Petroleum最新文献

{"title":"A graphene plugging material for high-temperature and high-salt water-based drilling fluids","authors":"Luo Pingya ,&nbsp;Dai Feng ,&nbsp;Bai Yi ,&nbsp;Bai Yang ,&nbsp;Wang Jianwei","doi":"10.1016/j.petlm.2026.03.006","DOIUrl":"10.1016/j.petlm.2026.03.006","url":null,"abstract":"<div><div>During the drilling process in deep oil reservoirs with high temperature and high salinity, the drilling fluid faces the risk of performance failure. Experiments have shown that the high-temperature and high-salinity environment weakens the negative charges on the surface of bentonite, causing the particles to aggregate, destroying the network structure and losing its rheological properties, as well as its ability to carry rock and filtrate. To solve this problem, this study improved the Hummers method to prepare rigid graphene oxide particles (GO-Y). In the experiment, 0.05 wt% graphene oxide was added to the drilling fluid containing 4% bentonite. Under the conditions of 10 wt% NaCl and 160 °C, graphene oxide adsorbed onto the surface of bentonite, increasing the particle spacing, and its spatial steric hindrance effect inhibited the aggregation of bentonite in the high-temperature and high-salinity environment, maintaining a smaller particle size distribution, and thus preserving the network structure of bentonite in the drilling fluid. The results showed that the rock-carrying capacity of the drilling fluid increased by 75.3%, and the filtrate volume decreased by 19.7%. Moreover, after adding 4% graphene-based leak stopper to the water-based drilling fluid, the permeability decreased to 1.89 × 10⁻² mD, and the leak stop rate reached 91.7%. The synthesized graphene-based leak stopper is suitable for high-temperature and high-salinity environments and can provide technical support for the drilling development of deep oil reservoirs.</div></div>","PeriodicalId":37433,"journal":{"name":"Petroleum","volume":"12 2","pages":"Pages 263-271"},"PeriodicalIF":3.5,"publicationDate":"2026-04-01","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"148170288","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":"Relative permeability model for shale reservoirs considering water distribution and imbibition with two fractal regions","authors":"Yingzhong Yuan ,&nbsp;Liangliang Jiang ,&nbsp;Aliakbar Hassanpouryouzband ,&nbsp;Nanlin Zhang ,&nbsp;Saeid Ataei Fath Abad ,&nbsp;Zhilin Qi ,&nbsp;Hongbin Liang ,&nbsp;Wende Yan","doi":"10.1016/j.petlm.2026.01.004","DOIUrl":"10.1016/j.petlm.2026.01.004","url":null,"abstract":"<div><div>Shale gas is a key transitional low-carbon energy source, offering a cleaner-burning alternative to coal, reducing greenhouse gas emissions, and supporting energy security during the transition to renewable energy systems. However, its efficient production is challenged by issues such as fracturing fluid retention, which adversely affects gas flow. During well shut-in and flowback following hydraulic fracturing, fracturing fluid imbibes into the formation, redistributing within its complex pore structure and altering gas-water flow dynamics. This study develops a comprehensive gas-water relative permeability model for shale reservoirs, using fractal theory and porous media mechanics. The model incorporates key factors, including pore size distribution, fractal geometry, tortuosity, pore connectivity, and fluid-phase interactions within distinct fractal regions of the shale. The analysis shows that increases in fractal tortuosity, critical water saturation, fractal dimension in the large-pore fractal region, displacement probability in the small-pore fractal region, and imbibition time reduce water relative permeability. In contrast, increasing displacement probabilities in both fractal regions, pore coordination number, and imbibition time enhance gas relative permeability. These findings highlight the importance of mitigating aqueous phase trapping and optimizing fracturing fluid flowback to minimize formation damage and improve production rates. By advancing our understanding of fluid behavior under complex reservoir conditions, this study provides a theoretical framework for designing operational strategies that enhance shale gas recovery, supporting its role in meeting energy demands while reducing greenhouse gas emissions.</div></div>","PeriodicalId":37433,"journal":{"name":"Petroleum","volume":"12 2","pages":"Pages 279-293"},"PeriodicalIF":3.5,"publicationDate":"2026-04-01","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"148170240","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":"Assessing the efficiency of long-term CO2 geological storage using an advanced multiphase compositional simulator","authors":"Abdul Salam Abd,&nbsp;Ahmad Abushaikha","doi":"10.1016/j.petlm.2026.02.002","DOIUrl":"10.1016/j.petlm.2026.02.002","url":null,"abstract":"<div><div>CO₂ sequestration has a critical role in mitigating climate change impacts, thus we rely on numerical simulations to capture the processes of CO₂ injection, migration, and long-term storage. This paper presents a comprehensive benchmarking study of an in-house built multiphase compositional simulator for CO₂ storage modelling applications, emphasizing the accurate modeling of trapping mechanisms within geological formations. We perform rigorous tests to benchmark the simulator's performance against established analytical solutions, focusing on the evolution of CO₂ plumes, leakage rates through abandoned wells, and interactions of CO₂ with the formation water. Our results demonstrate the simulator's robustness in handling complex subsurface phenomena, including variable property simulations and the effects of hysteresis on plume behavior. These comparisons offer insights into the effects of parameter choices and boundary conditions on the simulation outcomes. Our work not only validates the simulator against known analytical solutions and numerical benchmarks, but also lays a foundation for future enhancements in our code, particularly in the area of geochemical interactions and the assessment of CO₂ leakage on the security of the storage media.</div></div>","PeriodicalId":37433,"journal":{"name":"Petroleum","volume":"12 2","pages":"Pages 230-253"},"PeriodicalIF":3.5,"publicationDate":"2026-04-01","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"148170286","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":"Enhancing CO2 huff-n -puff strategies for improved oil recovery in the Bakken formation: A numerical simulation approach","authors":"Saddam Mohammed Mohammed Nasser,&nbsp;Vivek Ramalingam,&nbsp;N. Madhavan","doi":"10.1016/j.petlm.2026.02.004","DOIUrl":"10.1016/j.petlm.2026.02.004","url":null,"abstract":"<div><div>This study investigates the performance of various huff and puff (HnP) strategies for enhanced oil recovery (EOR) in the Sanish field of the Bakken formation, using a numerical model developed with CMG software. The model integrates PVT validation, CO₂ miscibility, swelling tests, heterogeneity, and history matching with field data. Several HnP strategies, including Supported (S HnP), Alternative Supported (AS HnP), and Alternative Zigzag Supported (AZS HnP), were evaluated. Key findings show that dual porosity and permeability are essential for accurate modeling, while CO₂ diffusion has minimal impact in field-scale simulations with high fracture spacing. The S HnP strategy improves oil recovery with 50% less CO₂ than the Normal HnP, and the AS HnP further enhances production. The AZS HnP outperforms both, offering higher oil recovery and better CO₂ utilization. Fracture length was found to influence recovery significantly, and the sensitivity of oil production to CO₂ injection rates was notably higher in the AZS HnP compared to the N HnP scenario. These results highlight the potential for optimized CO₂-EOR strategies in unconventional reservoirs.</div></div>","PeriodicalId":37433,"journal":{"name":"Petroleum","volume":"12 2","pages":"Pages 313-322"},"PeriodicalIF":3.5,"publicationDate":"2026-04-01","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"148170284","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":"Development and evaluation of graphene nanosheets as a novel micro-nano plugging agent for oil-based muds","authors":"Fan Yu ,&nbsp;Huang Weian ,&nbsp;Guo Jianhua ,&nbsp;Tang Yijia","doi":"10.1016/j.petlm.2026.03.005","DOIUrl":"10.1016/j.petlm.2026.03.005","url":null,"abstract":"<div><div>Although there are abundant shale gas resources in China, shale gas is generally buried much deeper than foreign countries. For large-scale development, there are still many core technologies that have not yet been solved. In this paper, we have analyzed microstructure of formation rock and its mineral composition, and the mechanism of wellbore instability is revealed by studying the petrophysical properties and characteristics of the wellbore instability strata in the Changning-Weiyuan area. The laboratory innovatively constructs the “solid phase intercalation-liquid phase expansion stripping method” and obtains high-quality graphene nanosheets. The results of the performance test and the HTHP filtration test on the graphene nanosheets show that it achieves the lowest HTHP filtration loss (8.0 mL) among tested additives, outperforming super-fine CaCO₃(8.6 mL) and conventional agents (9.2 mL), while minimally affecting rheology. Other performance tests indicate that high-quality graphene nanosheets made by our laboratory can be well dispersed in solvent with almost no obvious aggregation and it has the median particle size ranges from 212 nm to 228 nm, which means it has perfect ability to plug micro-crack in the Changning-Weiyuan area. The oilfield application shows that adding 0.75% graphene nanosheets to the field mud significantly enhanced wellbore stability, achieving zero mud loss and a 94.6% drilling rate in the target zone, while reducing HTHP filtration to below 2.4 mL.</div></div>","PeriodicalId":37433,"journal":{"name":"Petroleum","volume":"12 2","pages":"Pages 272-278"},"PeriodicalIF":3.5,"publicationDate":"2026-04-01","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"148170289","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":"Petroleum system modeling in the central part of the Fars platform (Zagros Basin)","authors":"Ali Soleimani ,&nbsp;Mohammad Hassan Jazayeri ,&nbsp;Mehdi Kobraei ,&nbsp;Mehrab Rashidi ,&nbsp;Xiyuan Liu ,&nbsp;Mehdi Ostadhassan","doi":"10.1016/j.petlm.2026.03.007","DOIUrl":"10.1016/j.petlm.2026.03.007","url":null,"abstract":"<div><div>The Fars Platform is a geological region with significant untapped potential for petroleum resources. Its unique structural and stratigraphic features, combined with favorable reservoir conditions, make it a key area for hydrocarbon exploration and production. To better delineate the Paleozoic petroleum system and mitigate future charge-related risks in the region, one- and two-dimensional petroleum system modeling was carried out. The primary objective of this study is to analyze the burial, thermal, maturation, and generation histories of the source rock(s), as well as the migration pathways, hydrocarbon charging history, and accumulation within reservoirs in the central part of the Fars Platform based on a comprehensive integration of geological, geophysical, and geochemical data. Geochemical investigation on potential source rocks showed that the Silurian hot shale of the Sarchahan Formation is the only effective source rock charging the Permian reservoir rocks. By conducting 1-D models in 6 wells, the maturation and hydrocarbon generation histories and also the heat flow for each well were obtained after calibrating the models with the measured temperature and vitrinite reflectance data. The resulting heat flows were consequently used in 2-D petroleum system modeling based on the interpretation of seismic data. The simulation results show that the occurrence of overpressure in the Dashtak Formation has caused the pressure to be different in the upper and lower layers, making this formation a suitable cap rock in the area. The hydrocarbons generated from the Sarchahan source rock started to expel in the eastern parts of the study area since the late Cretaceous, and expulsion occurred almost along the entire area during the Eocene. Before the Zagros orogeny happened in the Neogene, the hydrocarbon migration was mostly vertical while, after the orogeny, the lateral migration also occurred, mainly towards the regional high, and charged most of the traps. The large amounts of hydrocarbon, mostly in gaseous form, was expelled after the formation of structural traps. The results from this study can become the guideline for future exploration endeavors in the region to reduce risks and operational costs.</div></div>","PeriodicalId":37433,"journal":{"name":"Petroleum","volume":"12 2","pages":"Pages 197-215"},"PeriodicalIF":3.5,"publicationDate":"2026-04-01","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"148170243","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 probabilistic comprehensive evaluation method for the fracability of unconventional hydrocarbons reservoir considering description uncertainty of target formation","authors":"Hongzhi Xu ,&nbsp;Hao Zhang ,&nbsp;Zizhen Wang ,&nbsp;Weidong Zhou ,&nbsp;Jintang Wang ,&nbsp;Wang Zhou ,&nbsp;Chengwen Wang","doi":"10.1016/j.petlm.2026.03.008","DOIUrl":"10.1016/j.petlm.2026.03.008","url":null,"abstract":"<div><div>Fracability evaluation is a crucial basis for fracturing and production enhancement in tight reservoirs. Due to the complexity of the geological environment, factors influencing reservoir fracability exhibit significant uncertainty. Ignoring the uncertainty of relevant parameters and conducting fracability evaluation based on deterministic parameters may lead to deviations from actual fracability results. To address this issue, this paper proposes a comprehensive evaluation method for the fracability of unconventional oil and gas reservoirs, considering reservoir description uncertainty. Based on fundamental evaluation methods, a reservoir fracability evaluation model is constructed, incorporating the Monte Carlo stochastic simulation method to determine the comprehensive probability distribution of the reservoir fracability evaluation index. This approach enables a more scientific and reliable evaluation of reservoir fracability. The research results indicate that the assumed distribution of input parameters has a certain impact on fracability evaluation results, with normal distribution demonstrating significant disturbance resistance. Additionally, brittleness index is found to be the most sensitive factor affecting fracability evaluation. The proposed evaluation method and insights can provide theoretical references for the fracability assessment of highly heterogeneous tight reservoirs.</div></div>","PeriodicalId":37433,"journal":{"name":"Petroleum","volume":"12 2","pages":"Pages 294-312"},"PeriodicalIF":3.5,"publicationDate":"2026-04-01","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"148170283","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":"Analysis of the effect of steam injection conditions on the integrity of casing-cement sheath-formation assemblies in heavy oil thermal recovery","authors":"Fuquan Ding ,&nbsp;Huajie Liu ,&nbsp;Zhongguang Liu ,&nbsp;Yuhuan Bu ,&nbsp;Hongxu Zhang ,&nbsp;Hui Yin","doi":"10.1016/j.petlm.2026.04.002","DOIUrl":"10.1016/j.petlm.2026.04.002","url":null,"abstract":"<div><div>Accurately forecasting the sealing failure behavior of the casing-cement sheath-formation assembly under various steam injection operational parameters and cyclic steam stimulation conditions remains challenging. Such unpredictability heightens the risk of seal integrity compromise in the wellbores of thermal heavy oil production. This paper develops a numerical simulation and analytical approach based on heat-fluid-solid interactions within the casing-cement sheath-formation system. It assesses the impact of potential cement sheath and interfacial failures in response to differing steam injection pressures, temperatures, injection rates, and cyclic steam volumes. This assessment leverages the established relationships between the temperature-dependent elastic modulus and Poisson’s ratio of cementitious materials, as well as the dynamics of wellbore pressure, temperature, and steam quality during steam injection. Experimental findings suggest that maintaining steam injection temperatures between 340 °C and 380 °C can effectively mitigate the risk of shear-induced damage and enhance the safety of the cementing interface. The injection rate appears to have a minimal impact on interface integrity. The extent of plastic strain in the cement sheath is proportionate to the size of the micro-annular gap at the interface. When the initial formation has an elastic modulus of 15 GPa, variations in the cement sheath’s elastic modulus do not influence the micro-annular gap size. However, in formations with an initial elastic modulus of 5 GPa, a lower elastic modulus of the cement sheath corresponds to a smaller micro-annular gap. The study concludes that a higher initial geostress and temperature, coupled with a high elastic modulus of the surrounding strata, are conducive to maintaining the integrity of the cement sheath interface.</div></div>","PeriodicalId":37433,"journal":{"name":"Petroleum","volume":"12 2","pages":"Pages 323-338"},"PeriodicalIF":3.5,"publicationDate":"2026-04-01","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"148170285","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":"Molecular insight into the competitive adsorption mechanism of supercritical CO2/Crude oil in shale composite model","authors":"Yuanxiu Sun ,&nbsp;Yijie Ma ,&nbsp;Hongrui Guo ,&nbsp;Jiang Wu ,&nbsp;Liping Zhang ,&nbsp;Songqi Li","doi":"10.1016/j.petlm.2025.12.005","DOIUrl":"10.1016/j.petlm.2025.12.005","url":null,"abstract":"<div><div>With the continuous growth of global energy demand, shale oil, as an important unconventional oil and gas resource, is increasingly highlighting its strategic position. As one of the key means of shale oil development, supercritical carbon dioxide (CO₂) flooding technology has significant advantages in reducing crude oil viscosity, improving reservoir pore structure and fluid occurrence state, thereby effectively enhancing oil recovery. The molecular simulation method provides an effective way to reveal the microscopic mechanism of CO₂ flooding. In this paper, based on the molecular dynamics simulation method, a multi-component system model including supercritical CO₂, organic-inorganic composite wall and crude oil is constructed. The microscopic mechanism of competitive adsorption between supercritical CO₂ and components in both single-component and multi-component oil phase is systematically investigated. The effects of wall type, temperature and CO₂ injection pressure on competitive adsorption behavior are clarified. The results show that the competitive adsorption of supercritical CO₂ varies significantly among different shale oil compoents. The competitive adsorption efficiencies of supercritical CO₂ for the single-component systems, <em>n</em>-hexane, toluene, acetic acid, and <em>n</em>-dodecane, are 55.17%, 51.72%, 44.83%, and 27.59%, respectively. In the multi-component oil system, the competitive adsorption efficiencies of supercritical CO₂ are as follows: <em>n</em>-hexane (66.58%), <em>n</em>-dodecane (47.06%), toluene (49.46%), and acetic acid (78.78%). This indicates that the competitive adsorption efficiency is closely related to the molecular polarity, molecular weight and the component's position in the adsorption layer. In addition, the competitive adsorption efficiency of CO₂ for <em>n</em>-hexane first increases and then decreases with increasing temperature, reaching a maximum of 50.57% at 383.15K and the injection pressure of 10.5 MPa. The increase of injection pressure significantly improves the competitive adsorption efficiency, and 10.5 MPa is considered as the minimum miscibility pressure (MMP). This study reveals the competitive adsorption mechanism between supercritical CO₂ and shale oil at the molecular scale, thus providing theoretical support for the technical optimization and scheme design of shale oil of efficienyt development through CO₂ injection.</div></div>","PeriodicalId":37433,"journal":{"name":"Petroleum","volume":"12 1","pages":"Pages 105-127"},"PeriodicalIF":3.5,"publicationDate":"2026-02-01","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"147420541","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 quantitative risk assessment model for lightning-induced failures in natural gas automated metering systems","authors":"Xia Wu ,&nbsp;Jiujiang Cai ,&nbsp;Hanqing Liu ,&nbsp;Wenlong Jia ,&nbsp;Changjun Li ,&nbsp;Mengjun Teng","doi":"10.1016/j.petlm.2025.11.002","DOIUrl":"10.1016/j.petlm.2025.11.002","url":null,"abstract":"<div><div>As one of the most probable natural hazards leading to technological disasters, lightning can easily damage analytical instruments in oil and gas stations, resulting in data loss and operational anomalies. Compared with other equipment, Natural Gas Automated Metering Systems (NGAMS), which comprise various precision analytical instruments, are more susceptible to lightning strikes. This vulnerability often leads to production shutdowns, inaccurate metering, and commercial disputes. A quantitative risk assessment model for lightning-induced failures in NGAMS is proposed to enhance the integrity management of metering stations. The model consists of a lightning failure probability model and a consequence evaluation method that incorporates reputational loss. First, a lightning identification criterion is established based on the electro-geometric model, and a basic lightning probability model is developed using Monte Carlo simulations. Second, a basic failure probability model is constructed by modeling the system's equivalent circuit and incorporating the insulation withstand characteristics of the equipment. Two correction factors, specifically the location factor and lightning protection measures, are subsequently incorporated to establish the comprehensive lightning failure probability model. Furthermore, a reputational loss evaluation method is proposed by developing a reputation loss indicator system and integrating the Z-BWM method with cloud model. Case study results show that when the average lightning probability is 1.03 × 10⁻², the maximum system failure probability reaches 4.14 × 10⁻⁵, representing a 35.29% increase over the inherent failure probability. The corresponding reputational loss is classified as low risk, verifying the effectiveness and practicality of the proposed model.</div></div>","PeriodicalId":37433,"journal":{"name":"Petroleum","volume":"12 1","pages":"Pages 167-181"},"PeriodicalIF":3.5,"publicationDate":"2026-02-01","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"147420539","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}