Geoenergy Science and Engineering最新文献

{"title":"A constitutive model of natural gas hydrate reservoirs during exploitation by methane-carbon dioxide replacement","authors":"Chuanliang Yan ,&nbsp;Yong Chen ,&nbsp;Wanqing Tian ,&nbsp;Yuanfang Cheng ,&nbsp;Yang Li ,&nbsp;Jin Sun","doi":"10.1016/j.geoen.2025.213875","DOIUrl":"10.1016/j.geoen.2025.213875","url":null,"abstract":"<div><div>For the safe exploitation of marine gas hydrate resources, the mechanical stability of the reservoir itself and that of the exploitation equipment system need to be ensured, of which the former is the fundamental factor. The carbon dioxide replacement method uses carbon dioxide to chemically replace methane and then generate carbon dioxide hydrates in the reservoir, enhancing the reservoir stability while also sealing the reservoir with carbon dioxide. In this work, methane hydrate samples containing sediments were artificially prepared. Carbon dioxide replacement for methane hydrates and triaxial compression tests during carbon dioxide replacement were carried out. Based on the experimental results, the parameters of the Duncan–Chang constitutive model were modified according to the replacement ratio and hydrate saturation, and a nonlinear constitutive model for describing natural gas hydrate reservoirs under the effect of carbon dioxide replacement was established. These results indicate that the diffusion of carbon dioxide into a sample may gradually be blocked and inhibited by carbon dioxide hydrate formation during replacement. Overall, the stress‒strain curves of the samples are hyperbolic. The sample undergoes elastic deformation in the initial stage of the triaxial compression test. Subsequently, it undergoes plastic failure without apparent peak strength and shows strain-hardening characteristics. After replacement, the sample strength increases, and the stress‒strain curve is similar in shape to that before replacement, with an upward shift. In the established constitutive model, the replacement ratio significantly affects the initial tangent modulus, cohesion, and initial tangent Poisson's ratio. The calculation results provided by the model fit the experimental data well.</div></div>","PeriodicalId":100578,"journal":{"name":"Geoenergy Science and Engineering","volume":"251 ","pages":"Article 213875"},"PeriodicalIF":0.0,"publicationDate":"2025-04-05","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"143807916","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":"Simplified petrophysical reconnaissance tool for evaluation of unconventional shales","authors":"Samuel Gyasi,&nbsp;Steven K. Henderson,&nbsp;Dorcas S. Eyinla,&nbsp;Aman Arora","doi":"10.1016/j.geoen.2025.213859","DOIUrl":"10.1016/j.geoen.2025.213859","url":null,"abstract":"<div><div>Petrophysical evaluation of unconventional shale reservoirs is complex due to the formation's heterogeneity, requiring advanced methods to estimate parameters such as effective porosity (<span><math><mrow><msub><mo>∅</mo><mi>e</mi></msub></mrow></math></span>), effective water saturation (<span><math><mrow><msub><mi>S</mi><mrow><mi>w</mi><mi>e</mi></mrow></msub></mrow></math></span>), and permeability (<span><math><mrow><mi>k</mi></mrow></math></span>). While various techniques are available to characterize these reservoirs, this study presents a simplified workflow for reconnaissance evaluations aimed at identifying sweet spots. The proposed method utilizes standard resistivity and porosity logs (e.g., triple or quad combo), making it accessible and reproducible for use in commercial software or spreadsheets, even by non-experts. By integrating modified Archie's equation, a log-based total organic carbon (TOC) estimate, and Lewis's cutoffs into a single composite curve, this approach streamlines the process of sweet spot identification. The combined methods were tested on the Wolfcamp Shale in the Permian Basin, as well as the Woodford and Bakken shales, consistently identifying similar sweet spot intervals. The results demonstrated a strong alignment between the intervals flagged by Archie's method and those identified using Lewis's cutoffs, with the upper section of Wolfcamp B meeting sweet spot criteria, while the lower section showed less consistency. Similar patterns were observed in the Woodford and Bakken shales, where primary sweet spots were determined based on consistent cutoff satisfaction. The methodology was further validated by comparing the results with landing depths from DrillingInfo reports, confirming its effectiveness across different formations. Thus, this cost-effective method presented in this study reduces the reliance on expensive tools like nuclear magnetic resonance (NMR) or core analysis for sweet spot delineation, making it especially valuable for operators with budget constraints. Furthermore, the methodology provides an accessible approach for professionals of varying expertise levels, facilitating more informed decisions regarding lateral landing depths and net interval definitions in unconventional reservoirs.</div></div>","PeriodicalId":100578,"journal":{"name":"Geoenergy Science and Engineering","volume":"251 ","pages":"Article 213859"},"PeriodicalIF":0.0,"publicationDate":"2025-04-03","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"143777243","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":"Investigating the impact of wellbore lateral heat transfer on the performance of high-temperature aquifer thermal energy storage system by the coupling of wellbore and reservoir simulators","authors":"Guoqiang Yan ,&nbsp;Pål Østebø Andersen ,&nbsp;Yangyang Qiao ,&nbsp;Dimitrios Georgios Hatzignatiou ,&nbsp;Bo Feng ,&nbsp;Thomas Kohl","doi":"10.1016/j.geoen.2025.213874","DOIUrl":"10.1016/j.geoen.2025.213874","url":null,"abstract":"<div><div>This study investigates the often-overlooked impact of wellbore lateral heat transfer on high-temperature aquifer thermal energy storage (HT-ATES) systems, focusing on the Swiss Bern project. We coupled our in-house wellbore simulator (Moskito) with the reservoir simulator (PorousFlow) under the MOOSE framework to analyze wellbore heat loss. Utilizing both numerical and analytical approaches, we reveal how wellbore heat loss affects HT-ATES performance compared to previous studies that ignored it. Our sensitivity analysis examines various wellbore configurations and operational parameters, evaluating performance indicators including extracted energy, wellbore lateral heat loss fraction, and reservoir heat loss fraction. Key findings include: a more than 10 % difference between the analytical and numerical calculations of wellbore lateral heat loss. Smaller wellbore diameters, such as 6.75 inches, enhance energy recovery efficiency by enabling larger fluid extraction volumes. Low thermal conductivity wellbore casing materials (e.g., 0.045 W m⁻¹∙K⁻¹) could reduce wellbore lateral heat loss by 51.4 %. Although energy recovery efficiency declines with more supporting wells during the initial storage cycle, three supporting wells yield the best performance in later cycles due to larger extracted fluid volumes. High flow rates (e.g., 25 L s⁻¹) enhance energy recovery efficiency by decreasing heat losses through faster fluid movement, which reduces residence time and thermal diffusion. While high fluid injection temperatures (e.g., 210 °C) increase heat losses, overall heat loss fractions decrease due to significant injected energy. This study highlights the critical role of wellbore lateral heat loss in evaluating the performance of the HT-ATES system, providing insights on how to design and optimize these systems.</div></div>","PeriodicalId":100578,"journal":{"name":"Geoenergy Science and Engineering","volume":"251 ","pages":"Article 213874"},"PeriodicalIF":0.0,"publicationDate":"2025-04-02","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"143790848","PeriodicalName":null,"FirstCategoryId":null,"ListUrlMain":null,"RegionNum":0,"RegionCategory":"","ArticlePicture":[],"TitleCN":null,"AbstractTextCN":null,"PMCID":"OA","EPubDate":null,"PubModel":null,"JCR":null,"JCRName":null,"Score":null,"Total":0}

{"title":"Acidizing of deep carbonate reservoirs to reduce breakdown pressure: A review","authors":"Pingli Liu ,&nbsp;Yu Wu ,&nbsp;Xiang Chen ,&nbsp;Wen Luo ,&nbsp;Jinming Liu ,&nbsp;Pengfei Chen ,&nbsp;Gang Xiong ,&nbsp;Juan Du","doi":"10.1016/j.geoen.2025.213856","DOIUrl":"10.1016/j.geoen.2025.213856","url":null,"abstract":"<div><div>Acid treatments aimed at reducing formation breakdown pressure are becoming increasingly popular in stimulating deep and ultra-deep geothermal and natural gas reservoirs, where high pumping pressures are typically required for fracturing. This technique effectively reduces surface pumping pressures, ensuring safe operations. Through multiscale experiments and mechanistic analysis, this study reveals the fundamental mechanisms underlying breakdown pressure reduction via acid preconditioning. Key findings include: (1) High breakdown pressures arise from high in-situ stress, low porosity and permeability, and engineering contamination. (2) Acid-induced mineral dissolution triggers dual effects-pore structure evolution enhances reservoir permeability (facilitating subsequent fracturing fluid imbibition and pressure transmission), while mechanical property degradation substantially weakens rock resistance to fracturing. (3) Comparative analysis of HCl, organic acids, and chelating agents demonstrates that high-temperature reservoirs benefit from low-corrosivity chelating agents (e.g., GLDA) or organic acid systems combined with low-concentration HCl, achieving optimal dissolution efficiency while ensuring wellbore integrity. (4) A multiscale laboratory evaluation framework was established to integrate experimental data for optimizing acid formulations and post-acid fracturing strategies. This paper provides mechanistic insights, acid system selection criteria, and experimental methodologies for breakdown pressure reduction in deep carbonate reservoirs, offering significant engineering value for achieving safe and efficient reservoir stimulation.</div></div>","PeriodicalId":100578,"journal":{"name":"Geoenergy Science and Engineering","volume":"251 ","pages":"Article 213856"},"PeriodicalIF":0.0,"publicationDate":"2025-04-01","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"143823545","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 the computational model and distribution characteristics of rock fracture energy induced by supercritical CO2 phase transition","authors":"Erdi Abi ,&nbsp;Qifu Zeng ,&nbsp;Mingwei Liu ,&nbsp;Yingren Zheng ,&nbsp;Yafeng Han ,&nbsp;Mingjing Jiang ,&nbsp;Fayou Wu ,&nbsp;Deying Tang ,&nbsp;Hongbo Du ,&nbsp;Jie Zhang","doi":"10.1016/j.geoen.2025.213862","DOIUrl":"10.1016/j.geoen.2025.213862","url":null,"abstract":"<div><div>The current research on the energy distribution characteristics of supercritical CO₂ phase transition fracturing (CDPTF) is relatively lacking, particularly for effective quantitative calculation methods. This study develops models to calculate CO₂ shock wave and gas expansion energy, quantifying their roles in rock damage and energy distribution. Five field tests measured acoustic wave velocity, rock damage, and energy distribution during CO₂ rock fracturing. The results indicate that supercritical CO₂ creates large rock fragments, with a small crushing zone, forming numerous through-cracks on the surface and causing weak seismic effects. Additionally, the radius of rock failure ranges from 4.3 to 5.6 m, with gas expansion energy accounting for 84.36 % and shock wave energy only 15.64 %. Specifically, the average energy proportion of the shock wave used for rock fragmentation, crack formation, and surface vibration is 2.57 %, 12.13 %, and 1.94 %, respectively. The average energy proportion of gas expansion used for crack propagation is 42.15 %, while the energy used for gas ejection (i.e., wasted energy) accounts for 41.21 %, reflecting a relatively high overall energy efficiency. Furthermore, reducing the initial phase change pressure or increasing the tensile strength of the rock can effectively improve energy utilization efficiency. Minimizing gas leakage or applying the method in high-strength rock areas can further enhance the efficiency of gas expansion energy in rock fracturing. This study provides a theoretical basis for optimizing CDPTF energy utilization in rock fracturing.</div></div>","PeriodicalId":100578,"journal":{"name":"Geoenergy Science and Engineering","volume":"251 ","pages":"Article 213862"},"PeriodicalIF":0.0,"publicationDate":"2025-04-01","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"143760758","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 and application research on sweep efficiency for non-condensable gases assisted vertical-horizontal steam drainage in extra-heavy reservoirs","authors":"Yuting Wang ,&nbsp;Peng Liu ,&nbsp;Daode Hua ,&nbsp;Zhongyi Zhang ,&nbsp;Chao Wang ,&nbsp;Pengcheng Liu ,&nbsp;Jipeng Zhang ,&nbsp;Shuo Yang ,&nbsp;You Zhou","doi":"10.1016/j.geoen.2025.213857","DOIUrl":"10.1016/j.geoen.2025.213857","url":null,"abstract":"<div><div>The vertical-horizontal steam drainage (VHSD) method, combining vertical and horizontal wells, enhances steam-assisted gravity drainage to improve sweep efficiency and oil-steam ratios in extra-heavy oil reservoirs. This approach has become an effective alternative to steam stimulation in aging oil fields, particularly in China. However, thermal losses in late-stage VHSD can reduce the oil-steam ratio. The use of non-condensable gases like CO₂, CH₄, and N₂ may improve this process. Previous research on non-condensable gases mainly focused on steam-assisted gravity drainage (SAGD) with parallel, closely spaced wells, whereas VHSD uses wells positioned 50–60 m apart, affecting steam chamber dynamics and gas behavior.</div><div>This study is the first systematic investigation of non-condensable gases in VHSD, using the Z1 block of Xinjiang Oilfields in China as a case study. It examines the effects of CO₂, CH₄, and N₂ in enhancing VHSD, combining lab experiments with field research. A novel approach emphasizes well arrangement's impact on gas distribution and steam chamber development. The results show that CO₂ outperforms CH₄ and N₂ in solubility and viscosity reduction, leading to the highest sweep efficiency. At 1 MPa, CO₂ and CH₄ increased oil recovery by 4.47 % and 1.63 % respectively. At 2 MPa, the increases were 8.01 % and 5.1 %, while N₂ slightly reduced efficiency. Non-condensable gases accumulated at the steam chamber boundary, impacting heat loss, chamber morphology, and expansion rates. CO₂-assisted development yielded the best results, with a 4.3 % recovery rate increase. While N₂ effectively enhanced the oil-steam ratios, its influence on the recovery rate was relatively modest.</div></div>","PeriodicalId":100578,"journal":{"name":"Geoenergy Science and Engineering","volume":"251 ","pages":"Article 213857"},"PeriodicalIF":0.0,"publicationDate":"2025-03-29","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"143739898","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":"Comprehensive study of the mechanical characteristics and fracture propagation mechanisms of gravel-bearing sandstone reservoirs based on the finite element method","authors":"Kai Feng ,&nbsp;Zhenlin Wang ,&nbsp;Guanfang Li ,&nbsp;Peilin Zhang ,&nbsp;Zhichao Wang ,&nbsp;Yujia Wang ,&nbsp;Ying Tang ,&nbsp;Bin Jiang ,&nbsp;Kouqi Liu","doi":"10.1016/j.geoen.2025.213860","DOIUrl":"10.1016/j.geoen.2025.213860","url":null,"abstract":"<div><div>Gravel-bearing sandstone reservoirs represent a significant type of reservoir in oil and gas exploration. Due to the difference of the spatial random distribution the content and the shape of the gravel particles, these reservoirs exhibit complex mechanical properties and failure modes. In this study, a numerical model of gravel-bearing sandstone was developed by using the Finite Element Method (FEM) and were verified by the actual indoor experimental data. The effect of the gravel particle sizes, gravel content, and gravel types on the compressive peak strength and microcrack evolution processes are further analyzed. The results reveal that cracks initiate within the sandstone matrix surrounding the gravel and propagate through the gravel with continued loading. The primary factors governing the stability of gravel-bearing sandstone are the gravel radius and content. The variation in gravel penetration rate is synchronized with the changes in peak strength. By embedding gravel particles of different shapes into the model, it is observed that the peak compressive strength of round gravel is comparable to that of elliptical gravel, with both exhibiting higher peak strengths than angular gravel. Regression models demonstrate that the tensile strength difference between the gravel and the sandstone matrix is a critical parameter influencing gravel penetration. Confining pressure has a relatively minor effect on the elastic modulus, while its impact on peak compressive strength is significantly more pronounced.</div></div>","PeriodicalId":100578,"journal":{"name":"Geoenergy Science and Engineering","volume":"251 ","pages":"Article 213860"},"PeriodicalIF":0.0,"publicationDate":"2025-03-29","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"143768778","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":"Analysis of solid concentration profiles in particle sedimentation in directional reservoirs using the gamma-ray attenuation technique","authors":"R.S. Schimicoscki ,&nbsp;E.A. Souza ,&nbsp;F.M. Fagundes ,&nbsp;J.J.R. Damasceno ,&nbsp;F.O. Arouca","doi":"10.1016/j.geoen.2025.213865","DOIUrl":"10.1016/j.geoen.2025.213865","url":null,"abstract":"<div><div>Sedimentation of solid particles in drilling fluids poses significant challenges in directional drilling operations. This study investigates the dynamics of solid sedimentation in directional wells, considering various fluid rheologies. Experimental tests were conducted using three types of suspensions: aqueous media with calcium carbonate, aqueous media with glycerin, and aqueous media with xanthan gum, the latter two containing glass microspheres. These experiments were conducted across inclinations ranging from 0° to 60°, employing the gamma-ray attenuation technique. Results revealed that inclination intensifies the Boycott effect and alters concentration curve behaviors. Particularly, fluids with re-established gel structures exhibited accelerated sedimentation velocities, indicating the profound influence of fluid rheology on sedimentation dynamics. These findings underscore the pivotal roles of inclination and fluid rheology in governing sedimentation behavior, critical for designing directional wells and optimizing oil extraction processes. Insights from this study offer potential to mitigate operational risks, enhance drilling efficiency, and advance drilling practices for challenging environments.</div></div>","PeriodicalId":100578,"journal":{"name":"Geoenergy Science and Engineering","volume":"251 ","pages":"Article 213865"},"PeriodicalIF":0.0,"publicationDate":"2025-03-28","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"143739900","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":"Robust multi-objective production optimization with CO2 emissions reduction","authors":"Dean S. Oliver ,&nbsp;Jon Sætrom ,&nbsp;Arne Skorstad ,&nbsp;Trond Saksvik ,&nbsp;Odd Kolbjørnsen","doi":"10.1016/j.geoen.2025.213845","DOIUrl":"10.1016/j.geoen.2025.213845","url":null,"abstract":"<div><div>In this paper, we describe an efficient methodology for simultaneously maximizing the expected profitability of oil field production and minimizing the expected emission of greenhouse gasses associated with the production through optimizing controls of the reservoir injection and production wells. Instead of simply minimizing water production and injection as is often done as a surrogate for energy consumption, we use an emissions calculator to account for the energy efficiency of the injection and compression system. Because our approach to minimization is efficient, we are able to account for uncertainty in geology during the minimization and to use the operational simulation model for the field.</div><div>The most common approach to solving for Pareto optimal solutions is through some type of scalarization of the optimization problem. In this study, we apply the weighted-sum method, which despite its limitations when applied to problems with feasible regions for objective outcomes that are not convex provides Pareto optimal solutions at a relatively low cost.</div><div>Finally, we apply the methodology to the problem of well controls for a three-well field in the Norwegian Sea with platform facilities shared by another field. The reservoir model has 330,000 active cells with an active aquifer. The emissions calculator uses pump characteristics to account for fuel usage attributed to water injection. Gas compression, water treatment, and base energy costs are estimated by calibration of allocated energy usage to historical production data. The expectation of the objective functions is approximated by the sample average of the objective functions over the ensemble of 50 history-matched model realizations. Control variables are the injector and producer rates over one-month intervals. The Stochastic Simplex Approximate Gradient (StoSAG) method was used to estimate the gradient of the scalarized objective function and a quasi-Newton method (BFGS) was used for minimization. Results showed that moderately large reductions in CO2 emissions from a reference case optimized purely for profitability could be obtained at the cost of modest reductions in NPV. Larger reductions in CO<span><math><msub><mrow></mrow><mrow><mi>2</mi></mrow></msub></math></span> emissions were costlier. Additionally, the optimized reservoir production strategies were not intuitively obvious, indicating that a formal multi-objective optimization approach was beneficial.</div></div>","PeriodicalId":100578,"journal":{"name":"Geoenergy Science and Engineering","volume":"251 ","pages":"Article 213845"},"PeriodicalIF":0.0,"publicationDate":"2025-03-28","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"143760757","PeriodicalName":null,"FirstCategoryId":null,"ListUrlMain":null,"RegionNum":0,"RegionCategory":"","ArticlePicture":[],"TitleCN":null,"AbstractTextCN":null,"PMCID":"OA","EPubDate":null,"PubModel":null,"JCR":null,"JCRName":null,"Score":null,"Total":0}

{"title":"Thermal-hydraulic performance of high temperature aquifer thermal energy storage within naturally fractured reservoir: Functional dependence of heat recovery efficiency to multi-parameters","authors":"Yan Ding ,&nbsp;Yibin Jin ,&nbsp;Zuoji Qin ,&nbsp;Chunxiao Li ,&nbsp;Changsheng Zhang ,&nbsp;Quanrong Wang","doi":"10.1016/j.geoen.2025.213858","DOIUrl":"10.1016/j.geoen.2025.213858","url":null,"abstract":"<div><div>High Temperature-Aquifer Thermal Energy Storage (HT-ATES) systems provide an efficient solution for large-scale energy storage, playing a crucial role in achieving carbon neutrality and reducing peak carbon dioxide emissions. Although naturally fractured reservoirs are abundant in geothermal-rich sedimentary basins, they have been largely underutilized as potential reservoirs for HT-ATES applications due to their complex characteristics. In this study, a multi-physics model was developed to systematically investigate the thermal-hydraulic behavior of HT-ATES in naturally fractured reservoirs. The model was validated against experimental data, showing excellent agreement with production temperatures, with deviations within 3.2 %. By varying key operational parameters and matrix properties, this study quantified their impact on the thermal behavior and heat recovery efficiency of the HT-ATES system. Results showed that injection temperature was the most influential factor on heat recovery efficiency, followed by vertical and horizontal permeability of the reservoir. A functional dependence of heat recovery efficiency on these operational parameters and matrix properties was established and validated, with a relative error of less than 5 % for additional testing cases. Notably, among the simulated cases, naturally fractured reservoirs demonstrated lower heat recovery efficiency but higher total energy recovery potential due to their enhanced fluid accommodation capabilities. This work provides a deep understanding of the performance dynamics of HT-ATES systems in naturally fractured reservoirs, offering critical insights for operational strategies optimization.</div></div>","PeriodicalId":100578,"journal":{"name":"Geoenergy Science and Engineering","volume":"251 ","pages":"Article 213858"},"PeriodicalIF":0.0,"publicationDate":"2025-03-28","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"143786140","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}