Geofluids最新文献

{"title":"Surface Treatment of Rammed Earth Heritage Sites Using MICP Technology: An Investigation of Rainwater Erosion Resistance via Indoor Experiments and In Situ Testing","authors":"Liang Liu,&nbsp;Yun Zhang,&nbsp;Wanting Chen,&nbsp;Haiying Cao,&nbsp;Lianjun Guo,&nbsp;Lingling Zheng,&nbsp;Tianli Li,&nbsp;Rong Shu,&nbsp;Dongdong Li","doi":"10.1155/2024/2083124","DOIUrl":"https://doi.org/10.1155/2024/2083124","url":null,"abstract":"<p>Rammed earth, a commonly used building material in ancient times, differs from natural sedimentary layers in that it is more compact. Buildings constructed from historical rammed earth sites frequently encounter the issue of rainwater erosion. Microbially induced calcium carbonate precipitation (MICP) is commonly applied to sand soil treatment, yet reports on its use for stabilizing rammed earth are scarce. This study focused on the rammed earth of the Shanhaiguan Great Wall and explored the efficacy of MICP in mitigating rain erosion through permeation tests, splash experiments, and scouring trials. The findings indicate that the forms of rain erosion damage under MICP treatment vary across different operational conditions. In laboratory experiments, as the concentration of the cementation solution increases, the amount of calcium carbonate crystals also increases. However, the permeability, splash resistance, and rain erosion resistance initially increase and then decrease. When the cementation solution concentration is 1.0 mol/L, the penetration rate is the highest, lasting 712.55 s. The splash pit rate is the lowest, at only 1.2 mm, and the soil erosion rate is the lowest, at only 4.13%. The rain erosion resistance in the field test exhibit the same trend, and the optimal concentration is 1.2 mol/L. The optimal concentration mechanism involves the aggregation of calcium carbonate crystals at suitable cementation solution concentrations, which begin to fill the soil particle pores, effectively resisting rainwater erosion. At lower concentrations of the cementation solution, calcium carbonate crystals are merely adsorbed by soil particles without blocking the pores. Due to the high compressibility of rammed earth, which results in lower porosity, a higher concentration of the cementation solution leads to rapid pore clogging by excessive calcium carbonate crystals, which accumulate on the surface to form a white crust layer. The MICP technique can effectively alleviate rainwater erosion in rammed earth, and the optimal concentration needs to be tailored to the porosity of the rammed earth. This mechanism was also validated in field scouring experiments on the Shanhaiguan Great Wall’s rammed earth.</p>","PeriodicalId":12512,"journal":{"name":"Geofluids","volume":"2024 1","pages":""},"PeriodicalIF":1.2,"publicationDate":"2024-10-19","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"https://onlinelibrary.wiley.com/doi/epdf/10.1155/2024/2083124","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"142451734","PeriodicalName":null,"FirstCategoryId":null,"ListUrlMain":null,"RegionNum":4,"RegionCategory":"地球科学","ArticlePicture":[],"TitleCN":null,"AbstractTextCN":null,"PMCID":"OA","EPubDate":null,"PubModel":null,"JCR":null,"JCRName":null,"Score":null,"Total":0}

{"title":"Numerical Simulation Study on In-Depth Profile Control of Core–Shell Coagulation System Considering the Time-Variation of Permeability","authors":"Zhaobo Sun,&nbsp;Shuchun Cao,&nbsp;Gongchang Wang,&nbsp;Xiaofei Jia,&nbsp;Guoqing Ning","doi":"10.1155/2024/5030111","DOIUrl":"https://doi.org/10.1155/2024/5030111","url":null,"abstract":"<p>The coring data in high water-cut oilfields indicates that the reservoir permeability will change continuously with water flooding, while the existing reservoir numerical simulation software cannot consider the time-varying phenomenon of permeability. With the enhancement of reservoir heterogeneity, the near-wellbore profile control fails to stabilize the oil production and control the water cut. The in-depth profile control has been widely used in oilfields as a new technology, and the types of profile control agents are diverse, with a complex mechanism that cannot be effectively described by the existing conventional numerical simulation software. Considering these two phenomena comprehensively, a new three-dimensional, three-phase, six-component mathematical model that can take into account the time-varying phenomenon of reservoir permeability is proposed for a new kind of in-depth profile control system, namely, the core–shell coagulation system, and an integrated numerical simulation software is developed. The mechanism of the in-depth profile control system can be perfectly demonstrated in the simulator with time-variation of permeability. The results of sensitivity analysis show that the effect is influenced by three factors: the mix slug injecting concentration, the coagulant aid slug volume, and the concentration of the suspension dispersing agent.</p>","PeriodicalId":12512,"journal":{"name":"Geofluids","volume":"2024 1","pages":""},"PeriodicalIF":1.2,"publicationDate":"2024-10-15","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"https://onlinelibrary.wiley.com/doi/epdf/10.1155/2024/5030111","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"142435441","PeriodicalName":null,"FirstCategoryId":null,"ListUrlMain":null,"RegionNum":4,"RegionCategory":"地球科学","ArticlePicture":[],"TitleCN":null,"AbstractTextCN":null,"PMCID":"OA","EPubDate":null,"PubModel":null,"JCR":null,"JCRName":null,"Score":null,"Total":0}

{"title":"Two-Phase Relative Permeability Curves of Bingham Heavy Oil Under Different Types of Wettability: A Theoretical Model","authors":"Qing Wang,&nbsp;Yu Li,&nbsp;Chao Peng,&nbsp;Jiao Peng,&nbsp;Jingyu Fu,&nbsp;Renjie Liu,&nbsp;Huiqing Liu,&nbsp;Jiaxin Li,&nbsp;Hao Peng","doi":"10.1155/2024/5057354","DOIUrl":"https://doi.org/10.1155/2024/5057354","url":null,"abstract":"<p>As an important and universal petrophysics of heavy oil reservoirs, the two-phase flow ability inside porous medium is vital for heavy oil development. Utilizing the laminar flow theory and an ideal pore structure, especially cylinder model, the function of the relative permeability of heavy oil–water with water saturation is derived by incorporating the principles of momentum conservation and the characteristics of Bingham fluids, which was modified by validated experiment. Two-phase relative permeability, considering heavy oil as non-Newtonian fluid, is the function of water saturation, pore size, oil–water viscosity ratio, and yield stress. The results of the validated experiment show that the theoretical values calculated employing the modified equation exhibit better agreement with the experimental values, particularly when the viscosities of two-phase fluid are great. The results of the modified two-phase relative permeability show a decrease in water saturation interval corresponding to the two-phase flow area and a smaller value of permeability at equal two-phase relative permeability. The oil–water viscosity ratio in the hydrophobic pores affects the water-phase relative permeability, although the magnitude of its influence diminishes as the viscosity ratio increases. The behavior of relative permeability in hydrophilic pores is the opposite of that in hydrophobic pores. This work can afford good application prospects for mobility control in multilayered reservoirs through the heterogeneous-phase-composite fluid. The saturations of the remaining oil and irreducible water also play a vital role in the prediction of permeability. The work can afford good application prospects for the flow behavior of Bingham heavy oil in pores with different types of wettability.</p>","PeriodicalId":12512,"journal":{"name":"Geofluids","volume":"2024 1","pages":""},"PeriodicalIF":1.2,"publicationDate":"2024-10-15","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"https://onlinelibrary.wiley.com/doi/epdf/10.1155/2024/5057354","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"142435443","PeriodicalName":null,"FirstCategoryId":null,"ListUrlMain":null,"RegionNum":4,"RegionCategory":"地球科学","ArticlePicture":[],"TitleCN":null,"AbstractTextCN":null,"PMCID":"OA","EPubDate":null,"PubModel":null,"JCR":null,"JCRName":null,"Score":null,"Total":0}

{"title":"Study on Resistance Loss of Fly Ash Slurry Multistage High-Pressure Grouting Pipeline Based on Fluent","authors":"Qiqing Wang,&nbsp;Linzhe Li,&nbsp;Huijie Wu,&nbsp;Kun Wang,&nbsp;Sixiang Wang","doi":"10.1155/2024/6434066","DOIUrl":"https://doi.org/10.1155/2024/6434066","url":null,"abstract":"<p>In order to understand the resistance loss along the way during multistage high-pressure slurry transportation, the flow state of fly ash slurry in the pipeline was simulated by Fluent software in this paper, and the effects of pipe diameter <i>D</i>, pipe transportation flow rate <i>Q</i>, and fly ash mass concentration <i>C</i>_<i>w</i> on the resistance loss along the pipeline were studied. The fly ash slurry is a non-Newtonian Bingham fluid that moves in a turbulent state in a pipeline. When simulating the flow of fly ash slurry using Fluent software, the mesh type is a mixed mesh of hexahedron and wedge shapes, and the viscous model is selected as realizable k-<i>ε</i> Turbulence Model, with Enhanced-Wall Function (EWF) selected as the wall function, combined with a four-layer boundary layer mesh, which can more accurately capture the details of velocity changes at the wall, thereby improving the accuracy of the model. The inlet of the model is the velocity inlet, and the outlet is the pressure outlet. The coupled algorithm is chosen as the solution method. Under these conditions, the model converges quickly and the calculation accuracy is high. The results show that the resistance loss along the pipeline decreases as a power function with the increase of pipeline diameter, and there is a polynomial relationship between the pipeline flow and the resistance loss along the pipeline, while the mass concentration of fly ash slurry changes linearly with the resistance loss along the pipeline. In addition, three friction coefficient models, namely Blasius formula, Colebrook–White equation, and Wilson–Thomas model, were selected according to the flow characteristics of fly ash slurry. Based on the Blasius formula with the smallest relative calculation error, the Blasius formula was modified by multiple linear regression analysis to improve the accuracy of the frictional resistance coefficient model and to provide help for the design and use of separate layer grouting conveying system.</p>","PeriodicalId":12512,"journal":{"name":"Geofluids","volume":"2024 1","pages":""},"PeriodicalIF":1.2,"publicationDate":"2024-10-12","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"https://onlinelibrary.wiley.com/doi/epdf/10.1155/2024/6434066","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"142429916","PeriodicalName":null,"FirstCategoryId":null,"ListUrlMain":null,"RegionNum":4,"RegionCategory":"地球科学","ArticlePicture":[],"TitleCN":null,"AbstractTextCN":null,"PMCID":"OA","EPubDate":null,"PubModel":null,"JCR":null,"JCRName":null,"Score":null,"Total":0}

{"title":"Hydrothermal Signatures Discovered in Outcropping Rocks of the Los Humeros Geothermal Field (Mexico): A Geochemometric Exploration Case Study","authors":"D. Yáñez-Dávila,&nbsp;E. Santoyo,&nbsp;E. González-Partida,&nbsp;Kailasa Pandarinath,&nbsp;G. Santos-Raga,&nbsp;Sumit Mishra,&nbsp;Z. G. Gómez-Salgado","doi":"10.1155/2024/2316078","DOIUrl":"https://doi.org/10.1155/2024/2316078","url":null,"abstract":"<p>Hydrothermal geochemical signatures in outcropping rock samples of the super-hot Los Humeros geothermal field were discovered by using an integrated geochemometric study of the mobility of components (major oxides) and trace elements. Chemical component and element mobilities were determined by using the Gresens–Grant equation for mass balances. A spatial distribution of component and element mobility patterns was carried out through the mineral characterization, hydrothermal alteration, and whole-rock elemental analysis. Four alteration assemblages were mainly identified: (i) argillic–silicic; (ii) argillic–sericite; (iii) advance argillic–sulphate acid (alunite or jarosite); and (iv) silicic–carbonate. A clear increasing order of mobility for major oxides such as Fe₂O₃^T, P₂O₅, K₂O, MnO, SiO₂, CaO, Al₂O₃, and MgO and trace elements such as Pb, Th, Sr, Zn, V, Rb, Cr, Cu, and Ba was inferred from hydrothermally altered rocks. The mobility of these components and trace elements showed a geochemical association with a higher contribution of Fe₂O₃^T, CaO, V, Cu, Zn, and Sr and a lower contribution of K₂O, Rb, Th, and Cr. The spatial distribution of hydrothermal signatures obtained by tracking the mobilities of major and trace elements in samples collected in a new sector of Los Humeros geothermal field is aligned with NW-SE and NE-SW fault systems. Three areas characterised by a higher permeability were identified, for the first time, from low-cost analyses of rock samples by using energy-dispersive X-ray fluorescence spectrometry. The successful application results obtained from this study provided a new integrated geochemometric method to track high permeability zones for geothermal prospection tasks.</p>","PeriodicalId":12512,"journal":{"name":"Geofluids","volume":"2024 1","pages":""},"PeriodicalIF":1.2,"publicationDate":"2024-10-10","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"https://onlinelibrary.wiley.com/doi/epdf/10.1155/2024/2316078","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"142404568","PeriodicalName":null,"FirstCategoryId":null,"ListUrlMain":null,"RegionNum":4,"RegionCategory":"地球科学","ArticlePicture":[],"TitleCN":null,"AbstractTextCN":null,"PMCID":"OA","EPubDate":null,"PubModel":null,"JCR":null,"JCRName":null,"Score":null,"Total":0}

{"title":"Influence of Permeable Wellbore on Formation Testing While Drilling and Mobility Inversion","authors":"Lejun Wu,&nbsp;Ming Chen,&nbsp;Jianxin Liu,&nbsp;Zhiqiang Zhang,&nbsp;Xiaodong Li,&nbsp;Nian Peng,&nbsp;Tianshou Ma","doi":"10.1155/2024/6711874","DOIUrl":"https://doi.org/10.1155/2024/6711874","url":null,"abstract":"<p>Formation pressure and mobility represent two fundamental parameters that are essential for the development of oil and gas resources. These parameters can be obtained in real time through the process of formation testing while drilling (FTWD). It is highly probable that the drilling fluid will invade the formation during the FTWD process. Nevertheless, the prevailing theory regarding FTWD assumes that the wellbore is impermeable, thereby rendering its potential impact on FTWD and mobility inversion unclear. Therefore, to clarify the influence of the permeable wellbore on FTWD and mobility inversion, a mathematical model of FTWD seepage was first proposed by involving the permeable wellbore. Secondly, the finite element method was used to solve this model, and this model was verified by using the analytical models. The pressure response curves and isobaric surface near the FTWD probe were then compared for both the permeable and impermeable wellbores, and the influence of the permeable wellbore on the pressure response curves of FTWD was analyzed. Finally, the method of integral area was used to invert mobility, and the compressive influence of different factors on both the pressure response curves and mobility inversion was discussed for both the permeable and impermeable wellbores. The results indicated that the permeable wellbore has a significant impact on the pressure response curves and isobaric surface near the probe due to the limited pressure sweeping range around the probe and the invasion of drilling fluid. In the case of a permeable wellbore, the invasion of the drilling fluid into the formation can cause a supercharge effect around the well. This effect can cause an initial increase followed by a decrease in the pressure buildup phase. The pressure buildup always exceeds the original formation pressure, which can lead to an overestimation of the measured formation pressure compared to the original. Meanwhile, the permeable wellbore can also lead to an overestimation of the inversion mobility, but the impermeable wellbore has much less influence on the mobility inversion. To improve inversion accuracy, it is recommended to increase the rubber packer radius, lengthen the suction period, reduce the storage volume of the pipeline, and decrease the overbalanced pressure. However, these measures cannot mitigate the impact of the supercharge effect on formation pressure testing. This paper provides theoretical guidelines for the use of FTWD tools and data interpretation.</p>","PeriodicalId":12512,"journal":{"name":"Geofluids","volume":"2024 1","pages":""},"PeriodicalIF":1.2,"publicationDate":"2024-10-09","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"https://onlinelibrary.wiley.com/doi/epdf/10.1155/2024/6711874","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"142404632","PeriodicalName":null,"FirstCategoryId":null,"ListUrlMain":null,"RegionNum":4,"RegionCategory":"地球科学","ArticlePicture":[],"TitleCN":null,"AbstractTextCN":null,"PMCID":"OA","EPubDate":null,"PubModel":null,"JCR":null,"JCRName":null,"Score":null,"Total":0}

{"title":"Corrigendum to “The Conformal Finite-Difference Time-Domain Simulation of GPR Wave Propagation in Complex Geoelectric Structures”","authors":"Man Yang,&nbsp;Hongyuan Fang,&nbsp;Dazhong Chen,&nbsp;Xueming Du,&nbsp;Fuming Wang","doi":"10.1155/2024/9896545","DOIUrl":"https://doi.org/10.1155/2024/9896545","url":null,"abstract":"<p>In the article titled “The Conformal Finite-Difference Time-Domain Simulation of GPR Wave Propagation in Complex Geoelectric Structures” [<span>1</span>], the postal code in Dazhong Chen’s affiliation was incorrectly shown as 450001 and should be corrected as above to 450016.</p>","PeriodicalId":12512,"journal":{"name":"Geofluids","volume":"2024 1","pages":""},"PeriodicalIF":1.2,"publicationDate":"2024-10-06","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"https://onlinelibrary.wiley.com/doi/epdf/10.1155/2024/9896545","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"142404327","PeriodicalName":null,"FirstCategoryId":null,"ListUrlMain":null,"RegionNum":4,"RegionCategory":"地球科学","ArticlePicture":[],"TitleCN":null,"AbstractTextCN":null,"PMCID":"OA","EPubDate":null,"PubModel":null,"JCR":null,"JCRName":null,"Score":null,"Total":0}

{"title":"Comprehensive Application of Borehole Fine Detection Methods: A Case Study in Shantou Bay Subsea Tunnel","authors":"Chengkun Wang,&nbsp;Zhengyu Liu,&nbsp;Zhao Dong,&nbsp;Fengkai Zhang,&nbsp;Chuanyi Ma,&nbsp;Xiaolin Xu,&nbsp;Qian Guo","doi":"10.1155/2024/5546191","DOIUrl":"https://doi.org/10.1155/2024/5546191","url":null,"abstract":"<p>Water inrush disaster is one of the most severe problems during the construction of sea tunnels, primarily due to faults, karst, and weathered zones. Once a water inrush disaster occurs, it can lead to construction delays, traffic disruptions, and major economic losses, as well as potential consequences such as seawater intrusion, casualties, project suspension, and tunnel closure. Thus, advanced geological prediction is indispensable. During the construction of the Shantou Bay subsea tunnel, a sudden water inrush accident occurred in the sea–land transition section. To prevent such incidents and ensure safety, an integrated approach was employed. Firstly, the cross-hole resistivity method was used to predict water content in front of the tunnel, as it is highly sensitive to water. Subsequently, borehole ground-penetrating radar was applied to finely characterize the geological structure. By combining these two methods, the size, scale, location, water content, and spatial distribution of water-bearing structures in front of the tunnel were identified. With the above measures, the Shantou Bay subsea tunnel passed through the detection section successfully. Herein, we present a case study and offer a valuable reference for similar projects concerning subsea tunnel construction.</p>","PeriodicalId":12512,"journal":{"name":"Geofluids","volume":"2024 1","pages":""},"PeriodicalIF":1.2,"publicationDate":"2024-10-01","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"https://onlinelibrary.wiley.com/doi/epdf/10.1155/2024/5546191","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"142404250","PeriodicalName":null,"FirstCategoryId":null,"ListUrlMain":null,"RegionNum":4,"RegionCategory":"地球科学","ArticlePicture":[],"TitleCN":null,"AbstractTextCN":null,"PMCID":"OA","EPubDate":null,"PubModel":null,"JCR":null,"JCRName":null,"Score":null,"Total":0}

{"title":"Three-Dimensional Numerical Simulation of Fracture Extension in Conglomerate Fracturing Considering Pore-Fracture Seepage and Study of Influencing Factors","authors":"Zehao Xu,&nbsp;Haiyang Zhao,&nbsp;Xiangjun Liu,&nbsp;Lixi Liang,&nbsp;Pandeng Luo","doi":"10.1155/2024/7883958","DOIUrl":"https://doi.org/10.1155/2024/7883958","url":null,"abstract":"<p>The nonhomogeneity of conglomerate in terms of organization and the complexity of fracture extension make the design and effective implementation of fracturing in conglomerate reservoirs challenging. Considering the limitations of physical experiments and two-dimensional (2D) numerical modeling, this paper adopts the continuum-discontinue element method (CDEM) to carry out numerical simulation of three-dimensional (3D) conglomerate fracturing considering pore-fracture seepage. By introducing multiple parameters to quantify the correlation between fracture geometry, fracture complexity, and damage mode, the evolution mechanism of fracture morphology under the influence of multiple factors is systematically investigated. The results show that the numerical simulation experiments can control the variables well, but the random distribution of gravel leads to the unpredictability of fracture extension, and the concluding patterns obtained still show large fluctuations. The high permeability of the gravel promotes the development of gravel-penetrating fractures but has less effect on the overall morphology of the fractures. High-strength gravel promotes the development of branching fractures in the initiation phase, which acts as a barrier to expanding fractures, and the most complex fracture development occurs when the gravel strength is approximately 4–5 times that of the matrix. In the weakly cemented state, fracture development around the gravel contributes to the shear failure of the conglomerate, but the strength of the cemented interface has no obvious control on the overall fracture morphology. The correlation between gravel content and conglomerate damage mode is significant, with the highest degree of fracture complexity occurring when the gravel content is approximately 30%. Stress differential is the most significant controlling factor affecting fracture morphology, followed by minimum principal stress. When the stress difference reaches 8 MPa, the fracture morphology begins to stabilize, and too high a stress difference will cause the phenomenon that the fracture stops expanding, affecting the fracturing effect. A high level of minimum stress promotes tensile failure in conglomerate, and the scale and complexity of fracture decrease. High injection displacement promotes branch fracture development and reduces the effect of in situ stress on fracture extension, and too high a displacement leads to inhibition of main fracture development.</p>","PeriodicalId":12512,"journal":{"name":"Geofluids","volume":"2024 1","pages":""},"PeriodicalIF":1.2,"publicationDate":"2024-10-01","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"https://onlinelibrary.wiley.com/doi/epdf/10.1155/2024/7883958","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"142404392","PeriodicalName":null,"FirstCategoryId":null,"ListUrlMain":null,"RegionNum":4,"RegionCategory":"地球科学","ArticlePicture":[],"TitleCN":null,"AbstractTextCN":null,"PMCID":"OA","EPubDate":null,"PubModel":null,"JCR":null,"JCRName":null,"Score":null,"Total":0}

{"title":"Cavitation-Induced Shear Failure Mechanism of Fractured Plugging Zone and Structure Strengthening Method for Lost Circulation Control in High-Temperature and High-Pressure Fractured Gas Reservoirs","authors":"Xiaoming Su,&nbsp;Xiaodong Wang,&nbsp;Yuan Yuan,&nbsp;Yun Ren,&nbsp;Wang Gaoming","doi":"10.1155/2024/8856179","DOIUrl":"https://doi.org/10.1155/2024/8856179","url":null,"abstract":"<p>The stability of the plugging zone has a great impact on lost circulation control and gas invasion prevention in fractured reservoirs. In this work, the concept of “cavitation-induced shear failure” is put forward based on the analysis of the flow field characteristics, and the failure mechanism is discussed. The strength physical model of a fractured plugging zone is formed based on the analysis of the characteristic parameters of LCMs and the failure mechanism. And then the simulation experiments of cavitation-induced shear failure, gas invasion prevention, pressure bearing, and tight plugging are carried out. The research shows that (1) the fractured plugging zone is a dense granular matter system, and the contact forces and quid bridge force are dominant in its internal; (2) the cavitation-induced shear failure is one of the main failure modes of the plugging zone in a fractured gas reservoir, and the failure process includes three steps: gas diffusion-dilution damage, confluence and carry damage, and displacement dislocation shear failure; (3) the strengthening model of the plugging zone, “rigid bridging+elastoplastic filling+lacing wire of fiber+film-forming seal,” is a better model, and experiments prove that it can form a tight pressure-bearing plugging zone, preventing drill-in fluid loss. The research results provide a theoretical and technical basis for the lost circulation control of fractured gas formations.</p>","PeriodicalId":12512,"journal":{"name":"Geofluids","volume":"2024 1","pages":""},"PeriodicalIF":1.2,"publicationDate":"2024-09-26","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"https://onlinelibrary.wiley.com/doi/epdf/10.1155/2024/8856179","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"142320766","PeriodicalName":null,"FirstCategoryId":null,"ListUrlMain":null,"RegionNum":4,"RegionCategory":"地球科学","ArticlePicture":[],"TitleCN":null,"AbstractTextCN":null,"PMCID":"OA","EPubDate":null,"PubModel":null,"JCR":null,"JCRName":null,"Score":null,"Total":0}