Journal of Natural Gas Science and Engineering最新文献

{"title":"Machine-learning-based well production prediction under geological and hydraulic fracture parameters uncertainty for unconventional shale gas reservoirs","authors":"Cong Xiao ,&nbsp;Guangdong Wang ,&nbsp;Yayun Zhang ,&nbsp;Ya Deng","doi":"10.1016/j.jngse.2022.104762","DOIUrl":"https://doi.org/10.1016/j.jngse.2022.104762","url":null,"abstract":"<div><p><span><span>Shale gas production prediction under history-matching-based geomodel is crucial to achieve reliable assessment and economic management of unconventional shale resources, however, conventional history matching is generally performed through repeatedly running high-fidelity </span>reservoir simulations<span> and therefore presents intensive computation-cost in practical applications. Without the need of history matching step, this work presents an efficient and robust post-history production forecasting framework using a latent-space learning-based direct forecast approach, e.g., referred to as LS-LDFA. A novel dimensionality reduction method, e.g., convolutional autoencoder, is employed to regularize the multi-well time-series data by low-order representation within a latent space. Once the machine-learning proxy is trained offline, the online post-history production forecast can be efficiently achieved by input history data. This paper presents some comparative studies between LS-LDFA and model-based history matching. This approach is tested on two examples with an increasing complexity, e.g., a multi-fractured horizontal well and a </span></span>naturally fractured reservoir<span> model with multi-well-pad-production based on synthetic shale formation. The results confirm that the method achieves high robustness and computational efficiency simultaneously in comparison with the conventional history matching. The application of learning-based direct forecast approach can effectively fuse information from history data and thus support reliable decision-making and risk assessment.</span></p></div>","PeriodicalId":372,"journal":{"name":"Journal of Natural Gas Science and Engineering","volume":"106 ","pages":"Article 104762"},"PeriodicalIF":4.965,"publicationDate":"2022-10-01","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"1529724","PeriodicalName":null,"FirstCategoryId":null,"ListUrlMain":null,"RegionNum":2,"RegionCategory":"工程技术","ArticlePicture":[],"TitleCN":null,"AbstractTextCN":null,"PMCID":"","EPubDate":null,"PubModel":null,"JCR":null,"JCRName":null,"Score":null,"Total":0}

{"title":"Pore-scale simulation of gas-water two-phase flow in volcanic gas reservoir based on Volume of Fluid method","authors":"Yongfei Yang ,&nbsp;Quan Xu ,&nbsp;Xinze Li ,&nbsp;Lianjin Zhang ,&nbsp;Xuemei Lan ,&nbsp;Junjie Wang ,&nbsp;Kai Zhang ,&nbsp;Hai Sun ,&nbsp;Lei Zhang ,&nbsp;Jun Yao","doi":"10.1016/j.jngse.2022.104733","DOIUrl":"https://doi.org/10.1016/j.jngse.2022.104733","url":null,"abstract":"<div><p><span><span><span>Understanding the transport process of gas-water flow in volcanic gas reservoir is of key importance for natural gas production. However, there is still limited evidence on the precise influence of volcanic reservoir type, </span>capillary number and </span>wettability<span>. We thus performed gas-water flow simulations (using Volume of Fluid method) at different capillary numbers under different wettability conditions directly on microcomputed tomography<span> (μ-CT) images. The simulation results demonstrated that the eddy current in dead-end corners is the main mechanism for the formation of </span></span></span>residual gas<span>. The gas phase near the wall of fractured porous medium<span><span> was mainly dominated by drag force, resulting in lower residual gas saturation. Moreover, it is generally believed that a low capillary number facilitates the displacement of residual gas in dead-end corners. However, we found that under high temperature (&gt;100 °C) and high pressure (&gt;100 MPa), less residual gas distributed in dead-end corners at higher capillary number. This showed that the conventional percolation law was unlikely to provide reliable predictions in fluid distribution under </span>high temperature and high pressure. The wettability of rock affected the shape of displacement front. The water-gas flow dynamics under water-wet condition was piston like. However, fingering flow occurred under non-hydrophilic condition, and snap-off trapping was more likely to occur, resulting in higher residual gas saturation. This work provides fundamental data on the influence of pore structure, capillary number and wettability on gas-water flow and aids in the further advancements of improved nature gas recovery in volcanic reservoirs.</span></span></p></div>","PeriodicalId":372,"journal":{"name":"Journal of Natural Gas Science and Engineering","volume":"106 ","pages":"Article 104733"},"PeriodicalIF":4.965,"publicationDate":"2022-10-01","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"3454234","PeriodicalName":null,"FirstCategoryId":null,"ListUrlMain":null,"RegionNum":2,"RegionCategory":"工程技术","ArticlePicture":[],"TitleCN":null,"AbstractTextCN":null,"PMCID":"","EPubDate":null,"PubModel":null,"JCR":null,"JCRName":null,"Score":null,"Total":0}

{"title":"Insight into the anti-corrosion performance of synthesized novel nano polymeric material of SiO2 for the protection of J55 steel in 3.5 wt% NaCl solution saturated with carbon dioxide","authors":"Wenlong Song ,&nbsp;Xia Dayu ,&nbsp;Liu Mingxing ,&nbsp;K.R. Ansari ,&nbsp;Ambrish Singh","doi":"10.1016/j.jngse.2022.104758","DOIUrl":"https://doi.org/10.1016/j.jngse.2022.104758","url":null,"abstract":"<div><p><span>The oil and gas industry<span><span> faces a great challenge and loss due to corrosion in the sweet aggressive medium. To overcome this effect addition of corrosion inhibitors, especially eco-friendly ones, are the prime additive. The description in this paper includes the synthesis of nano-sized novel </span>polymeric composite material of SiO</span></span>₂, i.e., n-SiO₂/P (ANA), and its application as a sweet corrosion inhibitor (3.5 wt% NaCl saturated with CO₂) for J55 steel. The characterization of synthesized n-SiO₂<span><span>/P (ANA) was done via spectroscopic techniques. The chemical and electrochemical methods were used to evaluate the inhibitive performance. The surface texture of both protected and corroded samples was analyzed via scanning electron microscopy (SEM), Energy-dispersive X-ray spectroscopy (EDX), and </span>atomic force microscopy (AFM). The results of EIS and PDP reveal the increase in </span><em>R</em>_ct values with the rising amount of n-SiO2/P (ANA) and the anodic nature of n-SiO₂/P (ANA) inhibiting action. The maximum inhibitive performance result is 92% at 400 mg/L. The Langmuir plot supports the best fitting experimental data. The surface study supports the n-SiO₂/P (ANA) covering onto J55 steel.</p></div>","PeriodicalId":372,"journal":{"name":"Journal of Natural Gas Science and Engineering","volume":"106 ","pages":"Article 104758"},"PeriodicalIF":4.965,"publicationDate":"2022-10-01","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"3137335","PeriodicalName":null,"FirstCategoryId":null,"ListUrlMain":null,"RegionNum":2,"RegionCategory":"工程技术","ArticlePicture":[],"TitleCN":null,"AbstractTextCN":null,"PMCID":"","EPubDate":null,"PubModel":null,"JCR":null,"JCRName":null,"Score":null,"Total":0}

{"title":"Hydraulic diffusivity estimations for US shale gas reservoirs with Gaussian method: Implications for pore-scale diffusion processes in underground repositories","authors":"Ruud Weijermars ,&nbsp;Clement Afagwu","doi":"10.1016/j.jngse.2022.104682","DOIUrl":"https://doi.org/10.1016/j.jngse.2022.104682","url":null,"abstract":"<div><p><span><span>This paper first presents so-called unified Gaussian solutions for the spatial advance of diffusion transients triggered by a sudden change in pressure, molecular mass<span><span> concentration and/or temperature. The mathematical description<span> with a Gaussian solution for the pressure transient<span> is similar to that for molecular diffusion and quantifies the diffusion of pressure into the reservoir space due to a change in molecular density initiated at the well intervention point. The resulting </span></span></span>pressure gradients<span> due to the pressure transient quantify, via Darcy's Law, the fluid-particle velocity resulting from that gradient everywhere in the reservoir. Also based on the Gaussian pressure transient, a Gaussian decline curve fitting formula is derived, uniquely scaled by the hydraulic </span></span></span>diffusivity<span>. The physics-based, Gaussian decline curve equation was utilized to match 30-year production data from 68 counties in four major US shale gas plays to compute their hydraulic diffusivities. The average hydraulic diffusivities of Marcellus, Haynesville-Bossier, Barnett and Utica shale are 7.43 × 10</span></span>⁻⁹ m² s⁻¹, 7.9 × 10⁻⁹ m² s⁻¹, 12.3 × 10⁻⁹ m² s⁻¹, and 59.0 × 10⁻⁹ m² s⁻¹<span><span>, respectively. The empirical history-matched estimates of the pressure-gradient-driven diffusion rates in shale are similar or faster than the shale diffusion-rates measured in the laboratory. It can be assumed that the empirical diffusion rate accounts for the integrated effects of Darcy and non-Darcy flow. Computation of the Gaussian Péclet number<span> in gas plays confirms that the advective flux is much faster than the combined Fickean and non-Fickean mass transport rates. The implications for gas recovery from shale formations, and secure disposal of </span></span>nuclear waste in the subsurface shale repositories (wellbores and cavities) are discussed. In particular, our field estimations being faster than the laboratory diffusion rates calls for caution because mass transport from leaking containers at disposal sites would diffuse several orders of magnitude faster than suggested by the slower laboratory rates.</span></p></div>","PeriodicalId":372,"journal":{"name":"Journal of Natural Gas Science and Engineering","volume":"106 ","pages":"Article 104682"},"PeriodicalIF":4.965,"publicationDate":"2022-10-01","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"1830229","PeriodicalName":null,"FirstCategoryId":null,"ListUrlMain":null,"RegionNum":2,"RegionCategory":"工程技术","ArticlePicture":[],"TitleCN":null,"AbstractTextCN":null,"PMCID":"","EPubDate":null,"PubModel":null,"JCR":null,"JCRName":null,"Score":null,"Total":0}

{"title":"A semi-analytical solution technique for predicting circulating mud temperatures","authors":"Can Polat","doi":"10.1016/j.jngse.2022.104754","DOIUrl":"https://doi.org/10.1016/j.jngse.2022.104754","url":null,"abstract":"<div><p><span>Accurate prediction of circulating fluid temperature in wellbore is required for proper drilling operations and design of the closed-loop systems. This study involves the improvement of the traditional analytical solution based on the assumption of constant input values. The presented solutions are derived from the analytical solution of the transient radial </span>heat conduction. Application of the superposition theorem and combination of the analytical solutions established for each segment constituting the wellbore to account for temporal and positional variations are the main features of the semi-analytical solution presented in this study. In this respect, it can be asserted that the solution is also valid for variable mud/water circulation in deviated and horizontal wells.The presented solution is validated using the pertinent results of the traditional analytical solution. The results of the semi-analytical solution for realistic wellbore design reveal the possible deviations from temperature profile corresponding to analytical solution. The temperature profile as a result of the circulation with variable rate in a designed horizontal well is examined to test the presented semi-analytical solution. The trials indicate that the semi-analytical solution which is able to be implemented with plausible computational effort can be an alternative improvement for the traditional analytical solution.</p></div>","PeriodicalId":372,"journal":{"name":"Journal of Natural Gas Science and Engineering","volume":"106 ","pages":"Article 104754"},"PeriodicalIF":4.965,"publicationDate":"2022-10-01","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"1830231","PeriodicalName":null,"FirstCategoryId":null,"ListUrlMain":null,"RegionNum":2,"RegionCategory":"工程技术","ArticlePicture":[],"TitleCN":null,"AbstractTextCN":null,"PMCID":"","EPubDate":null,"PubModel":null,"JCR":null,"JCRName":null,"Score":null,"Total":0}

{"title":"Transient analysis of horizontal wells with multiple fractures in sour gas reservoirs","authors":"Bo Fang ,&nbsp;Jinghong Hu ,&nbsp;Xiaodong Wang ,&nbsp;Yuan Zhang","doi":"10.1016/j.jngse.2022.104730","DOIUrl":"https://doi.org/10.1016/j.jngse.2022.104730","url":null,"abstract":"<div><p><span><span><span>Due to the decrease of reservoir pressure<span>, the elemental sulfur deposits in sour gas reservoirs, leading to the reduction in the reservoir porosity and permeability. It can also impact the </span></span>transient pressure and rate behavior of gas wells, which is always reflected in pressure and flow rate type curves. However, few studies focus on transient analysis of multi-fractured horizontal wells affected by sulfur deposition. Therefore, the objective of this work is to develop a comprehensive model to analyze the transient pressure and flow rate of multi-fractured horizontal wells in sour gas reservoirs. Pseudo-time function and pseudo-pressure function are derived and the point source method is applied in this model. Then the proposed model is validated against analytical solutions and real production data. Furthermore, sensitivity analysis for pressure and rate type curves was conducted. Results show that the pressure type curves can be divided into six stages. The reservoir with higher H2S concentration will result in more sulfur deposition, which requires larger pressure difference to maintain a constant rate in the late time. </span>Fracture properties impact </span>flow rate in the early production time, and increasing fracture conductivity and fracture number is helpful to reduce the generation of sulfur deposition. For a smaller reservoir, larger pressure difference is essential to stabilize constant production rate, which means more sulfur deposition will be produced in the reservoir. During the development of sour gas reservoir, it is important to control flow rate to reduce pressure depletion for decrease amount of sulfur deposition. This paper reveals the impacts of sulfur deposition on type curves and provides a comprehensive transient analysis for multi-fractured horizontal wells in the development of sour gas reservoirs.</p></div>","PeriodicalId":372,"journal":{"name":"Journal of Natural Gas Science and Engineering","volume":"106 ","pages":"Article 104730"},"PeriodicalIF":4.965,"publicationDate":"2022-10-01","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"1830216","PeriodicalName":null,"FirstCategoryId":null,"ListUrlMain":null,"RegionNum":2,"RegionCategory":"工程技术","ArticlePicture":[],"TitleCN":null,"AbstractTextCN":null,"PMCID":"","EPubDate":null,"PubModel":null,"JCR":null,"JCRName":null,"Score":null,"Total":0}

{"title":"Full coupling of CO2–CH4 transport and sorption with solid deformation in gas shale enhances natural gas recovery and geological CO2 storage capacity","authors":"Wei Zhang ,&nbsp;Amin Mehrabian","doi":"10.1016/j.jngse.2022.104736","DOIUrl":"https://doi.org/10.1016/j.jngse.2022.104736","url":null,"abstract":"<div><p><span><span><span>A thermodynamically rigorous constitutive model is used to describe the full coupling among the nonlinear processes of transport, </span>sorption, and solid deformation in organic shale where the </span>pore fluid<span> is the binary mixture of carbon dioxide and methane. The constitutive model is utilized in a numerical solution that simulates injection of carbon dioxide in shale before producing carbon dioxide and methane from the same. The solution considers advection<span><span> and diffusion as viable mechanisms of pore fluid transport where the latter comprises molecular, Knudsen, and surface diffusion in ultralow permeability shale. Results indicate that </span>gas adsorption would be the main storage mechanism of sequestration in shale which may comprise up to 70% of the stored CO</span></span></span>₂<span><span> mass. A third of this storage capacity could be due to the geomechanical effects. Therefore, complete or partial exclusion of the coupling between sorption and solid phase deformation from the solution would result in underestimation of carbon dioxide storage<span> capacity and natural gas recovery factor of the rock. Surface diffusion, sorption-induced deformation, as well as strain-induced changes in gas sorption capacities, are all conducive to both outcomes. Sensitivity analysis shows that the solution results are most sensitive to changes in adsorption capacities<span>, followed by initial permeability, Young's modulus, </span></span></span>Poisson's ratio<span>, surface diffusivities, and initial pore radius.</span></span></p></div>","PeriodicalId":372,"journal":{"name":"Journal of Natural Gas Science and Engineering","volume":"106 ","pages":"Article 104736"},"PeriodicalIF":4.965,"publicationDate":"2022-10-01","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"1830226","PeriodicalName":null,"FirstCategoryId":null,"ListUrlMain":null,"RegionNum":2,"RegionCategory":"工程技术","ArticlePicture":[],"TitleCN":null,"AbstractTextCN":null,"PMCID":"","EPubDate":null,"PubModel":null,"JCR":null,"JCRName":null,"Score":null,"Total":0}

{"title":"The influence of confining stress and pore pressure on effective stress coefficient for permeability: A novel Discretized Clay Shell Model for clayey sandstone","authors":"P.L. Tai ,&nbsp;J.J. Dong","doi":"10.1016/j.jngse.2022.104777","DOIUrl":"https://doi.org/10.1016/j.jngse.2022.104777","url":null,"abstract":"<div><p>The effective stress coefficient <span><math><mrow><mi>α</mi></mrow></math></span> determines the effective stress and dominates the permeability of rocks. This study proposes a novel theoretical model called the Discretized Clay Shell Model (DCSM) that modifies the Clay Shell Model (CSM) by incorporating the stress-dependent elastic modulus of clay into a discretized multi-layer clay domain to depict the relationship between <span><math><mrow><mi>α</mi></mrow></math></span>, pore pressure, and confining stress. The proposed model was successfully used to provide insights into the stress-dependent <span><math><mrow><mi>α</mi></mrow></math></span> of clayey sandstones. We found that <span><math><mrow><mi>α</mi></mrow></math></span> always decreased with increasing pore pressure and could decrease or increase with increasing confining stress. The modelling trends, which are also observed in the previous laboratory tests, can be well explained using two effects due to the heterogeneity of radial stress within clay domain, that is, the bulk and differential clay hardening effects. The bulk clay hardening effect generates a decreasing trend in <span><math><mrow><mi>α</mi></mrow></math></span> with increasing pore pressure, while the differential clay hardening effect competes with the bulk clay hardening effect and yields a reverse trend, that is, <span><math><mrow><mi>α</mi></mrow></math></span> first decreases with increasing confining stress and then decreases when the confining stress reaches a certain critical value. This study provides synthetic cases to quantify the influence of stress-dependent <span><math><mrow><mi>α</mi></mrow></math></span> evaluated by the DCSM on the evaluation of the permeability-depth relation. Based on the laboratory testing data, the calibrated parameters of the stress-dependent permeability model assuming <span><math><mrow><mi>α</mi><mo>=</mo><mn>1</mn></mrow></math></span> are significantly overestimated, and the prediction model yields overestimated permeability up to three to four orders of magnitude. Meanwhile, the synthetic in-situ case shows that the predicted permeability could be underestimated by up to one third, and the errors due to laboratory analysis that neglect the stress dependency of <span><math><mrow><mi>α</mi></mrow></math></span> will propagate to and amplify the errors of prediction for the in-situ permeability-depth relation.</p></div>","PeriodicalId":372,"journal":{"name":"Journal of Natural Gas Science and Engineering","volume":"106 ","pages":"Article 104777"},"PeriodicalIF":4.965,"publicationDate":"2022-10-01","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"1830233","PeriodicalName":null,"FirstCategoryId":null,"ListUrlMain":null,"RegionNum":2,"RegionCategory":"工程技术","ArticlePicture":[],"TitleCN":null,"AbstractTextCN":null,"PMCID":"","EPubDate":null,"PubModel":null,"JCR":null,"JCRName":null,"Score":null,"Total":0}

{"title":"Experimental investigation on inorganic scaling induced by the shale reaction with oxidation solution","authors":"Jiaxin Shao ,&nbsp;Yili Kang ,&nbsp;Lijun You ,&nbsp;Na Jia ,&nbsp;Mingjun Chen","doi":"10.1016/j.jngse.2022.104717","DOIUrl":"https://doi.org/10.1016/j.jngse.2022.104717","url":null,"abstract":"<div><p><span>Inorganic scale produced from shale reservoir oxidation<span><span> during hydraulic fracturing will block pores and fractures, thus hindering the multi-scale transportation of </span>shale gas. The results show that the cations produced after soaking in distilled water mainly consisted of Ca</span></span>²⁺, Mg²⁺, Na⁺, K⁺ and Fe²⁺<span>. Pyrite and chlorite contain reduced Fe, and the oxidized solution dissolves the reduced iron in shale, further increasing the ion concentration in shale, especially the Fe</span>²⁺. The shale produced precipitation and solid particles after soaking in solutions containing dissolved oxygen and different oxidation solutions. The oxidation solution affects the concentration of ions and the type of solid particles produced in the soaking process.</p></div>","PeriodicalId":372,"journal":{"name":"Journal of Natural Gas Science and Engineering","volume":"106 ","pages":"Article 104717"},"PeriodicalIF":4.965,"publicationDate":"2022-10-01","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"3454231","PeriodicalName":null,"FirstCategoryId":null,"ListUrlMain":null,"RegionNum":2,"RegionCategory":"工程技术","ArticlePicture":[],"TitleCN":null,"AbstractTextCN":null,"PMCID":"","EPubDate":null,"PubModel":null,"JCR":null,"JCRName":null,"Score":null,"Total":0}

{"title":"Analysis of micropore size distribution using Dubinin's theory of volume filling - Effect of particle size on pore characterization of organic-rich Indian shales","authors":"Venkata Yasaswy Turlapati ,&nbsp;Basanta Kumar Prusty ,&nbsp;Dheeraj Kumar Yarlagadda ,&nbsp;Samir Kumar Pal ,&nbsp;Elangovan Raja","doi":"10.1016/j.jngse.2022.104746","DOIUrl":"https://doi.org/10.1016/j.jngse.2022.104746","url":null,"abstract":"<div><p><span><span><span>Micropores play a significant role in adsorption and are abundant in a shale pore structure. The influence of particle size on pore structure parameters, especially micropores, is a subject of primary interest for </span>shale gas characterisation. In this work, a total of 6 samples with varying mineralogical and organic content are selected from 2 Indian </span>sedimentary basins, Cambay and Krishna-Godavari. Selected samples were crushed to different particle sizes 500-425 μm (M1), 425-250 μm (M2), 250-150 μm (M3), and 150-75 μm (M4) and low pressure N</span>₂ and CO₂ adsorption experiments at 77 K and 273 K were performed on them. Through these experiments, it was observed that, with crushing of samples to smaller particle sizes low-pressure N₂<span> adsorption tend to show higher values for total pore volume and average pore diameter. The mean difference over all samples for average pore diameter between M4 and M1 particle size is closer to 1 nm. Similarly, the mean difference over all samples for total pore volume between M4 and M1 particle sizes of all samples is 0.005 cc/g, which is almost closer to their micropore volumes. Such inconsistencies in measurements can lead to serious errors in shale gas exploration. Further, the low pressure N</span>₂ experiments indicated that M4 particle size samples show higher values of pore structure parameters, and low pressure CO₂ experiments show that M3 particle size shows higher micropore volumes. For further understanding of nano-sized pore contributions, micropore size distributions of the samples have been constructed using Stoeckli pore size distribution function. From these distributions and other analysis, it was concluded that the smallest particle size overestimates the pore structure parameters and M3 particle size is optimum for both low pressure N₂ and CO₂ adsorption.</p></div>","PeriodicalId":372,"journal":{"name":"Journal of Natural Gas Science and Engineering","volume":"106 ","pages":"Article 104746"},"PeriodicalIF":4.965,"publicationDate":"2022-10-01","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"3454233","PeriodicalName":null,"FirstCategoryId":null,"ListUrlMain":null,"RegionNum":2,"RegionCategory":"工程技术","ArticlePicture":[],"TitleCN":null,"AbstractTextCN":null,"PMCID":"","EPubDate":null,"PubModel":null,"JCR":null,"JCRName":null,"Score":null,"Total":0}