zhiyuan Lu,&nbsp;Can Chen","doi":"10.1016/j.engeos.2025.100460","DOIUrl":"10.1016/j.engeos.2025.100460","url":null,"abstract":"<div><div>Multiple sets of marine shale sequences occur in western Hubei Province and its adjacent areas within the Middle-Upper Yangtze region, offering substantial resource potential. However, their shale gas preservation conditions differ significantly due to the heterogeneous porosity and fracture system resulting from multistage tectonic reworking. This necessitates developing region-specific evaluation systems and exploitation techniques. Drawing on previous application cases and guided by the research paradigm of geology-engineering integration, this study presents key technologies potentially applicable to shales in western Hubei Province, spanning from reservoir and sweet spot evaluation to fracturing scheme design and fracturing performance monitoring. Several insights are gained accordingly. In terms of pore evaluation, the pore heterogeneity caused by compaction and rebound can be quantified using ideal shape coefficients and fractal dimensions, both of which are influenced by structural deformations, thereby guiding reservoir classification. For seismic data interpretation, pre-stack elastic inversion and azimuthal anisotropy inversion can be employed as core techniques, overcoming the limitation of individual post-stack attributes in typically detecting only major faults. Furthermore, the inversion boundaries are constrained using log-seismic joint quality control and geomechanical simulation, contributing to enhanced reliability of sweet spot evaluation and efficient exploration in areas with complex structures. For fracturing scheme design, scientifically formulated well shut-in strategies, tailored to regional geological characteristics, are essential to activate the fracture-matrix imbibition effect. Parameters with vastly different scales used in the design, such as meter-scale fracture half-length and millidarcy-scale fracture conductivity, can be co-optimized using artificial intelligence (AI) algorithms such as the genetic algorithm (GA) and the simultaneous perturbation stochastic approximation (SPSA) algorithm. Dynamic monitoring of fracturing performance can be achieved using trace chemical tracer technology, thereby reducing target ambiguity caused by structural complexity. Research on shale gas in the structurally complex areas of western Hubei faces multiple challenges, spanning from basic geological understanding to development engineering. These challenges create an urgent need for deep interdisciplinary collaboration. Therefore, this study highlights research into geology-engineering integration, aiming to enhance the efficiency of shale gas exploration and development in western Hubei.</div></div>","PeriodicalId":100469,"journal":{"name":"Energy Geoscience","volume":"6 4","pages":"Article 100460"},"PeriodicalIF":3.6,"publicationDate":"2025-12-01","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"144879014","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":"Hydrocarbon source rock potential of the Late Cretaceous sediments in the Asaga–Ohafia Axis, Afikpo Basin, Nigeria: Insights from facies and kerogen analyses","authors":"Samuel Okechukwu Onyekuru ,&nbsp;Timothy Chibuike Anyanwu ,&nbsp;Kenneth Okechukwu Nwosu ,&nbsp;Ifeyinwa Juliana Ofoh ,&nbsp;Francis Begianpuye Akiang ,&nbsp;Obinna Chigoziem Akakuru ,&nbsp;Onyema Uchenna Achukwu–Ononye ,&nbsp;Kalu Kalu Ibe ,&nbsp;Godwin Okumagbe Aigbadon","doi":"10.1016/j.engeos.2025.100447","DOIUrl":"10.1016/j.engeos.2025.100447","url":null,"abstract":"<div><div>This study investigated the hydrocarbon source rock potential of the Late Cretaceous Mamu and Nkporo formations in the Asaga–Ohafia Axis, Afikpo Basin, southeastern Nigeria, using integrated facies analysis, organic geochemical and palynofacies data. Five lithofacies were identified: dark grey shale, oolitic limestone, heterolithic mudstone/sandstone, laminated bioturbated sandstone, and calcareous mudstone, indicating estuarine, deltaic, and shallow marine depositional environments. Total organic carbon (<em>TOC</em>) contents range from 1.47 to 2.40 wt%, which reflects moderate to good organic richness. For the Mamu Formation, kerogen composition is dominated by Type II/III, composed of 30 %–50 % amorphous organic matter (<em>AOM</em>), 5 %–10 % liptinite, 30 %–50 % vitrinite, and 10 %–20 % inertinite. Spore coloration and Thermal Alteration Index (<em>TAI</em>: 3–3+) suggest thermal maturity within the oil window (<em>R</em>_o: 0.80 %–1.50 %). In contrast, the Nkporo Formation shows comparable kerogen composition (20 %–45 % <em>AOM</em>, 0–20 % liptinite, and 40 %–65 % vitrinite) but lower maturity (<em>TAI</em>: 2–2+; <em>R</em>_o: 0.45 %–0.80 %). Rock–Eval pyrolysis further supports these findings. The Mamu Formation displays higher Hydrogen Index, favorable <em>T</em>_max, and Production Index values, confirming its maturity and oil and gas–prone potential. Palynological assemblages, including marine dinoflagellate cysts (Mamu Formation) and freshwater algae/fungal spores (Nkporo Formation), align with the inferred depositional settings. Thus, the Mamu Formation is the more prolific source rock, characterized by superior organic quality and thermal maturity.</div></div>","PeriodicalId":100469,"journal":{"name":"Energy Geoscience","volume":"6 4","pages":"Article 100447"},"PeriodicalIF":3.6,"publicationDate":"2025-12-01","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"144827549","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":"Influence of mineral evolution on pore development in marine shales based on thermal simulation experiments","authors":"Jinghui Yang,&nbsp;Bao Jia,&nbsp;Xu Chen,&nbsp;Qiang Wang,&nbsp;Shixi Wang","doi":"10.1016/j.engeos.2025.100469","DOIUrl":"10.1016/j.engeos.2025.100469","url":null,"abstract":"<div><div>High-temperature thermal simulation experiments (500–1000 °C) were conducted with samples from the Lower Cambrian Niutitang Formation shale to investigate its mineral evolution and pore development. Integrated analyses, including total organic carbon (<em>TOC</em>) content determination, X-ray diffraction (XRD), Scanning Electron Microscopy (SEM), and pore structure characterization, reveal that clay minerals progressively decompose and transform into quartz during heating, with a new mineral phase mullite produced at a temperature above 800 °C. Concurrently, organic matter undergoes thermal evolution and shrinkage, creating distinctive shrinkage-induced fractures that enhance pore development. Clay mineral decomposition produces a more complex internal pore structure and fragmented reservoir matrix, generating pores at various scales. This process increases the number and size of micropores, mesopores, and macropores, creating intricate pore networks favorable for shale reservoir development. The study illuminates the intrinsic relationship between mineral transformation and pore development in highly mature marine shales exposed to elevated temperatures.</div></div>","PeriodicalId":100469,"journal":{"name":"Energy Geoscience","volume":"6 4","pages":"Article 100469"},"PeriodicalIF":3.6,"publicationDate":"2025-12-01","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"145157948","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":"2025-12-01","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":"Exploring interconnected indicators of energy transition: A global perspective","authors":"Abroon Qazi","doi":"10.1016/j.engeos.2025.100445","DOIUrl":"10.1016/j.engeos.2025.100445","url":null,"abstract":"<div><div>This study aims to evaluate the relative importance of the pillars and indicators within the Energy Transition Index (ETI) and their influence on overall ETI performance. Using a dataset from the World Economic Forum's 2024 ETI report, which covers 120 countries, this research applies Bayesian Belief Networks (BBNs), a probabilistic graphical modeling technique suited for analyzing complex interdependencies among variables. Two models are developed: one connecting the ETI to its eight pillars, and another linking it to 22 selected indicators. Findings reveal that the finance and investment pillar has the strongest positive association with ETI scores, whereas innovation is the area with the highest concentration of low-performing countries. Additionally, strong synergies are observed across digital infrastructure readiness and education quality, highlighting opportunities for multi-dimensional policy interventions. The study provides actionable insights for policymakers, such as prioritizing financial instruments, strengthening regulatory frameworks, and enhancing educational and digital infrastructure to accelerate progress in energy transitions.</div></div>","PeriodicalId":100469,"journal":{"name":"Energy Geoscience","volume":"6 4","pages":"Article 100445"},"PeriodicalIF":3.6,"publicationDate":"2025-12-01","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"144865114","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":"Retraction notice to “Paleoclimatic and paleoenvironmental constraints on organic matter enrichment in the Paleocene strata in the Lishui Sag, East China Sea Shelf Basin” [Energy Geoscience 6/1 (2025) 100356]","authors":"Shiyan Yin ,&nbsp;Chuang Lei ,&nbsp;Jiaren Ye ,&nbsp;Jingfu Wu ,&nbsp;Yu Wang ,&nbsp;Ying Zhang ,&nbsp;Xiaoying Han","doi":"10.1016/j.engeos.2025.100464","DOIUrl":"10.1016/j.engeos.2025.100464","url":null,"abstract":"","PeriodicalId":100469,"journal":{"name":"Energy Geoscience","volume":"6 4","pages":"Article 100464"},"PeriodicalIF":3.6,"publicationDate":"2025-12-01","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"145519416","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":"Evaluating poro-elastic production drive mechanisms: Quantifying the potential contribution to well-rates and risk of core handling damage inflating pore-volume compressibility measurements","authors":"Ruud Weijermars","doi":"10.1016/j.engeos.2025.100432","DOIUrl":"10.1016/j.engeos.2025.100432","url":null,"abstract":"<div><div>By analyzing core data from an offshore Gulf of Mexico reservoir and developing analytical solutions, it can be demonstrated that laboratory measurements on pore-volume compressibility include artifacts, leading to a misinterpretation of porosity and permeability trends. A systematic evaluation of poro-elastic changes in pore volumes (and quantifying any consequent fluid expulsion during reservoir compaction) suggests that poro-elastic relaxation may enhance fluid production rates from deep reservoirs by up to 25 %. This value may be inadvertently inflated if the core samples used for pore-volume compressibility measurements suffered from handling damage. Nonetheless, poro-elastic fluid expulsion from the pores in producing reservoirs can provide additional lift and thus may enhance the recovery factor. Therefore, the possible contribution to well performance from poro-elastic production drive mechanisms ought to be carefully evaluated in reserves estimation. Reversely, injection wells may encounter poro-elastic suppression of injectivity due to elastic resistance, which would adversely affect the storage coefficient. By integrating geomechanical reservoir response with traditional fluid production models, reservoir model predictions of production under pressure depletion and injection conditions will be more accurate. The new insights reported here are essential for optimizing well performance, improving reservoir management, and extending the economic life of geological reservoirs. However, caution is warranted regarding pore-volume compressibility measurements. To what degree laboratory measurements of pore-volume compressibility measure true values or mainly record handling damage could not be conclusively settled in the present study.</div></div>","PeriodicalId":100469,"journal":{"name":"Energy Geoscience","volume":"6 3","pages":"Article 100432"},"PeriodicalIF":0.0,"publicationDate":"2025-09-01","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"144548787","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":"Organic pore heterogeneity and its impact on absorption capacity in shale reservoirs in the Wufeng and Longmaxi formations, South China","authors":"Yuying Zhang ,&nbsp;Zhiliang He ,&nbsp;Shuangfang Lu ,&nbsp;Dianshi Xiao ,&nbsp;Yifei Li ,&nbsp;Yang Liu","doi":"10.1016/j.engeos.2025.100427","DOIUrl":"10.1016/j.engeos.2025.100427","url":null,"abstract":"<div><div>This study aims to determine the variation and controlling factors of shale gas adsorption capacity in reservoirs in the Upper Ordovician Wufeng Formation and the Lower Silurian Longmaxi Formation (also referred to as the WF-LMX formations), South China. Based on data obtained using scanning helium ion microscopy (HIM) and nitrogen (N₂) and methane (CH₄) adsorption experiments, this study analyzed the organic pore heterogeneity of shales in the WF-LMX formations in well A and its effect on shale gas adsorption. Using the Frenkel-Halsey-Hill (FHH) model, data from N₂ adsorption experiments were converted into fractal dimensions, which can reflect the complexity and heterogeneity of organic pores while also serving as a novel indicator for quantitatively assessing the pore structure complexity. The results indicate that shales in the WF-LMX formations in well A can be divided into two sections: (Ⅰ) the Wufeng Formation and the lower Longmaxi Formation (depths: ca. 2871.0–2898.6 m), and (Ⅱ) the upper Longmaxi Formation (depths: &lt; 2871.0 m). Organic pores in Section Ⅰ typically exhibit complex internal structures, coarse surfaces, and interconnectivity, whereas those in Section Ⅱ are simple, smooth, and isolated. Moreover, the former possesses larger specific surface areas (SSAs) than the latter. A fractal analysis reveals that organic pores in the shale sequence can be classified into micropores (&lt;2 nm), mesopores (2–10 nm), and macropores (&gt;10 nm). The calculated fractal dimensions show greater heterogeneity of organic pores, especially macropores, in Section Ⅰ compared to Section Ⅱ. The results also reveal that organic macropores are the primary pores controlling the SSAs of organic pores in shale reservoirs in the WF-LMX formations. Organic pores in Section Ⅰ manifest a superior shale gas adsorption capacity compared to Section Ⅱ. The heterogeneity of organic pores might affect the adsorption capacity of shales in the formations. Generally, organic macropores in Section Ⅰ of the shale sequence exhibit more complex structures and larger SSAs, leading to a stronger absorption capacity of shale reservoirs in Section Ⅰ compared to Section Ⅱ.</div></div>","PeriodicalId":100469,"journal":{"name":"Energy Geoscience","volume":"6 3","pages":"Article 100427"},"PeriodicalIF":0.0,"publicationDate":"2025-09-01","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"144480802","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}