Geoenergy Science and Engineering最新文献

{"title":"Non-crosslinked multiphase hybrid fracturing fluid with high temperature resistance of 300 °C","authors":"Depei Xu ,&nbsp;Zhongcong Zhao ,&nbsp;Mingjia Hu ,&nbsp;Huaqiang Shi ,&nbsp;Guofeng Dong ,&nbsp;Xiaohui Sun ,&nbsp;Qiuyu Chen ,&nbsp;Yanxin Hou ,&nbsp;Xuge Zhou","doi":"10.1016/j.geoen.2025.214009","DOIUrl":"10.1016/j.geoen.2025.214009","url":null,"abstract":"<div><div>The introduction of nanomaterials usually enhances the stability and temperature resistance of materials, but whether the introduction of nanomaterials in polymer fracturing fluids will significantly enhance their temperature resistance needs to be investigated urgently. The objective of this study is to form a crosslinker-free fracturing fluid system by multiphase hybridization of modified montmorillonite with polymers, and to discuss its advantages over ordinary polymer fracturing fluids in order to achieve a breakthrough of polymer fracturing fluids in terms of temperature resistance. The successful modification of the montmorillonite and the successful synthesis of the temperature-resistant polymer were demonstrated by FT-IR detection. The microdistribution state and microstructure of the fracturing fluid were analyzed by combining SEM and TEM tests, and the mode and mechanism of action of the montmorillonite and the polymer were demonstrated. In other words, the montmorillonite is dispersed in the polymer in three structures, filling, intercalation, and lamellar peeling, to form a heterogeneous effect, which gives the fracturing fluid more excellent stability performance. At the same time, the thermogravimetric analysis of the multiphase hybridized fracturing fluid and the comparison of the experimental results of the unhybridized fracturing fluid clarify and confirm the temperature-resistant effect and the temperature-resistant mechanism of the multiphase hybridized fracturing fluid. After the performance evaluation, it is concluded that the multiphase hybridized fracturing fluid has excellent temperature and shear resistance, sand-carrying and gel-breaking performance. Temperature resistance for over 30 min after reaching the temperature of 300 °C, and the ambient temperature sand sedimentation rate was lower than 10 % for 120 min. The multiphase heterogeneous fracturing fluid can be completely broken within 5 h after adding a gel-breaking agent. Compared with the conventional modified and synthesised polymer fracturing fluids, the multiphase hybridized fracturing fluids studied in this paper have significantly improved the temperature resistance through nanoorganic multiphase hybridization, and the operation process is simple to realize the resistance to 300 °C ultrahigh temperature. The performance indexes meet the requirements of the industry and show great potential for application in fracturing and reforming of reservoirs in ultra-high temperature and 10,000-m deep wells.</div></div>","PeriodicalId":100578,"journal":{"name":"Geoenergy Science and Engineering","volume":"253 ","pages":"Article 214009"},"PeriodicalIF":0.0,"publicationDate":"2025-05-28","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"144166392","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 the impact of H2S and H2SO4 in CO2 on five different sealant compositions under conditions relevant for geological CO2-storage","authors":"Reinier van Noort ,&nbsp;Gaute Svenningsen ,&nbsp;Kai Li","doi":"10.1016/j.geoen.2025.214005","DOIUrl":"10.1016/j.geoen.2025.214005","url":null,"abstract":"<div><div>The integrity of well sealants is a key challenge to secure geological storage of CO₂. While it has been well-established through experimental research that the exposure of such sealants to CO₂-bearing fluids can lead to carbonation, and potentially degradation during prolonged exposure or flow, the impact of impurities present in injected CO₂ has not received much consideration.</div><div>This paper reports exposure of five different sealants to simulated well conditions with supercritical CO₂ containing H₂S or H₂SO₄ as impurities. Three of these sealants are based on Portland Cement, while the other two are based on Calcium Aluminate Cement, and a rock-based geopolymer specifically developed for Geological CO₂ Storage (GCS). The impact of the impurities on these sealants was assessed through scanning electron microscopy with energy-dispersive X-ray spectroscopy, computed tomography scanning, and fluid chemical analysis, and compared to previous research where the same five sealants were exposed to clean CO₂ under otherwise identical conditions.</div><div>The results show that during exposure to CO₂-saturated water, the presence of H₂S mostly resulted in enhanced sealant alteration depths, and reduced carbonate precipitation. During exposure to wet supercritical CO₂, the presence of H₂S or H₂SO₄ resulted in reduced carbonate precipitation, and enhanced alteration depths in some (H₂S) or all (H₂SO₄) sealants. Additionally, relatively minor degradation was observed in the outer 100–200 μm of samples exposed in the presence of H₂SO₄. Overall, the impacts of impurities were more pronounced for sealants that were more affected by exposure to clean CO₂.</div></div>","PeriodicalId":100578,"journal":{"name":"Geoenergy Science and Engineering","volume":"253 ","pages":"Article 214005"},"PeriodicalIF":0.0,"publicationDate":"2025-05-28","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"144166398","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":"Two-dimensional modified Darcy model for calculating seepage problems in underground gas storage reservoirs","authors":"Yun Chen ,&nbsp;Dejun Liu ,&nbsp;Yang Li ,&nbsp;Zongran Li ,&nbsp;Yuan Zhu","doi":"10.1016/j.geoen.2025.213971","DOIUrl":"10.1016/j.geoen.2025.213971","url":null,"abstract":"<div><div>The management and control of underground gas storage (UGS) require comprehensive optimization of multiple factors. However, the high computational cost of reservoir simulations severely limits the sensitivity and accuracy of UGS control optimization. To address this limitation, this study proposes a modified two-dimensional (2D) Darcy model for rapid simulation of immiscible phase displacement in reservoirs. This model represents a simplified equation of the conventional three-dimensional (3D) two-phase reservoir displacement problem. Compared to the traditional 2D Darcy model, our modified version incorporates a gravity compensation factor and a path compensation factor, designed to account for vertical terrain variations and gravitational effects neglected during dimensional reduction. Through comparative analysis with 3D benchmark models, we demonstrate both the critical role of gravity forces and the limitations of conventional 2D Darcy equations. The modified 2D Darcy model shows significantly improved alignment with 3D simulation results while reducing computational costs by over 70% without compromising model stability. Due to the compensatory modification of the simplified model based on the 2D Darcy equation describing the behavior of force action. So it cannot only be used to describe the gas injection problem of underground gas storage. And theoretically, it can be generalized to analyze three-phase (oil–gas–water) migration in complex reservoirs under Darcy flow regimes.</div></div>","PeriodicalId":100578,"journal":{"name":"Geoenergy Science and Engineering","volume":"253 ","pages":"Article 213971"},"PeriodicalIF":0.0,"publicationDate":"2025-05-27","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"144166399","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":"Prediction of hydraulic fracture parameters in tight gas reservoir using physics-constrained neural network","authors":"Huiying Tang ,&nbsp;Shangui Luo ,&nbsp;Ge He ,&nbsp;Honglin Xiao ,&nbsp;Yulong Zhao ,&nbsp;Qinzhuo Liao ,&nbsp;Liehui Zhang","doi":"10.1016/j.geoen.2025.214001","DOIUrl":"10.1016/j.geoen.2025.214001","url":null,"abstract":"<div><div>The prediction of hydraulic fracture parameters is crucial for hydraulic fracturing evaluation and design. For field scale problems, the geometries of hydraulic fractures are mostly evaluated with numerical simulations, assisted by monitoring methods such as micro-seismic, tracer, and optical fiber techniques. However, such simulations are often time-consuming and difficult to meet the computational efficiency requirement for treatment parameter optimizations. In this paper, a physics-constrained neural network (PCNN) model, with the modified PKN model as its loss function, is proposed to predict the fracture parameters in tight gas reservoirs. Random search hyperparameter optimization, 10-fold cross validation, and ensemble learning are further used to increase the model accuracy. This model is systematically validated through hydraulic fracturing numerical simulations and field monitoring data. The results indicate that compared with the modified PKN model and the deep neural network (DNN), the PCNN shows the best generalization ability and prediction accuracy, while also avoiding predictions that violate physical laws. For heterogeneous reservoirs, the PCNN model can still provide a fast and reasonable prediction of fracture parameters.</div></div>","PeriodicalId":100578,"journal":{"name":"Geoenergy Science and Engineering","volume":"253 ","pages":"Article 214001"},"PeriodicalIF":0.0,"publicationDate":"2025-05-27","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"144166390","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":"Relationship between architecture of uranium reservoirs and mineralization: A case study from the northern Songliao Basin, China","authors":"Weihong Liu ,&nbsp;Changqi Guo ,&nbsp;Hui Rong ,&nbsp;Yang Liu ,&nbsp;Qiwei Wang ,&nbsp;Kaiyu Chang","doi":"10.1016/j.geoen.2025.214006","DOIUrl":"10.1016/j.geoen.2025.214006","url":null,"abstract":"<div><div>Using a large volume of drilling data, this study aims to characterize the geometry and architecture of the uranium reservoir of the Lower Sifangtai Formation in the northern Songliao Basin on the basis of core observation, polarized light microscope, scanning electron microscopy (SEM), elemental analysis (EA) and sedimentary mapping. Following that, the effects of the geometry and architecture of uranium reservoirs on the uranium metallogenetic mechanism were discussed. The average thickness of the uranium reservoir of the Lower Sifangtai Formation in the southern Daqing area is 20.62 m, and the average ratio of the sandstone and strata is 41.02 %, with high value zones mainly distributed in the west, northeast and central-south of the study area. The average thickness of the impermeable beds is 30.15 m, and the average number of impermeable beds is 3, with high value zones mainly developed in the central-north, northwest and southwest of the study area. The average thickness of oxidized sandstones is 4.28 m, and the average ratio is 15.68 %. Oxidized zones are mainly developed in the northeast of the study area and on the north of the southern denudation zone, where the uranium reservoir thickness is 15–30 m, the ratio of the sandstone and strata is over 60 %, the thickness of the impermeable beds is less than 20 m and the number of impermeable beds is less than 2. Uranium mineralization is mainly developed near the transitional zone with the uranium reservoir thickness of 10–20 m, the ratio of the sandstone and strata of 20 %–80 %, the impermeable beds thickness of 10–40 m and the number of impermeable beds of 2–8. This study indicates that the geometry and architecture of uranium reservoir have a controlling effect on formation of the interlayer oxidized zone, which hence restricts uranium mineralization. The results have unveiled the restrictive mechanism of uranium reservoir architecture on uranium mineralization, laying a foundation for the study of regional uranium metallogenic regularities.</div></div>","PeriodicalId":100578,"journal":{"name":"Geoenergy Science and Engineering","volume":"253 ","pages":"Article 214006"},"PeriodicalIF":0.0,"publicationDate":"2025-05-26","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"144166391","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 comprehensive research on the effect of heavy oil properties by carbon dioxide and the evolution of enhanced efficiency in assisted steam flooding","authors":"Liang Xue ,&nbsp;Bobo Luo ,&nbsp;Pengyu Wang ,&nbsp;Hairiu Kong ,&nbsp;Pengcheng Liu","doi":"10.1016/j.geoen.2025.214004","DOIUrl":"10.1016/j.geoen.2025.214004","url":null,"abstract":"<div><div>Under the framework of carbon capture, utilization, and storage-enhanced oil recovery (CCUS-EOR) technology, a strategy is proposed to enhance the heavy oil recovery during the late stage of steam flooding by utilizing carbon dioxide (CO₂) to regulate the physical properties of heavy oil and strengthen assisted steam flooding. Taking the F Block in Xinjiang Oilfield, China as example, this study systematically examined the regulatory effect of CO₂ on the high-pressure properties of heavy oil. Additionally, two-dimensional visual physical models and sand-packed physical models were utilized to conduct an in-depth analysis of the sweep characteristics, microscopic displacement mechanisms, and oil recovery of CO₂-assisted steam flooding. The results indicate that CO₂ significantly improves the physical properties of heavy oil. The bubble point pressure increases with the amount of dissolved CO₂, while the expansion coefficient initially increases and then decreases with rising CO₂ injection pressure. Under the influence of CO₂, the viscosity reduction of heavy oil reached 27.16 %, and the relative density decreased to as low as 0.907. Injecting CO₂ during the late stage of steam flooding mitigates steam channeling issues. CO₂ dissolves and diffuses into the heavy oil, altering the interfacial film properties of emulsions and facilitating emulsion breakdown. These combined effects alleviate the oil trapping effect within the pores of low-permeability regions, significantly increasing the swept area. As a result, the areal sweep efficiency improves by 7.47 %, while the residual oil saturation is minimized to the greatest possible extent. The oil recovery improved from 39.13 % to 50.76 %, representing an 11.63 % enhancement compared to steam flooding alone. This study highlights the potential of CO₂ injection to enhance oil recovery during the late stage of steam flooding in heavy oil reservoirs. It also provides valuable insights into the regulatory effects of CO₂ on the physical properties of heavy oil and the underlying microscopic mechanisms.</div></div>","PeriodicalId":100578,"journal":{"name":"Geoenergy Science and Engineering","volume":"253 ","pages":"Article 214004"},"PeriodicalIF":0.0,"publicationDate":"2025-05-26","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"144166393","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":"Geothermal field thermal response experiment of large diameter energy shaft: A practical calculation method for thermal property parameters","authors":"Jie Zhou ,&nbsp;Xin Wang ,&nbsp;Zhenming Shi ,&nbsp;Jie Xu ,&nbsp;Liang Lv","doi":"10.1016/j.geoen.2025.214000","DOIUrl":"10.1016/j.geoen.2025.214000","url":null,"abstract":"<div><div>In the thermal response experiment of energy shafts, an accurate heat transfer model is essential for effectively determining the thermal properties of the surrounding soil in real-time. This paper presents an innovative cylindrical concrete test structure designed for field thermal response experiments of simulated energy shafts, aiming to reduce testing errors and design costs. Based on superposition theory, we have developed an unsteady heat transfer model that accounts for the differences in thermal properties between structures and soil, along with a practical calculation method for field applications. The results indicate that, compared to traditional linear heat source models and hollow column source models, the proposed model more accurately describes the heat transfer process in energy shafts. This improvement helps avoid calculation errors associated with neglecting material differences in the structure. Furthermore, the model effectively calculates the thermal conductivity of the soil surrounding the structure, as well as the thermal resistance within the structure. While maintaining a level of calculation accuracy comparable to that of solid column heat source models, the computational workload is reduced by more than half. Additionally, the practical calculation method is well-suited for various engineering application scenarios, ensuring both the accuracy of data processing and significantly enhancing the convenience of analyzing field thermal physical test data. The findings of this research provide a valuable reference for thermal response testing and the optimal design of energy shafts.</div></div>","PeriodicalId":100578,"journal":{"name":"Geoenergy Science and Engineering","volume":"253 ","pages":"Article 214000"},"PeriodicalIF":0.0,"publicationDate":"2025-05-26","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"144147860","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 statistical framework for survival modeling and performance evaluation of electrical submersible pumps","authors":"Ahmed Salah Mohamed ,&nbsp;Said Kamel El-Sayed ,&nbsp;Ibrahim Salahudin Mohamed","doi":"10.1016/j.geoen.2025.213993","DOIUrl":"10.1016/j.geoen.2025.213993","url":null,"abstract":"<div><div>Optimizing logistics and finances in artificial lift system (ALS) management requires objective performance data. This is necessary for logistics and financial planning. This research explores survival analysis, a statistical technique well-suited for analyzing time-to-event data like equipment lifespan. Moving beyond traditional statistical metrics like average run life (ARL) and mean time between pulls (MTBP), this approach provides a more comprehensive picture of system performance. We demonstrate the methodology, using Python and basic mathematics, on a real-world dataset of 641 electrical submersible pumps (ESPs) installed in an Egyptian onshore field over 14 years of operations.</div><div>The statistical measures and survival analysis yielded valuable insights into the population's performance through the development of survival models. These models enable the forecasting of equipment events like pulls and failures for better planning and estimate potential scenarios for both the worst and best-case situations. Model validation was performed through comparison to actual performance. Furthermore, the analysis identified trends in performance improvement over time and pinpointed key areas that can be addressed to extend the lifespan of the ESP systems. Additionally, the analysis allows for population segmentation based on criteria like time, equipment variations, or service conditions, enabling targeted performance evaluation. By leveraging this statistical framework, oil companies can gain a deeper understanding of their ALS systems' performance, leading to improved decision-making and ultimately enhanced production efficiency.</div></div>","PeriodicalId":100578,"journal":{"name":"Geoenergy Science and Engineering","volume":"253 ","pages":"Article 213993"},"PeriodicalIF":0.0,"publicationDate":"2025-05-19","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"144115803","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":"Feasibility analysis of converting abandoned oil and gas wells into geothermal wells and power generation","authors":"Jing-bin Li,&nbsp;Hao Wang,&nbsp;Tianshu Wang,&nbsp;Huan Li,&nbsp;Chenrui Guo,&nbsp;Dong Yang","doi":"10.1016/j.geoen.2025.213985","DOIUrl":"10.1016/j.geoen.2025.213985","url":null,"abstract":"<div><div>The growing emphasis on environmental protection and the urgent need for clean energy development have highlighted the potential of repurposing abandoned oil and gas wells. Converting these wells cost-effectively not only unlocks geothermal resources but also reduces abandonment and drilling costs, making it a key research focus. This study proposes a bottom-up renovation approach using double-layer insulation tubing for single closed-loop heat extraction in abandoned wells. A 4800-m-deep well was analyzed as a case study. Results show that, with an inlet temperature of 20 °C and a flow rate of 15 m³/h, the outlet temperature reaches 67 °C, yielding a heat extraction capacity of 857 kW and a ten-year net profit of RMB 2.33 million yuan. Utilizing a high-temperature reservoir at the bottom increases the outlet temperature by 4 °C when set to 200 m. The outlet temperature rises with insulation length and inlet temperature but decreases with higher flow rates. Based on outlet temperature, the optimal parameters are an insulation length of 4200 m, a flow rate of 10 m³/h, and an inlet temperature of 30 °C. Economic analysis shows that while heating revenue increases with insulation length, optimizing operational time is crucial for maximizing net profit. Higher inlet flow rates boost heat extraction but sharply increase pressure losses, leading to an initial rise followed by a decline in net profit. Additionally, the system's power generation potential suggests dual-use for heating and power generation could maximize economic benefits. This study provides a theoretical foundation and practical recommendations for advancing single-well closed-loop heat extraction systems.</div></div>","PeriodicalId":100578,"journal":{"name":"Geoenergy Science and Engineering","volume":"253 ","pages":"Article 213985"},"PeriodicalIF":0.0,"publicationDate":"2025-05-18","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"144105734","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":"Data-driven and unsupervised machine learning for comprehensive quality evaluation and intelligent optimization of multi-stage design in horizontal wells within shale reservoir","authors":"Wenchao Wang ,&nbsp;Xinfang Ma ,&nbsp;Wenzhe Zhang ,&nbsp;Yushi Zou ,&nbsp;Shicheng Zhang ,&nbsp;Xin Wang ,&nbsp;Lifeng Yang","doi":"10.1016/j.geoen.2025.213991","DOIUrl":"10.1016/j.geoen.2025.213991","url":null,"abstract":"<div><div>A critical strategy for shale reservoir development is the comprehensive reservoir evaluation and the fine division of fracturing grades. However, the diversity of evaluation parameters limits hydraulic fracturing optimization. Therefore, we propose an adaptive-category-gaussian-mixture-model (AC-GMM) based on a geology engineering framework, combining reservoir quality (RQ) and completion quality (CQ) to classify the composite quality index (CQI). The classification serves as the basis for an intelligent algorithm developed for fracturing design. Taking three typical wells from the Lucaogou Formation in the Junggar Basin in China as examples the following research results are summarized. First, the AC-GMM model can finely identify the fracturing grades, achieving a conformity rate of over 90 % with the field production data. Second, the paper obtains three types of fracturing grades (I, II, III) and further refines them into four grades (I, II₁, II₂, III), the grade I considers both high RQ and CQ, while grade II only regards the better of the double quality, and prioritizes the better CQ. Third, the intelligent algorithm groups similar qualities into the same stage, achieving up to 96 % intra-stage homogeneity, significantly enhancing hydraulic fracturing efficiency for long horizontal wells. Our work provides a data-driven framework for optimizing multi-stage fracturing designs in shale reservoirs.</div></div>","PeriodicalId":100578,"journal":{"name":"Geoenergy Science and Engineering","volume":"253 ","pages":"Article 213991"},"PeriodicalIF":0.0,"publicationDate":"2025-05-17","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"144105736","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}