Geoenergy Science and Engineering最新文献

{"title":"Investigation on the impact of CO2-Induced precipitation on microscopic pore structure of low-permeable reservoirs","authors":"Zhichao Zhang ,&nbsp;Mingxing Bai ,&nbsp;Long Xu ,&nbsp;Siyu Du ,&nbsp;Junzhang Shan ,&nbsp;Ming Gao","doi":"10.1016/j.geoen.2024.213441","DOIUrl":"10.1016/j.geoen.2024.213441","url":null,"abstract":"<div><div>CO₂ injection into reservoirs might induce organic or inorganic precipitation in microscopic pores, and some of the pores are blocked by the precipitates, resulting in a decrease in the connectivity of pores and affecting oil recovery. In this paper, a set of experiments on CO₂ displacement and CO₂-water-oil-rock interaction are conducted to study the microscopic mechanisms of reservoir damage. In-situ Nuclear Magnetic Resonance (NMR) technology is applied to conduct the microscopic analysis of CO₂-EOR and reservoir damage at real reservoir conditions. The results reveal that the particle size and the amount of inorganic precipitates formed in the formation water will increase with the rise of CO₂ injection pressure, and the inorganic precipitates primarily consist of siderite and kaolinite. The change of NMR T2 spectra of the core samples reveals that the inorganic precipitates primarily block the small pores less than 0.89 μm. However, as a result of stronger mineral dissolution and solute transport, the pore volume of the large pores (greater than 0.89 μm) increases after the CO₂-water-rock reaction. Ultimately, this interaction results in a 5.4% increment in pore volume. In addition, the displacement efficiency of water-saturated cores is improved after the first CO₂ displacement, which indicates that CO₂-water-rock interaction can effectively improve the seepage properties of reservoirs. Nevertheless, the reservoir damage caused by asphaltene precipitation during CO₂ flooding is more significant. The asphaltene precipitation percentage in formation oil increases with the rise of CO₂ injection pressure, reservoir temperature, and asphaltene content in virgin oil. CO₂-induced asphaltene precipitation causes more severe blockage on small pores in comparison with large pores. After 2 h of CO₂ injection to the oil-saturated core, permeability and oil recovery caused by CO₂-induced precipitation decreased by 17.6% and 11.4%, respectively.</div></div>","PeriodicalId":100578,"journal":{"name":"Geoenergy Science and Engineering","volume":"244 ","pages":"Article 213441"},"PeriodicalIF":0.0,"publicationDate":"2024-10-28","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"142561145","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 study on rock drilling vibration of PDC bit in interbedded formations","authors":"Jiawei Zhang ,&nbsp;Meng Cui ,&nbsp;Qing Wang ,&nbsp;Haitao Ren ,&nbsp;Guodong Ji ,&nbsp;Fangyuan Shao ,&nbsp;Lubin Zhuo ,&nbsp;Hong Li ,&nbsp;Jinping Yu","doi":"10.1016/j.geoen.2024.213452","DOIUrl":"10.1016/j.geoen.2024.213452","url":null,"abstract":"<div><div>Mastering the vibration characteristics of PDC bit, especially in interbedded formations, can help to explore reasonable bit failure control measures, achieve bit optimization and drilling optimization. This work used single rocks to construct different types of vertical and horizontal interbedded rocks with different interbedded properties, the experimental study obtained the bit vibration characteristics under single rock, sudden-changed rock, and alternating rock conditions. The vibration acceleration of a single rock is consistent with the rock strength. The acceleration increases with the increase of weight-on-bit and rotary speed, the influence of weight-on-bit is greater than that of rotary speed. The maximum amplitude of accelerations always occurs in the low frequency range of 0∼300 Hz, the difference between rocks is mainly reflected in the high frequency range greater than 400 Hz. When the drill bit suddenly crosses from soft rock to hard rock in the vertical interbedded formation, the acceleration increases rapidly, causing direct impact. When the drill bit suddenly crosses from hard rock to soft rock, the impact and acceleration attenuates slowly, which could cause fatigue damage to the drill bit and induce high-frequency vibration. The rapid and significant change in depth-of-cut is the fundamental reason for the impact generated when the bit crosses through the interlayer, and both the maximum and minimum depth-of-cut occur in the transition region. PDC bit alternately encountered soft and hard rocks in the horizontal interbedded formation, causing intensified vibration. The acceleration is consistent with rock difference. The influence of weight-on-bit on acceleration increases with the increase of rotary speed for horizontal interbedded formation with small rock differences. However, with the increase of weight-on-bit, the influence trend and degree of rotary speed on acceleration remain basically unchanged. The increase in weight-on-bit/rotary speed weakens the effect of rotary speed/weight-on-bit on acceleration in horizontal interbedded formations with significant rock differences. The research results illustrate that the reason for the abnormal bit failure in interbedded formations is the frequent changes in depth of cut caused by rock mutation and alternation, and the resulting impact. This provides theoretical guidance for the implementation of effective measures such as reasonable cutter arrangement design, pertinent setting of auxiliary structures, and appropriate adjustment of drilling parameters.</div></div>","PeriodicalId":100578,"journal":{"name":"Geoenergy Science and Engineering","volume":"244 ","pages":"Article 213452"},"PeriodicalIF":0.0,"publicationDate":"2024-10-28","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"142573164","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":"Formulizing relationships between producing area of fracture-controlled unit and productivity of segmented multi-cluster fractured well by delineating water saturation limit","authors":"Jia Deng ,&nbsp;Hongqing Song","doi":"10.1016/j.geoen.2024.213448","DOIUrl":"10.1016/j.geoen.2024.213448","url":null,"abstract":"<div><div>Predicting the producing area of fracture-controlled unit created by hydraulic fracturing is crucial to fracturing evaluation, estimation of remaining reserves and formulation of development plan. Under the background of segmented multi-cluster fractured horizontal wells intercepted by line-shaped fractures, this study establishes a transient gas-water two-phase flow model to solve the analytical solutions of gas-water productivity, formation pressure and water saturation in water-bearing shale gas reservoirs, well matching with the field production data and simulation results. Subsequently, by delineating water saturation limit in an analytical nephogram, the producing area of fracture-controlled unit can be determined and calculated. The key contributions to producing areas and gas-water productivities at early, middle and late stages are dynamically identified via a sensitivity analysis, thus demonstrating that both fracture length and initial matrix water saturation are key factors contributing to the producing area and productivity. Meanwhile, the producing area shows a positive relation with matrix permeability, cluster spacing and fracture length whereas has a negative relation with initial matrix water saturation. Furthermore, their relationship between producing area and productivity is formulized to show an approximately linear characteristic. Thus, based on field productivities at different production times, their producing areas of fracture-controlled unit can be estimated to evaluate the potential of remaining reserves. This innovative approach with low requirements on the gas-water production dataset is convenient to yield a rapid prediction of dynamic reserves of gas reservoirs, thereby contributing to high-efficient development of unconventional gas resources.</div></div>","PeriodicalId":100578,"journal":{"name":"Geoenergy Science and Engineering","volume":"244 ","pages":"Article 213448"},"PeriodicalIF":0.0,"publicationDate":"2024-10-28","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"142573055","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":"Comparative analysis of 3D reservoir geologic modeling: A comprehensive review and perspectives","authors":"Lingfeng Zhao ,&nbsp;Chenlin Hu ,&nbsp;Jonathan Atuquaye Quaye ,&nbsp;Ning Lu ,&nbsp;Rufei Peng ,&nbsp;Lirong Zhu","doi":"10.1016/j.geoen.2024.213440","DOIUrl":"10.1016/j.geoen.2024.213440","url":null,"abstract":"<div><div>The emergence and application of geological models have contributed to new assessment schemes for oil and gas reservoir development. The model simulates stratigraphic conditions and is used to implement and enhance the development scheme. This approach enables the simultaneous evaluation of multiple schemes, thereby increasing the resource utilization rates. Therefore, modeling is indispensable for studying the formation and development of hydrocarbon reservoirs. This study synthesized and analyzed diverse modeling methods, improvements, method combinations, and actual cases to propose an innovative modeling workflow. The proposed modeling workflow aimed to enhance the accuracy of geological models to guide subsequent reservoir development and utilization effectively. This workflow encompassed data processing, tectonic conditions (boundaries, cracks, faults, and stratigraphy), attribute conditions, and dynamic simulations. Additionally, the modeling methodology for different lithologies of the main reservoir was refined to accurately characterize various formations. This workflow provided recommendations for the current modeling of carbon dioxide (CO₂) sequestration, addressing subsurface sequestration and the impact of CO₂ sequestration on enhanced recovery in oil and gas reservoirs. The future development of geological modeling proposed an intelligent modeling theory based on automated and intelligent modeling technology that was further enhanced. Moreover, the geological model was envisioned to serve as a key component for monitoring smart oilfield operations, facilitating the full-scale intelligent management of such fields. This review could present new modeling workflows and two future model development concepts, with the objective of assisting scholars in their research endeavors and offering directions for future studies.</div></div>","PeriodicalId":100578,"journal":{"name":"Geoenergy Science and Engineering","volume":"244 ","pages":"Article 213440"},"PeriodicalIF":0.0,"publicationDate":"2024-10-28","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"142539387","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 synthesis of temperature-responsive Janus nanoparticles with high salt tolerant for enhanced heavy oil recovery","authors":"Haotian Gao ,&nbsp;Jianwen Hu ,&nbsp;Mingshuo Chi ,&nbsp;Junjie Fan ,&nbsp;Tianhao Zhang ,&nbsp;Wenqing Xie ,&nbsp;Ekemini Ituen ,&nbsp;Shuangqing Sun ,&nbsp;Chunling Li ,&nbsp;Songqing Hu","doi":"10.1016/j.geoen.2024.213433","DOIUrl":"10.1016/j.geoen.2024.213433","url":null,"abstract":"<div><div>Enhancing the recovery efficiency of heavy oil reservoirs remains one of the foremost challenges confronting the petroleum industry. Nanoparticles have garnered considerable attention as potential oil displacement agents, drawing numerous researchers to the field. In this study, temperature-responsive SiO₂ Janus nanoparticles (JNs) were successfully prepared through the Pickering emulsion template method and atom transfer radical polymerization (ATRP) reactions. Experiments on the interfacial tension (IFT) of oil-water systems indicate that JNs exhibit good dynamic interfacial activity. Furthermore, the JNs exhibit remarkable emulsification capabilities for heavy oil, facilitating the formation of stable emulsions. Notably, the modified nanoparticles exhibit a degree of salt resistance, even up to a mineralization of 1.55 × 10⁴ mg/L. Additionally, their temperature-responsive properties enable their utilization for high-temperature emulsification and low-temperature demulsification, making them well-suited for oilfield field operations. To visualize and simulate the underground oil displacement process, a microscopic displacement visualization experimental apparatus was employed. Notably, the addition of just 0.03 wt% of Janus nanoparticles resulted in a significant enhancement of the recovery rate by 16.49%. The research findings suggest that the JNs developed in this study exhibit promising application prospects and commercial value in terms of enhancing oil recovery efficiency.</div></div>","PeriodicalId":100578,"journal":{"name":"Geoenergy Science and Engineering","volume":"244 ","pages":"Article 213433"},"PeriodicalIF":0.0,"publicationDate":"2024-10-28","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"142539428","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 comparison study of pore structure and permeability of sandstone by BSE-SE images","authors":"Hongyang Ni ,&nbsp;Hai Pu ,&nbsp;Jiangfeng Liu ,&nbsp;Junce Xu ,&nbsp;Jiale Guo","doi":"10.1016/j.geoen.2024.213435","DOIUrl":"10.1016/j.geoen.2024.213435","url":null,"abstract":"<div><div>The pore structure and permeability of geotechnical materials are critical parameters that guide underground engineering. With advancements in digital imaging technology, scanning electron microscopy (SEM) has emerged as a vital tool for examining the pore structure and permeability of these materials. SEM operates in two primary modes: backscattered electron imaging (BSE) and secondary electron imaging (SE), each of which emphasizes different aspects of the material's structure. However, few studies have been conducted to elucidate the influence of these two modes on the quantification of geotechnical structural characteristics. This study undertakes a more comprehensive quantitative analysis of the structure and permeability of sandstones by juxtaposing the two modes. The findings indicate that the BSE mode excels in analyzing the structure and composition, whereas the SE mode highlights the surface morphology. In terms of image segmentation, BSE mode images are more conducive to effective segmentation. Although SE images permit viable segmentation when preprocessed, they tend to represent a greater number of discrete tiny pores. Furthermore, there exists a discernible correlation between pore size and shape, wherein larger pores exhibit heightened roughness and deviate more from sphericity. Notably, these larger pores predominantly contribute to the material's permeability. Given that the BSE mode more readily captures continuous pore structures, the permeability values derived from BSE images are significantly higher than those obtained from SE images. These findings hold profound implications for enhancing our comprehension of geotechnical materials' pore structure and permeability, thereby informing the strategic use of BSE and SE modes in related studies.</div></div>","PeriodicalId":100578,"journal":{"name":"Geoenergy Science and Engineering","volume":"244 ","pages":"Article 213435"},"PeriodicalIF":0.0,"publicationDate":"2024-10-28","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"142539386","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":"Thermal recovery of heavy oil reservoirs: Modeling of flow and heat transfer characteristics of superheated steam in full-length concentric dual-tubing wells","authors":"Peng Li ,&nbsp;Xiangyu Wang ,&nbsp;Yanyu Zhang","doi":"10.1016/j.geoen.2024.213432","DOIUrl":"10.1016/j.geoen.2024.213432","url":null,"abstract":"<div><div>Accurately predicting the flow and heat transfer characteristics of superheated steam (SHS) in the wellbore is essential for efficiently developing heavy oil reservoirs. However, few studies have examined SHS flow in full-length concentric dual-tubing wells (CDTWs). In this paper, firstly, based on fluid dynamics and thermodynamics theories, a mathematical model for SHS flow in vertical and horizontal wellbores is proposed. Then, this model is solved using a finite difference method for spatial discretization and an iterative technique. Finally, model verification, type curve analysis, and sensitivity analysis are conducted sequentially. The results indicate that SHS temperature and pressure are independent variables, and the effect of friction energy on temperature is greater than its impact on pressure. The injection rate has a critical value, and the critical injection rates of the main controlling factors affecting the pressure drop and temperature drop of SHS in the vertical tubing are different. When the injection rate is below the critical value, the gravitational force of the SHS helps maintain high enthalpy. The SHS should be transported to the well bottom as quickly as possible. To enhance the uniform heating effect of the reservoir and improve heat utilization efficiency, a relatively small injection rate, high injection pressure, and low injection temperature are recommended. The uniformity of SHS pressure and temperature distribution in the horizontal annulus positively correlates with the uniformity of the reservoir's heat absorption rate. Achieving more uniform SHS pressure and temperature profiles in the horizontal annulus benefits the uniform heating of the reservoir.</div></div>","PeriodicalId":100578,"journal":{"name":"Geoenergy Science and Engineering","volume":"244 ","pages":"Article 213432"},"PeriodicalIF":0.0,"publicationDate":"2024-10-28","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"142552234","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":"Study on rock-breaking mechanism of the vertical wheel PDC bits","authors":"Yan Yang ,&nbsp;Yingxin Yang ,&nbsp;Dongdong Song ,&nbsp;Haitao Ren ,&nbsp;Shunzuo Qiu ,&nbsp;Xiaoyong Xie ,&nbsp;Zequan Huang","doi":"10.1016/j.geoen.2024.213428","DOIUrl":"10.1016/j.geoen.2024.213428","url":null,"abstract":"<div><div>To address the issues of slow drilling speed and poor operational stability of PDC bits in hard and heterogeneous formations, a VW-PDC bit with an integrated axle structure is proposed. A variable parameter experimental bit device was developed, and indoor rock drilling experiments with varying parameters were conducted. The performance of the VW-PDC bit and the C-PDC bit in drilling Jiang'an sandstone, Maokou limestone, and heterogeneous rocks were compared and analyzed, along with the influence of key structural parameters of the VW on bit performance. The study results indicate that the ROP and torque of the VW-PDC bit are highly sensitive to changes in the relative protrusion height. The VW PDC bit achieves an ROP comparable to the C-PDC bit but with a lower torque response and smaller three-directional acceleration. When drilling in soft rock (Jiang'an sandstone), the VW PDC bit's ROP is similar to that of the C-PDC bit, with the equivalent torque reduced by 1%–34.35% and the three-directional acceleration reduced by 15%–70%. In harder rock formations, while the VW structure slightly reduces the ROP, it significantly lowers the torque and stabilizes the torque response. When drilling rocks with interbedded layers, the VW-PDC bit exhibits excellent stability, with lower torque fluctuation and smaller three-directional acceleration. The VW cutting structure provides cushioning protection and auxiliary cutting for the PDC teeth, enhancing rock-breaking efficiency and overall bit stability. The research findings offer theoretical support and technical means for the design and application of VW-PDC bit in gravelly and interbedded heterogeneous rock formations.</div></div>","PeriodicalId":100578,"journal":{"name":"Geoenergy Science and Engineering","volume":"244 ","pages":"Article 213428"},"PeriodicalIF":0.0,"publicationDate":"2024-10-28","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"142539429","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":"Oil recovery and cooling for underground salt cavern oil storage: Insights from coupled flow and thermal model","authors":"Tongtao Wang ,&nbsp;Youqiang Liao ,&nbsp;Tao He ,&nbsp;Dongzhou Xie ,&nbsp;Zhongxin Ren ,&nbsp;Ken Qin ,&nbsp;Chaoyang Zhang","doi":"10.1016/j.geoen.2024.213456","DOIUrl":"10.1016/j.geoen.2024.213456","url":null,"abstract":"<div><div>Petroleum reserve in salt caverns is paying more attention to oil cooling to prevent dissolved gas release from heated crude oil. This work introduced a method for oil recovery in conjunction with cooling, along with a matching flow and heat transfer model taking changes in crude oil thermophysical parameters into consideration. An average error of 3.43% was observed between the model results and filed monitoring data. It was found that after being cooled by the heat exchanger, the temperature of extracted crude oil drops from 39.5 °C to 26.8 °C, demonstrating the effectiveness of this approach for oil cooling. Sensitivity analysis indicates that the season is the primary determining factor for the cooling efficacy of crude oil. Even worse, cooling will be useless when the ambient temperature exceeds 35 °C. However, increasing brine temperature will reduce the surface pumping pressure from 7.60 MPa to 5.17 MPa, with a decrease of up to 31.97%. A special focus was given to the brine injection rate, which seemed to have less impact on the cooling efficiency but became more significant in the pressure profile. In addition to providing further insights into the flow and thermal performance of strategic petroleum reserves in the salt cavern, this study could also be a powerful tool for determining the best process parameters to ensure the delivery temperature of crude oil and the stability of the salt cavern.</div></div>","PeriodicalId":100578,"journal":{"name":"Geoenergy Science and Engineering","volume":"244 ","pages":"Article 213456"},"PeriodicalIF":0.0,"publicationDate":"2024-10-28","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"142539427","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 mechanism of controlling water and stabilizing production in heavy oil reservoirs with edge-bottom water","authors":"Lei Tao ,&nbsp;Zhihao Yang ,&nbsp;Wenyang Shi ,&nbsp;Jiajia Bai ,&nbsp;Zhengxiao Xu ,&nbsp;Qingjie Zhu ,&nbsp;Lili Cao ,&nbsp;Yong Song","doi":"10.1016/j.geoen.2024.213447","DOIUrl":"10.1016/j.geoen.2024.213447","url":null,"abstract":"<div><div>The development of edge-bottom water heavy oil reservoirs typically involves short water-free production period and a rapid increase in water cut, leading to generally low oil recovery factors. Combining the advantages of foam and viscosity reducers for composite development can effectively address the challenges in edge-bottom water reservoirs; however, the mechanism of action remains unclear. In this study, the concentrations of foaming agent and viscosity reducer were initially determined using a foam evaluator and an Anton Paar rheometer. Subsequently, a 2D large flat plate model was employed to conduct a composite group production experiment after water flooding, and then the change in oil saturation during flooding was analyzed by measuring electrical resistance. Finally, the dynamic curves of flooding were compared to analyze the mechanism of water control and oil stabilization (WCOS). The results indicate that the 2D large flat plate model and the method of inverting saturation field maps can effectively simulate the oil-water flow behavior during the composite flooding process after water flooding. The synergistic mechanism of N₂ foam controlling bottom water coning and CO₂ enhanced viscosity reducer to reduce viscosity in deep areas was revealed, increasing the overall recovery factor by 10.3% compared to water flooding. The mechanism of the combined oil recovery is clarified, which providing a reference for formulating WCOS plans following water flooding.</div></div>","PeriodicalId":100578,"journal":{"name":"Geoenergy Science and Engineering","volume":"244 ","pages":"Article 213447"},"PeriodicalIF":0.0,"publicationDate":"2024-10-28","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"142660020","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}