Petroleum最新文献

{"title":"Numerical simulation of seismicity potential resulting from the injection of CO2 into depleted reservoir in Wilbarger County field, Texas","authors":"Dorcas S. Eyinla,&nbsp;Hossein Emadi,&nbsp;Steven K. Henderson,&nbsp;Humza Bin Navaid,&nbsp;Abir Kebir,&nbsp;Aman Arora","doi":"10.1016/j.petlm.2025.04.002","DOIUrl":"10.1016/j.petlm.2025.04.002","url":null,"abstract":"<div><div>Fluid injection in fractured rocks presents significant challenges requiring the integration of various elements to account for reservoir property heterogeneities. To understand magnitude of potential seismic risks resulting from CO₂ injection in naturally fractured sand reservoirs in the study location, we devised a simulation model which utilizes a coupled thermo-hydro-mechanical (THM) approach, encompassing different injection scenarios and reservoir injection systems. The model effectively captures the complex interplay between geological features and fault failure processes. Furthermore, we examined the mechanical response of the caprock under constant injection rates by analyzing the evolution of shear stress and its impact on permeability enhancement. Our findings reveal that the pressurization effect of fluid and stress alterations trigger significant fault rupture, leading to seismic events of varying magnitudes. The extent of seismic activity hinges on the reservoir's initial state, the properties of the overlying caprock, and the injected volume. Moreover, we discovered that deformations within the caprock layer are most pronounced near fault zones, gradually diminishing with distance from these zones. Notably, the degree of permeability modification in the caprock is linked to the magnitude of shear stress. Additionally, our research corroborated that higher injection rates markedly accelerate fault slip, albeit with minimal impact on the extent of permeability enhancement. However, we noted a non-linear relationship between seismic activity and fluid injection rates, suggesting that the magnitude of seismic consequences is contingent upon the temporal analysis of various parameters. These significant findings offer valuable insights into understanding the intricate processes associated with subsurface injection, which often manifest in phenomena such as fault ruptures and induced seismicity.</div></div>","PeriodicalId":37433,"journal":{"name":"Petroleum","volume":"11 3","pages":"Pages 353-365"},"PeriodicalIF":4.2,"publicationDate":"2025-06-01","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"144501491","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":"Advancements in green materials for chemical enhanced oil recovery: A review","authors":"Jamil F. El-Masry ,&nbsp;Elsa Maalouf ,&nbsp;Azza H. Abbas ,&nbsp;Kamel F. Bou-Hamdan","doi":"10.1016/j.petlm.2025.03.007","DOIUrl":"10.1016/j.petlm.2025.03.007","url":null,"abstract":"<div><div>Chemical enhanced oil recovery (CEOR) is well known for its success in recovering the trapped oil in reservoirs after waterflooding operations. In CEOR, synthetic chemicals are utilized to increase the capillary number or modify the mobility ratio of reservoirs; however, they are expensive and are associated with environmental concerns. Hence, the rise in environmental awareness paved the way for environmentally friendly and cheaper alternatives, such as green products, to replace synthetic chemicals. This paper comprehensively reviews recent studies on applying green products in CEOR. It also includes comparisons between the performance of several green products and their synthetic counterparts in CEOR. Moreover, limitations, cost, and environmental footprints are analyzed. Finally, the displacement efficiency of green chemicals and pertinent challenges in the field are highlighted. While the utilization of some natural materials in EOR still has an environmental impact, they constitute a safer option than synthetic chemicals. Furthermore, green materials are more affordable than synthetic chemicals that are commonly utilized, making them a financially viable option for EOR. An up-to-date overview is urgently needed due to the growth of natural chemical utilization in oil and gas applications. Promoting sustainable alternatives is essential to addressing the rise in global environmental concerns.</div></div>","PeriodicalId":37433,"journal":{"name":"Petroleum","volume":"11 3","pages":"Pages 259-276"},"PeriodicalIF":4.2,"publicationDate":"2025-06-01","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"144501582","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":"Experimental evaluation method of density suitability between bridging lost circulation materials and drilling fluid","authors":"Yili Kang,&nbsp;Ketao Hao,&nbsp;Chengyuan Xu,&nbsp;Kun Guo,&nbsp;Jie Zhou,&nbsp;Ruiheng Wang,&nbsp;Yao Xiao,&nbsp;Yunsong Xie","doi":"10.1016/j.petlm.2025.04.001","DOIUrl":"10.1016/j.petlm.2025.04.001","url":null,"abstract":"<div><div>Ultra-deep geological conditions are complex, often leading to leakage issues. As the depth increases during ultra-deep bridging lost-circulation operations, the varying settling velocities of different types of lost circulation materials (LCMs) lead to gravitational differentiation. This causes stratification of the LCMs, forming an unevenly dispersed system and reduced plugging efficacy. An experimental methodology is described for assessing the density suitability between LCMs and drilling fluids, which calculates the density suitability factor (DSF) by measuring the density of the plugging slurry at various locations after a designated resting period, ultimately evaluating its density suitability based on the DSF. Experimental results indicate that LCMs with lower densities demonstrate superior density suitability compared to those with higher densities. Smaller particle sizes (10–40 mesh) show better density suitability than larger ones (2–6 mesh). Fracture-plugging experiments validated this method, the plugging slurry composed of a good density suitability material, such as walnut shells, exhibited no notable gravitational differentiation after 2 h, achieving a maximum plugging pressure of 16.4 MPa with 88 mL of total volume loss. In contrast, the slurry formed with poorly density suitability materials, such as calcite, showed significant gravitational differentiation after 2 h, achieving only 9.6 MPa in maximum plugging pressure and a total volume loss of 96 mL. These findings highlight that LCMs with superior density suitability enhance plugging efficiency, highlighting the critical role of density suitability testing and the optimization of plugging formulations to improve the success of plugging operations.</div></div>","PeriodicalId":37433,"journal":{"name":"Petroleum","volume":"11 3","pages":"Pages 334-341"},"PeriodicalIF":4.2,"publicationDate":"2025-06-01","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"144501489","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":"Impact of hydroxypropyl guar polymer on rheology and filtration properties of water-based drilling fluids","authors":"Husam Al-Ziyadi ,&nbsp;Narendra Kumar ,&nbsp;Amit Verma","doi":"10.1016/j.petlm.2025.03.006","DOIUrl":"10.1016/j.petlm.2025.03.006","url":null,"abstract":"<div><div>Water-based drilling muds (WBM) are a very crucial component of the oil and gas industry; however, they often face challenges with inadequate rheological performance and excessive fluid loss. This paper introduces hydroxypropyl guar polymer (HPG) and fly ash (FA) as new additives to regulate the rheological properties and filtration loss of WBM. The primary objectives of this study are to reduce filtration loss, enhance rheological characteristics, reduce clay swelling, improve cutting dispersion, and control barite sag. The experimental procedure involves formulating optimized mud samples by incorporating HPG and FA up to 120 °C. The synergistic effect of HPG and FA enhances rheological properties and achieves a 56.52% reduction in filtration loss compared to WBM without additives. Additionally, HPG/FA incorporation resulted in controlling the clay swelling. The swelling dropped from 91.5% to 36.7% compared to the base mud. Shale cuttings recovery in the base fluid was 52.4% after hot rolling at 90 °C, 60 °C, and 40 °C for 16 h and treatment with 0.18% HPG inhibitors improved recovery to 82.1%, 54.1%, and 57.2%, respectively. The sag factor remained controlled compared to the base mud, staying within the acceptable range of 0.503–0.521 at both vertical and 45° inclined angles. The WBM with the addition of HPG and FA is more efficient and has enhanced the well integrity and reduced operational costs in the oil and gas industry.</div></div>","PeriodicalId":37433,"journal":{"name":"Petroleum","volume":"11 3","pages":"Pages 320-333"},"PeriodicalIF":4.2,"publicationDate":"2025-06-01","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"144501487","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":"Criterion to foresee the affinity of various coatings/substrates to asphaltene deposition in oil wells","authors":"Sakineh Hadizadeh ,&nbsp;M. Reza Malayeri","doi":"10.1016/j.petlm.2025.03.005","DOIUrl":"10.1016/j.petlm.2025.03.005","url":null,"abstract":"<div><div>Asphaltene deposition in oil wells has long been considered a severe problem. It can be treated using various chemical, mechanical, and thermal methods. However, these methods are often associated with significant hazards, operational limitations, and costs. In light of these challenges, recent research has shifted towards preventive measures, particularly using surface coatings/substrates to inhibit asphaltene deposition. The present study introduces a novel criterion based on surface energy for assessing the effectiveness of such coatings/substrates. The criterion is derived using the XDLVO theory, which considers the adhesive interaction energy in an asphaltene/crude oil/surface system and its relation to the spreading coefficient. The approach provides a theoretical framework for understanding the interactions between asphaltenes, crude oil, surface coatings/substrates, and how these interactions influence asphaltene deposition. Subsequently, utilizing characterization data from ten surface coating/substrate samples, and corresponding crude oil and asphaltene samples from Z, K, and R fields, the accuracy of this criterion is evaluated. The results showed that, based on the proposed new criterion, among the selected coatings, L-80 and N-80 were asphaltene-repellent for oil Z-55 while SS316 and SS304 were repellent for oil K-42. For oil R-95, only the L-80 substrate exhibited affinity to asphaltene deposition, whereas other coatings were repellent. These results align well with field data, where 16% of wells in field Z, 43% in field R, and 100% in field K face asphaltene deposition.</div></div>","PeriodicalId":37433,"journal":{"name":"Petroleum","volume":"11 3","pages":"Pages 377-389"},"PeriodicalIF":4.2,"publicationDate":"2025-06-01","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"144501493","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 systematic investigation of drilling fluid bulk relaxation impact on NMR interpretation for formation evaluation","authors":"Fauzan Akomolafe,&nbsp;Ammar El-Husseiny,&nbsp;Abdulrauf Adebayo,&nbsp;Mohamed Mahmoud,&nbsp;Badr Bageri","doi":"10.1016/j.petlm.2025.05.001","DOIUrl":"10.1016/j.petlm.2025.05.001","url":null,"abstract":"<div><div>During drilling, mud filtrate invasion alters near-wellbore properties which possibly impacts well logging measurements causing inaccuracies in formation evaluation. Given the shallow detection depth of nuclear magnetic resonance (NMR) logging, the transverse relaxation time (<span><math><mrow><msub><mi>T</mi><mn>2</mn></msub></mrow></math></span>) spectrum is highly susceptible to invasion effects. However, the impact of drilling fluid bulk relaxation on NMR <span><math><mrow><msub><mi>T</mi><mn>2</mn></msub></mrow></math></span> and formation damage remains underexplored. This study aims to investigate how drilling fluid bulk relaxation influences NMR <span><math><mrow><msub><mi>T</mi><mn>2</mn></msub></mrow></math></span> relaxometry responses in the near-wellbore region. Two factors controlling the drilling fluid bulk relaxation were considered and systematically varied: (1) XC polymer concentrations and (2) perlite concentrations in the drilling fluid. We conducted NMR measurements before and after filtration experiments on both permeable and tight limestone samples to assess the influence of host rock properties on the results. The study shows that drilling fluid bulk relaxation significantly impacts <span><math><mrow><msub><mi>T</mi><mn>2</mn></msub></mrow></math></span> values. Additives like XC polymer or barite lower <span><math><mrow><msub><mi>T</mi><mn>2</mn></msub></mrow></math></span> bulk values, reducing the <span><math><mrow><msub><mi>T</mi><mn>2</mn></msub></mrow></math></span> logarithmic mean by up to 90% especially in invaded macropores. The more notable impact in macropores is because they are more influenced by bulk relaxation mechanism compared to micropores. Rocks with larger pores experience greater reduction in <span><math><mrow><msub><mi>T</mi><mn>2</mn></msub></mrow></math></span>, while tight rocks, dominated by surface relaxation, show mineral changes. The findings underscore the importance of accounting for drilling fluid bulk relaxation in NMR interpretation to avoid overestimating formation damage and permeability reduction.</div></div>","PeriodicalId":37433,"journal":{"name":"Petroleum","volume":"11 3","pages":"Pages 308-319"},"PeriodicalIF":4.2,"publicationDate":"2025-06-01","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"144501488","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":"Architecture and differential hydrocarbon enrichment of basins under joint constraints of basement nature and regional stresses: A case study of the passive continental margin basins along the East Coast of Canada","authors":"Zhenrui Bai,&nbsp;Naxin Tian,&nbsp;Gaokui Wu,&nbsp;Yanyang Wang,&nbsp;Kun Tian","doi":"10.1016/j.petlm.2025.04.003","DOIUrl":"10.1016/j.petlm.2025.04.003","url":null,"abstract":"<div><div>The East Coast of Canada presents multiple passive continental margin basins (PCMBs) characterized by significant architectural differences and limited oil and gas discoveries, establishing these basins as the global frontier for hydrocarbon exploration. Limited understanding of the characteristics of basin architectures and their control of hydrocarbon accumulation hinders exploration breakthroughs in these basins. Using magnetic anomaly, seismic, and drilling data, this study conducts integrated geological and geophysical interpretations of the PCMBs. Accordingly, this study reveals that the PCMBs have undergone three evolutionary stages, namely rifting (comprising three episodes), depression, and continental margin, with the synthem of each stage being referred to as rift layer, depression layer, and continental margin layer, respectively. Under the control of transform faults and basement nature, four distinct types of PCMBs have formed: transtensional, transform, gentle-rampy, and volcanic rifted types from south to north. The basins with varying architectures govern the sedimentary filling, the combination of petroleum system elements, and differential hydrocarbon accumulation across three major types of synthems. Furthermore, this study highlights substantial hydrocarbon exploration potentials in the turbidite sandstones within the slope and basin-floor areas of the transtensional and transform types of PCMBs, as well as in the deltaic sandstones within the rift and depression layers of the gentle-rampy type of PCMBs.</div></div>","PeriodicalId":37433,"journal":{"name":"Petroleum","volume":"11 3","pages":"Pages 277-289"},"PeriodicalIF":4.2,"publicationDate":"2025-06-01","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"144501531","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":"Characteristics and genesis analysis of middle and lower Ordovician dolomite in the southern margin of the Ordos Basin, China","authors":"Xinyi Tang ,&nbsp;Zijing Li ,&nbsp;Hong Fang ,&nbsp;Yang Li ,&nbsp;Zongyang Dai ,&nbsp;Tian Li ,&nbsp;Peng Lai","doi":"10.1016/j.petlm.2025.05.003","DOIUrl":"10.1016/j.petlm.2025.05.003","url":null,"abstract":"<div><div>The Middle-Lower Ordovician formations in the southern margin of the Ordos Basin host multiple sets of dolomites, which readily form high-quality reservoirs with promising exploration prospects. Understanding the geochemical characteristics and analyzing the genesis of these dolomites in this region is crucial. Based on drilling, logging, core observation, and thin section identification, representative dolomite samples from the Xiweikou, Jueshangou, and Caojiagou profiles were selected for comprehensive geochemical analysis. Combined with the petrological characteristics and cathodoluminescence features of the dolomites, their characteristics and genesis were analyzed. The results indicate that the average ⁸⁷Sr/⁸⁶Sr ratio of 11 dolomite samples in this area is 0.710842. The rare earth element distribution pattern shows an enrichment of light rare earth elements (LREE) and a depletion of heavy rare earth elements (HREE). The micritic and finely crystalline dolomite crystals are euhedral to subhedral, with low ordering, high Na, K, Sr, and low Fe, Mn content. Under cathodoluminescence, they emit rose-red to dark-red light, indicating a product of penecontemporaneous dolomitization. The sandy crystalline dolomites (fine, medium, and coarse crystalline) generally have anhedral to subhedral crystal forms, high ordering, low Na, K, Sr, and high Fe, Mn content. Under cathodoluminescence, they emit dark-red or no light, indicating a product of burial diagenesis.</div></div>","PeriodicalId":37433,"journal":{"name":"Petroleum","volume":"11 3","pages":"Pages 290-307"},"PeriodicalIF":4.2,"publicationDate":"2025-06-01","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"144501486","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":"Design and analysis of low-density, high-pressure-resistant epoxy resins for advanced leakage control: Insights from experiments and simulations","authors":"Gang Xie ,&nbsp;Keming Fu ,&nbsp;Yujuan Jing ,&nbsp;Bo Peng ,&nbsp;Yujie Luo ,&nbsp;Li Fu ,&nbsp;Lan Ma ,&nbsp;Danchao Huang ,&nbsp;Jinjun Huang","doi":"10.1016/j.petlm.2025.05.004","DOIUrl":"10.1016/j.petlm.2025.05.004","url":null,"abstract":"<div><div>Leakage control in deep oil and gas wells is challenging, often leading to increased costs. In this study, a low-density, high-pressure resistant and thermally stable epoxy resin (BEPD) was synthesized by ring opening of 2,2-bis(4-epoxypropoxyphenyl) propane cured with 1,8-diaminonaphthalene. The material was thoroughly characterized using fourier-transform infrared spectroscopy, a universal testing machine, thermogravimetric analysis, and density testing. Comprehensive experimental and simulation analyses were conducted to evaluate BEPD's dispersion stability, its impact on the rheological properties of drilling fluid, and its effectiveness as a leakage control agent. It exhibits a high compressive strength (250.12 MPa) and a thermal decomposition temperature of 337.75 °C, making it suitable for high-temperature environments. Its irregular particle shape ensures a strong bond with surrounding strata, forming a stable plugging layer. With a density of 1.09 g/cm³, BEPD disperses well in plugging slurry, reducing sedimentation. At dosages between 1% and 4%, it doesn't significantly affect the rheology of the slurry and effectively prevents sedimentation. BEPD particles effectively plugged fractures ranging from 1 to 4 mm, withstanding pressures up to 11.5 MPa. This performance is due to its unique particle size distribution, where larger particles act as bridges and smaller particles fill gaps, forming a dense plugging layer. BEPD shows potential as a highly effective material for improving leakage control in deep well applications.</div></div>","PeriodicalId":37433,"journal":{"name":"Petroleum","volume":"11 3","pages":"Pages 342-352"},"PeriodicalIF":4.2,"publicationDate":"2025-06-01","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"144501490","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":"An experimental study to investigate the role of pyrolysis reaction on in-situ hydrogen generation from sandstone oil reservoirs","authors":"Mohamed Abdalsalam Hanfi ,&nbsp;Olalekan Saheed Alade ,&nbsp;Abdulkadir Tanimu ,&nbsp;Mohamed Mahmoud ,&nbsp;Sulaiman A. Alarifi","doi":"10.1016/j.petlm.2025.05.002","DOIUrl":"10.1016/j.petlm.2025.05.002","url":null,"abstract":"<div><div>In-situ combustion gasification (ISCG) is a technology in the field pilot stage used for hydrogen generation from oil reservoirs. ISCG is implemented by injecting an oxidant (pure oxygen, air, …) into the reservoir to trigger in-situ chemical reactions responsible for hydrogen generation. Pyrolysis reaction is one of the significant reactions triggered by in-situ combustion (ISC). This study used a fixed-bed micro-activity test (MAT) unit to investigate hydrogen generation from crude oil through pyrolysis. Crude oil pyrolysis experiments were conducted in the MAT unit under different temperatures (300 °C, 400 °C, 500 °C, 600 °C), atmospheric pressure, and under a flow of a nitrogen gas. The results showed that the threshold initiation temperature of hydrogen generation and coke formation was about 500 °C. The experiments demonstrated that the introduced sandstone enhanced hydrogen generation and coke formation at high temperatures. The maximum volume of hydrogen generated with sandstone effect reached 8.15 mL at 600 °C, while that without sandstone was only 6.39 mL at 600 °C. The study provides deep insights into the in-situ hydrogen generation from crude oil through pyrolysis. In addition, the obtained data of various pyrolysis products provide a comprehensive representation of crude oil pyrolysis that could promote the existing reaction models of in-situ hydrogen generation from the gasification of crude oil. The findings demonstrate the potential of adopting pyrolysis of crude oil for direct hydrogen generation from reservoirs.</div></div>","PeriodicalId":37433,"journal":{"name":"Petroleum","volume":"11 3","pages":"Pages 366-376"},"PeriodicalIF":4.2,"publicationDate":"2025-06-01","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"144501492","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}