Geoenergy Science and Engineering最新文献

{"title":"Feasibility analysis of gas storage salt caverns in ultra-deep strata with thick interlayers","authors":"Hang Li ,&nbsp;Chunhe Yang ,&nbsp;Hongling Ma ,&nbsp;Zhentao Li ,&nbsp;Xiaopeng Liang ,&nbsp;Rui Cai ,&nbsp;Xuan Wang ,&nbsp;Jiangyu Fang ,&nbsp;Ziheng Wang","doi":"10.1016/j.geoen.2025.213994","DOIUrl":"10.1016/j.geoen.2025.213994","url":null,"abstract":"<div><div>To address peak-shaving demand and ensure energy security, deep underground energy storage stands as a crucial approach in the development of future energy reserves. The target depth of the underground gas storage salt cavern (GSSC) in the Jingjie district of Yulin City, China, exceeds 2600 m. Based on the geological characteristics, a new scheme for constructing an ultra-deep GSSC with thick interlayers was proposed, and a geomechanical model was developed. The simulation results indicated that the thick interlayer in 9 sub-members collapsed when the cavern pressure decreased to 12 MPa. Based on an extensive evaluation system, the stability of the GSSC with thick interlayers was analyzed. The results indicated that as operational pressure increased, there was a decrease in the displacement, volume shrinkage (VS), and plastic zone, alongside an increase in vertical stress and the safety factor (SF). The minimum operation pressure (MOP) range of 28–48 MPa is proposed to adhere to the stability criteria. A novel method for gas storage utilizing the void space within bottom sediments is proposed. The available volume of the cavern using sediment voids (7.43 × 10⁵ m³) is about 1.36 times that of the conventional cavern (5.48 × 10⁵ m³). The use of sediment voids can significantly improve the energy storage capacity of caverns. The research results demonstrated that Jingjie ultra-deep GSSC has good feasibility.</div></div>","PeriodicalId":100578,"journal":{"name":"Geoenergy Science and Engineering","volume":"254 ","pages":"Article 213994"},"PeriodicalIF":0.0,"publicationDate":"2025-05-17","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"144365959","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":"Modified SiO2 nanoparticles for enhanced oil recovery: A comprehensive review and perspectives","authors":"Zhenghao Zhang ,&nbsp;Bo Peng ,&nbsp;Kai Cheng ,&nbsp;Yupeng Zhang ,&nbsp;Jindong Liu ,&nbsp;Xuechao Yang ,&nbsp;Hongfeng Zhang","doi":"10.1016/j.geoen.2025.213973","DOIUrl":"10.1016/j.geoen.2025.213973","url":null,"abstract":"<div><div>Research on traditional surfactants and polymers for enhanced oil recovery (EOR) has reached a bottleneck. SiO₂ nanoparticles, as the most commonly used nanomaterial, exhibit low cost, easy surface modification, and high environmental compatibility. Appropriate modification of these nanoparticles is one of the key strategies for EOR. This review systematically reviews a complete strategy for modifying SiO₂ nanoparticles to improve oil displacement efficiency. In terms of modification approaches, physical modification is straightforward but has limited effectiveness, while chemical modification demonstrates significant effects but requires intricate procedures. The modification mechanisms of surfactants, polymers, surfactant-polymer composite systems, and hydrogels as modification agents for SiO₂ nanoparticles are explored, along with their effects on the nanoparticles. The oil displacement mechanisms of modified SiO₂ nanoparticles in EOR are analyzed, including interfacial tension (IFT) reduction, wettability alteration, emulsion stability enhancement, mobility control, and the synergistic effects of multiple mechanisms. For EOR implementation, recommendations for selecting modification agents are provided by considering the EOR mechanisms of nanoparticles and reservoir conditions. Lastly, the existing challenges in experimental research on modified SiO₂ nanoparticles are reviewed, and further prospects for their application in EOR are explored. This work offers theoretical foundations and technical perspectives on the mechanism enhancement and field deployment of modified nanomaterials for oil displacement.</div></div>","PeriodicalId":100578,"journal":{"name":"Geoenergy Science and Engineering","volume":"253 ","pages":"Article 213973"},"PeriodicalIF":0.0,"publicationDate":"2025-05-16","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"144098718","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":"Viscous crossflow as the mechanism for polymer enhanced oil recovery in viscous oils: Evidence of crossflow between bypassed oil and viscous fingers","authors":"A. Beteta ,&nbsp;K. Sorbie ,&nbsp;A. Skauge ,&nbsp;T. Skauge","doi":"10.1016/j.geoen.2025.213968","DOIUrl":"10.1016/j.geoen.2025.213968","url":null,"abstract":"<div><div>Until recently, screening criteria typically stated that the upper limit of oil viscosity was ∼150 mPa s for successful polymer flood implementation. This was predicated on the understanding that polymer flooding operated via a mechanism of “mobility control” whereby the polymer reduced the mobility ratio between the water and viscous oil, ideally to near unity, thus giving a much more “stable” water-oil displacement process.</div><div>In recent years, there has been a significant number of both laboratory and field observations of effective polymer flooding of heavy oil with viscosities, μ_o ≫150 mPa s. In these cases, the mobility ratio with polymer flooding is still significantly ≫1, yet much higher recovery efficiencies have been observed compared with the waterflood. Sorbie and Skauge (2019) proposed that this greatly improved and unexpected performance was due to a form of viscous crossflow taking place during polymer displacement of the viscous oil. Similar to inter-layer crossflow, the injection of the viscosified water phase into a pre-fingered water displacement results in crossflow at the trailing front of water out of the viscous finger and crossflow of bypassed oil <em>into</em> the viscous finger region at the leading front.</div><div>This paper demonstrates the viscous crossflow mechanism using evidence from a series of laboratory and numerical experiments for heavy oils in the range of 100 to 2000 mPa s under tertiary polymer flooding. First, a number of recent visualised examples of viscous crossflow are presented, then a series of miscible simulations performed to demonstrate viscous crossflow the absence of relative permeability, capillary pressure etc. before a series of immiscible calculations. It is also shown via modification of the wettability of the porous media that capillarity can easily supress viscous fingers at the laboratory scale, and in such cases viscous crossflow cannot take place, since there are no immiscible viscous fingers to crossflow into, and polymer flooding operates through the mechanism of classical “mobility control”.</div></div>","PeriodicalId":100578,"journal":{"name":"Geoenergy Science and Engineering","volume":"253 ","pages":"Article 213968"},"PeriodicalIF":0.0,"publicationDate":"2025-05-15","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"144084490","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":"Sweet spots discrimination in carbonate reservoirs based on weakly supervised learning","authors":"Han Wang ,&nbsp;Zhiwen Xue ,&nbsp;Shengjuan Cai ,&nbsp;Zhijiang Kang ,&nbsp;Hanqing Wang ,&nbsp;Yitian Xiao","doi":"10.1016/j.geoen.2025.213965","DOIUrl":"10.1016/j.geoen.2025.213965","url":null,"abstract":"<div><div>The spatial distribution of karst caves in carbonate reservoirs plays a key role in guiding well placement. However, field production data reveal a high risk of drilling low-production wells even in cave-dense regions, resulting in low hydrocarbon recovery rates. Consequently, the identification of high-production “sweet spot” reservoirs has become a priority in optimizing well placement and enhancing recovery. This study proposes a two-step method for sweet spot identification using weakly supervised learning. Firstly, a multi-input convolutional neural network (CNN) is employed to detect caves from seismic data, including depth migration data, ant tracking, impedance, and structure tensor seismic attributes. The detection results, along with the seismic data, are then input into a second CNN to predict reservoir effectiveness. Since the effective reservoir classification can only be validated through production data from drilled wells, the available training samples are limited. To address this limitation, we define a random path crossing multiple wells and extract corresponding 2D seismic profiles, cave detection labels, and well-controlled classification labels. Notably, classification labels are only available at well locations, with no labels between wells. In the reservoir classification phase, a weakly supervised 2D CNN is trained using an adaptive loss, which evaluates the output cave classification profiles at partially labeled targets. The CNN can generate consistent 3D sweet spot predictions along both inline and crossline sections. Field tests and case studies demonstrate the prediction accuracy of proposed workflow can reach approximately 80 %, providing a practical solution for drilling risks and optimizing hydrocarbon recovery in carbonate reservoirs.</div></div>","PeriodicalId":100578,"journal":{"name":"Geoenergy Science and Engineering","volume":"252 ","pages":"Article 213965"},"PeriodicalIF":0.0,"publicationDate":"2025-05-13","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"143949110","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":"Production rate forecasting using pressure and saturation estimates near the wellbore","authors":"D. Voloskov ,&nbsp;E. Gladchenko ,&nbsp;D. Akhmetov ,&nbsp;E. Illarionov ,&nbsp;K. Pechko ,&nbsp;A. Afanasev ,&nbsp;M. Simonov ,&nbsp;D. Orlov ,&nbsp;D. Koroteev","doi":"10.1016/j.geoen.2025.213946","DOIUrl":"10.1016/j.geoen.2025.213946","url":null,"abstract":"<div><div>Production flow rate forecasting is crucial for effective reservoir management decisions. Usually, this forecasting relies on either full-scale reservoir models, which demand significant computational resources, or highly simplified surrogate models like the Capacitance–Resistance Model (CRM). While CRM offers computational efficiency, it faces considerable challenges when applied to multilayer reservoirs or scenarios with varying fluid saturations. We present a novel method for flow rate forecasting, occupying an intermediate position between these two approaches. The model consists of several components: separate machine learning models are used to predict pressure and fluid saturation in each grid cell perforated by the well. The predicted pressure and saturation values are then used to estimate well production rates. This workflow preserves the physical interpretability: outputs of intermediate models represent primary dynamic variables and the weighting coefficients of the flow rate estimation model can be interpreted as connection factors of the grid blocks. At the same time, it overcomes some of the limitations of both full-scale reservoir model and CRM-like surrogate models. Unlike CRM, each well is considered as a collection of cells for better representation of structural heterogeneity. Additionally, by considering fluid saturation as a dynamic property, it can manage problems with varying fluid phase composition. The focus only on values near the wellbore facilitates rapid forecasting compared to full-scale modeling. We test the proposed approach using two reservoir models: a simplistic synthetic reservoir and a model of a real-world reservoir, and compare it with the results obtained using a commercial reservoir simulator and CRM. We observe a better accuracy against the CRM and a reasonable approximation of full-scale simulation results.</div></div>","PeriodicalId":100578,"journal":{"name":"Geoenergy Science and Engineering","volume":"253 ","pages":"Article 213946"},"PeriodicalIF":0.0,"publicationDate":"2025-05-13","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"144072272","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":"Discovery of a surge in alteration depth of wellbore cement exposed to high concentration CO2 from 28 days to 56 days","authors":"Manguang Gan ,&nbsp;Liwei Zhang ,&nbsp;Yan Wang ,&nbsp;Theogene Hakuzweyezu ,&nbsp;Qiang Sun ,&nbsp;Qinglong Qin","doi":"10.1016/j.geoen.2025.213970","DOIUrl":"10.1016/j.geoen.2025.213970","url":null,"abstract":"<div><div>Efficient and secure storage of CO₂ in deep subsurface formations is currently an essential strategy for mitigating atmospheric CO₂ emissions. To guarantee the long-term integrity of the wellbore system, it is crucial to prevent the leakage of injected CO₂ through the wellbore. This study investigates the structural evolution of wellbore cement in static reaction with CO₂-saturated brine for 7, 14, 28, and 56 days under the conditions that mimic geologic CO₂ storage. Micro-CT was used to scan the samples both before and after the reaction. The threshold segmentation method was employed to distinguish the heavily-altered and less-altered regions of the specimens. The results indicated that the carbonation and alteration depths of the cement increased with the extension of reaction time. The alteration depth gradually increased during the initial 28 days, followed by a surge from 0.86 mm (28 days) to 3.21 mm (56 days). The SEM results indicate that the pores within the carbonate layer became larger and more pores appeared after 28 days of reaction, compared with those observed after 7 days of reaction. The primary cause of the sudden alteration depth increase after 28 days was that the carbonate layer had been defected, and the reaction fluid was able to penetrate the carbonate layer and react with the cement interior after 28 days of reaction, thereby expanding the range of the internal dissolved layer. Therefore, the carbonate layer may fail to protect the cement from CO₂ attack if the carbonate layer has defects. The prediction results based on the best-fit curve show that the carbonation front and alteration front of the wellbore cement reach 14.34 and 17.38 mm according to Fick's second law, while the Elovich equation estimates them to be 1.23 and 2.56 mm after 30 years of CO₂ attack. Those results are higher than the values reported in previous studies. The compressive strength of the wellbore cement is observed to decrease after carbonation, with a reduction of 13.7 % and 22.2 % compared to the initial compressive strength after reaction for 7 and 14 days, and has a very small decrease from 14 days to 56 days. In summary, this study reveals the possibility of a gradual loss of integrity of the carbonate shell in the exterior region of the cement exposed to CO₂, which increases the risk of wellbore cement damage.</div></div>","PeriodicalId":100578,"journal":{"name":"Geoenergy Science and Engineering","volume":"253 ","pages":"Article 213970"},"PeriodicalIF":0.0,"publicationDate":"2025-05-12","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"144070417","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":"Research on the bidirectional transmission system of wireless energy and signals in the steering system of orienter in coiled tubing drilling","authors":"Meng Li ,&nbsp;Mengxia Wu ,&nbsp;Kanhua Su ,&nbsp;Yachun Yang ,&nbsp;Qiang Wang ,&nbsp;Zhongli Yang","doi":"10.1016/j.geoen.2025.213966","DOIUrl":"10.1016/j.geoen.2025.213966","url":null,"abstract":"<div><div>Steering system of orienter in coiled tubing drilling (SSCTD) is currently one of the key devices in downhole exploration to improve drilling speed and enhance control accuracy. To replace traditional wired cable connections and enable bidirectional wireless transmission of both power and signals between a rotating shaft and a stationary housing, a method for simultaneous transmission of power and signals based on the principle of magnetic inductive coupling was proposed. Based on the power transmission channel, signal transceiver circuits are integrated to enable the simultaneous transmission of power and signals through a shared physical medium, thereby reducing wiring costs. By analyzing the advantages of the inductor–capacitor–inductor (<em>LCL</em>) compensation topology in harmonic suppression and system stability enhancement, a bidirectional <em>LCL</em> resonant compensation model for integrated power and signal transmission was developed on the Simulink platform. A combined active and reactive power (P&amp;Q) control strategy is implemented. By measuring the active power (P) and reactive power (Q) at the resonant network, the power flow on both sides can be regulated and synchronized without the need for dedicated communication interfaces for power transfer control. Simulation and experimental results demonstrate that the power and signal co-transmission system achieves a transmission efficiency of 95.16 %. The introduction of the signal channel results in a negligible impact on power transfer, with losses below 3W. The system exhibits excellent dynamic response and power stability.</div></div>","PeriodicalId":100578,"journal":{"name":"Geoenergy Science and Engineering","volume":"253 ","pages":"Article 213966"},"PeriodicalIF":0.0,"publicationDate":"2025-05-12","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"144068273","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 a solid-liquid composite CO2 adsorbent using rice husk from waste distiller's grains","authors":"Renjing Ji ,&nbsp;Xiaorong Yu ,&nbsp;Jingyi Cui ,&nbsp;Xuemei Wu ,&nbsp;Huan Yang ,&nbsp;Gaoshen Su","doi":"10.1016/j.geoen.2025.213967","DOIUrl":"10.1016/j.geoen.2025.213967","url":null,"abstract":"<div><div>As a solid waste in Baijiu production, rice husk of distiller's grains is considered as a low-cost biomass resource. To promote the resource utilization of distiller's grains, the hydrophobic modified rice husk biochar (DRHC) was prepared from solid waste of distiller's grains as precursor. DRHC was doped into hydrophobic silica as a solid phase material and an aqueous solution of 50 wt% K₂CO₃ was chosen as a liquid phase material. The solid-liquid composite adsorbents, prepared using a high-speed stirring method, exhibited a core-shell structure with a particle size of 52.98 μm. The adsorption capacity of the solid-liquid composite adsorbent increased as the addition of DRHC in the solid phase shell rose. The adsorption capacity of the composite adsorbent prepared with pure hydrophobic SiO₂ was 1.49 mmol/g, while the composite adsorbent had a capacity of up to 5.2 mmol/g when the addition of DRHC in the shell was 20 wt%. After 10 absorption-desorption cycles, the adsorption capacity of the composite adsorbent decreased by 13.8 %. The solid-liquid composite adsorbent could achieve the synergistic adsorption of the shell and the core. In this study, liquid absorbent and solid adsorbent were combined in a simple way, and the composite adsorbent effectively improved the adsorption capacity of CO₂, and also provided a new idea for the high-value utilization of distiller's grains.</div></div>","PeriodicalId":100578,"journal":{"name":"Geoenergy Science and Engineering","volume":"252 ","pages":"Article 213967"},"PeriodicalIF":0.0,"publicationDate":"2025-05-12","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"143943307","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 hybrid model of formation pore pressure prediction based on geological sequence matching","authors":"Chengkai Weng ,&nbsp;Jun Li ,&nbsp;Hongwei Yang ,&nbsp;Zhenyu Long ,&nbsp;Geng Zhang ,&nbsp;Biao Wang ,&nbsp;Yuxuan Zhao","doi":"10.1016/j.geoen.2025.213972","DOIUrl":"10.1016/j.geoen.2025.213972","url":null,"abstract":"<div><div>Formation pore pressure (Pp) is vital to every stage of petroleum exploration and development. However, current prediction methods often overlook geological sequence variations and rely heavily on direct depth alignment from offset wells, resulting in substantial discrepancies between predicted and actual Pp when measured data are scarce. To address these limitations, a novel and interpretable pre-drilling Pp prediction strategy was developed. First, Geological Sequence Matching (GSM) was introduced to align historical well-logging data with the pre-drilling well's stratification, thereby compensating for stratigraphic depth-thickness discrepancies induced by geological evolution—an essential factor systematically neglected in existing approaches. Second, a primary wave velocity (Vp) Error Compensation Hybrid (VECH) model was proposed, which uniquely combines a Vp-based physical model as the primary framework while employing machine learning specifically to correct systematic errors. Unlike purely machine-learning-based or traditional physical methods, VECH maintains robust physical interpretability while effectively incorporating real-world data corrections. By leveraging Vp to calculate effective stress, this approach eliminates the need for post-drilling corrected Pp in model training, overcoming a critical drawback of conventional workflows. Examples from the Bohai Oilfield show that, compared to traditional methods, the proposed hybrid model reduces the mean absolute error in Pp prediction by two-thirds. Furthermore, VECH model interpretation using decision-tree visualization and sensitivity analysis is performed to illustrate the model operation process and the influence of various features on the prediction outcomes. These findings demonstrate the effectiveness of the hybrid model in predicting Pp suggests potential applications in forecasting other geophysical parameters such as density, porosity, and permeability.</div></div>","PeriodicalId":100578,"journal":{"name":"Geoenergy Science and Engineering","volume":"252 ","pages":"Article 213972"},"PeriodicalIF":0.0,"publicationDate":"2025-05-12","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"143949118","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":"Microscopic effects of long-term water injection on reservoir pore structure","authors":"Xingyu Wang ,&nbsp;Liangjie Mao ,&nbsp;Xiangwei Kong","doi":"10.1016/j.geoen.2025.213952","DOIUrl":"10.1016/j.geoen.2025.213952","url":null,"abstract":"<div><div>Exploring the distribution patterns of residual oil in reservoirs constitutes the core and major challenge during the high water-cut development stages of oilfields with the aim of enhancing oil recovery rates. The distribution of residual oil in reservoirs is intimately associated with the seepage process of oil and water within the reservoir, and the seepage performance of the reservoir is contingent upon the microscopic pore structure characteristics. Long-term water injection development will induce alterations in the physical properties of the reservoir, such as wetting properties, porosity, pore diameter, and permeability. Hence, it holds significant importance to clarify the pore structure and its changing characteristics of the reservoir in water injection development for the improvement of oil recovery rates. The research was carried out on the S reservoir of L oilfield, concentrating on the microscopic alterations in the pore structure of the reservoir during water injection. A laboratory physical simulation experimental procedure for oil reservoir water injection and oil displacement was constructed, explicitly elucidating the effects and influences of water flooding on the reservoir's permeability, porosity, grain size, and electrical resistivity. Microscopic analysis methods were employed to dissect the variation characteristics of the pore structure, clay minerals, and grain occurrence of the reservoir rock, thereby delving into the mechanism through which water flooding causes changes in the reservoir's physical properties. The research findings indicate that in the initial water injection period and the low-to-middle water saturation phase, the micro particle activity within the reservoir is intense, and the permeability undergoes significant alterations. During the middle-to-high water saturation stage, the permeability tends to stabilize. With the escalation of the water-flooding multiples, the permeability of the high-permeability reservoir ascends, while that of the medium-to-low-permeability reservoir descends. The scouring effect of water injection on the reservoir exhibits heterogeneity, which is influenced by the original heterogeneous features of the reservoir, the mineral composition of rocks, and the pore structure characteristics. The electrical characteristic parameters do not present significant variations before and after water injection. This paper offers theoretical guidance for enhancing the water flooding efficiency of high water-saturation oil reservoirs and precisely predicting the distribution of residual oil.</div></div>","PeriodicalId":100578,"journal":{"name":"Geoenergy Science and Engineering","volume":"253 ","pages":"Article 213952"},"PeriodicalIF":0.0,"publicationDate":"2025-05-09","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"144068272","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}