Geoenergy Science and Engineering最新文献

{"title":"Geothermal potential of low enthalpy reservoirs in the Western Canada Sedimentary Basin","authors":"Makram Hedhli,&nbsp;Wanju Yuan,&nbsp;Stephen E. Grasby,&nbsp;Andy Mort","doi":"10.1016/j.geoen.2025.213876","DOIUrl":"10.1016/j.geoen.2025.213876","url":null,"abstract":"<div><div>Here we investigate Mesozoic and Paleozoic porous aquifer systems with different grades of temperature reservoirs to meet growing heat demand and sustain government infrastructure overlying The Western Canada Sedimentary Basin, Canada, where winters are cold (average daily temperature below −4 °C) and direct heat is an essential energy demand. Two stratigraphic intervals were modeled and simulated for geothermal heat production systems: conventional and closed loop. We estimated that 2.93 MWth and 6.9 MWth heat energy can be generated over 30 years of operation in the Mesozoic (300–500 m depth; 100 m thickness, 16 °C reservoir temperature, 1 D permeability, 0.3 porosity, 180 m³/h flow rate, 800 m well spacing) and Paleozoic (1400-1200 m depth, 100 m thickness, 35 °C reservoir temperature, 10 mD permeability, 0.1 porosity, a 180 m³/h flow rate, 400 m spacing) respectively. This study highlights the geothermal potential of the WCSB as a viable opportunity.</div></div>","PeriodicalId":100578,"journal":{"name":"Geoenergy Science and Engineering","volume":"251 ","pages":"Article 213876"},"PeriodicalIF":0.0,"publicationDate":"2025-04-08","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"143821304","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":"Mechanism of fault slippage in the underground gas storage and preliminary application in the Shuang 6 UGS in China","authors":"Yujia Song ,&nbsp;Hejuan Liu ,&nbsp;Zhongshun Min ,&nbsp;Mancang Liu ,&nbsp;Xiaosong Qiu ,&nbsp;Jianjun Liu ,&nbsp;Chunhe Yang","doi":"10.1016/j.geoen.2025.213881","DOIUrl":"10.1016/j.geoen.2025.213881","url":null,"abstract":"<div><div>The mechanical stability of faults is crucial for the safe operation of underground gas storage (UGS). The complex fault systems, strong heterogeneity and anisotropy of geological formations, associating with uncertainty of in-situ stress state after long-term exploitation of oil or gas reservoirs and multiple cycles of injection and production, making it particularly challenging to ensure the safe and efficient operation of the UGS in depleted gas reservoirs. This study investigates the Shuang 6 UGS in the Liaohe basin, NE China, employing a hydro-mechanical coupling approach through both simplified simulation modeling and field case analysis. Systematic parametric studies are carried out to illustrate the effect of key factors on fault slippage. Based on the results of fluid migration and geomechanical responses, an advanced critical pressure perturbation method is proposed to evaluate the risk of fault failure. The findings indicate the following: (1) The fault stress profile exhibites greater complexity than pore pressure due to geomechanical interactions between formations with contrasting properties on hanging wall and footwall; (2) The Δ<em>P</em> in the advanced critical pressure perturbation method provides quantifiable criteria for slip risk evaluation; (3) Low injection rates, small difference in Young's modulus between laminated formations, a high permeable fault zone, and damage zone, as well as simultaneous injection or withdrawal on both sides of the fault, may reduce the risk of fault failure; (4) Specific risk-prone areas are identified in the Xing II/III formation and the right side of Faults 2/3 in the SX block of the Shuang 6 UGS. These insights offer practical guidance for UGS design and operational safety management.</div></div>","PeriodicalId":100578,"journal":{"name":"Geoenergy Science and Engineering","volume":"251 ","pages":"Article 213881"},"PeriodicalIF":0.0,"publicationDate":"2025-04-08","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"143834498","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":"Elastic properties of anisotropic rocks using an stepwise loading framework in a true triaxial testing apparatus","authors":"Farshad Sadeghpour ,&nbsp;Hem Bahadur Motra ,&nbsp;Chinmay Sethi ,&nbsp;Sandra Wind ,&nbsp;Bodhisatwa Hazra ,&nbsp;Ghasem Aghli ,&nbsp;Mehdi Ostadhassan","doi":"10.1016/j.geoen.2025.213883","DOIUrl":"10.1016/j.geoen.2025.213883","url":null,"abstract":"<div><div>Directional dependence of mechanical properties, or waves propagating in geomaterials, known as anisotropy, is important in accurately predicting their response to stresses in various engineering applications. These measurements are generally conducted on cylindrical samples under conventional uniaxial or triaxial loading conditions where two or three samples that are prepared at different directions to the plane of symmetry would be required. To avoid using several samples and the variability that might exist in the specimens, this paper explores laboratory testing of anisotropic shale rock samples under true triaxial test (TTT or polyaxial testing) conditions. Herein, two cubic shale samples (A and B) of different lithotypes, were subjected to an step-wise loading path that was increased gradually on each side of the sample. At the same time, compressional and shear wave velocities were measured in three separate directions when isostatic stress conditions are achieved. As a result, independent components of the stiffness tensor of a transversely isotropic media (static elastic modulus and Poisson's ratio) are calculated from the directional stress-strain curve, while dynamic mechanical parameters are determined from directional ultrasonic wave velocities. The results showed strong dependence of these parameters to the direction of measurements with respect to the plane of symmetry, differing between these two lithotypes, confirming transversely isotropic behavior of the samples with varying magnitudes. Petrographic analysis of the samples revealed this is due to the internal structure and orientation of minerals and foliation, particularly muscovite and clay. Moreover, dynamic mechanical parameters were found larger than the static ones and a robust relationship between them was established. Additionally, Young's modulus, Poisson's ratio along axis of symmetry, as well as the P and S wave velocities traveling perpendicular to the bedding were found smaller compared to those parallel to the bedding. Collectively, this approach made us independent from running tests on several samples and avoid the bias that can exist in testing shale samples with high structural complexity when samples should be prepared in several directions.</div></div>","PeriodicalId":100578,"journal":{"name":"Geoenergy Science and Engineering","volume":"251 ","pages":"Article 213883"},"PeriodicalIF":0.0,"publicationDate":"2025-04-08","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"143826115","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":"Hybrid ROP modeling: Combining analytical and data-driven approaches for drilling","authors":"Ashutosh Sharma ,&nbsp;Tunc Burak ,&nbsp;Runar Nygaard ,&nbsp;Espen Hoel ,&nbsp;Tron Kristiansen ,&nbsp;Morten Welmer","doi":"10.1016/j.geoen.2025.213877","DOIUrl":"10.1016/j.geoen.2025.213877","url":null,"abstract":"<div><div>Rate of penetration (ROP) modeling has been widely employed to improve drilling efficiency, aiming to reduce both operational costs and risks. This study presents a hybrid model for predicting ROP by combining analytical and data-driven approaches, aimed at enhancing drilling efficiency in challenging formations. The model integrates operational parameters, rock strength properties, and bit design factors, using machine learning (ML) to estimate real-time rock strength at the bit for each depth interval by predicting compressional wave velocity and lithology. These predictions facilitate the calculation of uniaxial compressive strength (UCS) and confined compressive strength (CCS), inputs for ROP estimation. The study included datasets from five wells in the Norwegian Continental Shelf, with four wells used for model training and one for model testing/validation (blind test). The Random Forest regression model achieved an R² value of 93% for compressional wave velocity predictions, while the Random Forest classification model attained 96% accuracy in lithology prediction during blind testing. Model validation showed a strong correlation between calculated and measured ROP values, underscoring its accuracy. Sensitivity analysis was performed to evaluate the influence of various parameters, such as weight on bit (WOB), revolutions per minute (RPM), drilling fluid density, flow rate, bit hydraulics, and CCS, highlighting their interdependent effects on ROP. The sensitivity analysis indicated that CCS, WOB, RPM and bit diameter have the greatest impact on ROP. Existing ROP models lack real-time integration of lithology and compressional wave velocity at the bit, limiting their ability to estimate rock strength. This study addresses these gaps by incorporating ML to predict these parameters at each depth interval, enhancing unconfined and confined compressive strength calculations used in the ROP model. The results highlight the importance of optimizing drilling parameters to maximize ROP and operational efficiency, indicating the hybrid model's potential for real-time applications in complex drilling environments.</div></div>","PeriodicalId":100578,"journal":{"name":"Geoenergy Science and Engineering","volume":"251 ","pages":"Article 213877"},"PeriodicalIF":0.0,"publicationDate":"2025-04-08","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"143828881","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":"Generalized analytical solutions of imbibition characteristic behavior in shale matrix blocks under different boundary conditions","authors":"Guanqun Li ,&nbsp;Yong Yang ,&nbsp;Xiaopeng Cao ,&nbsp;Shiming Zhang ,&nbsp;Qi Lv ,&nbsp;Yuliang Su","doi":"10.1016/j.geoen.2025.213878","DOIUrl":"10.1016/j.geoen.2025.213878","url":null,"abstract":"<div><div>Continental shale reservoirs are rich in reserves, imbibition is an essential mechanism for enhancing the oil recovery of the shale matrix system. The pores of shale matrix are divided into organic pores, brittle mineral pores and clay pores. The clay pores have the osmosis of the semi-permeable membrane, which increases the driving force of imbibition, while the non-semi-permeable membrane components are mixed-wet. Based on this, the 1-D mathematical models under different boundary conditions (including Two Ends Open, TEO; One End Open, OEO; and TEO-Oil-Water, TEO-OW) are established using the analytical solution method, and the water saturation distribution and oil recovery characteristics of matrix blocks are studied, revealing distinct imbibition phenomena: (1) Under OEO boundary conditions, counter-current imbibition dominates, with oil recovery proportional to the square root of time before the imbibition front reaches the block end. (2) For TEO boundary conditions, spontaneous imbibition exhibits symmetric counter-current flows from both ends, resulting in approximately twice the oil recovery of OEO. (3) Under TEO-OW conditions, a hybrid process of counter-current and co-current imbibition occurs, with delayed saturation evolution near the outlet. Additionally, forced imbibition under TEO demonstrates co-current flow dominated by oil-water interaction, showing earlier breakthrough with increased oil viscosity. The imbibition models of shale matrix blocks under different boundary conditions effectively reveal the control mechanism of SI and FI, and provide practical guidance for determining shut-in time and optimizing fracturing parameters.</div></div>","PeriodicalId":100578,"journal":{"name":"Geoenergy Science and Engineering","volume":"251 ","pages":"Article 213878"},"PeriodicalIF":0.0,"publicationDate":"2025-04-08","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"143807975","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 deep geothermal resource exploration based on the wide field electromagnetic method: a case study in the Xuwen area","authors":"Qiaoxun Zhang,&nbsp;Ying Zhang,&nbsp;Jianyun Feng,&nbsp;Jun Luo,&nbsp;Xiaorui Yun","doi":"10.1016/j.geoen.2025.213888","DOIUrl":"10.1016/j.geoen.2025.213888","url":null,"abstract":"<div><div>Deep geothermal resources possess significant potential and promising application prospects, serving as an ideal supplement to the existing energy system. However, the exploration and efficient utilization of these resources remain challenging due to the complexity of subsurface geological structures and the limitations of conventional electromagnetic methods. This study addresses these challenges by presenting an innovative application of the Wide Field Electromagnetic Method (WFEM) for the exploration of deep geothermal resources in the Xuwen area. By strategically deploying four survey lines, the study collected comprehensive data, which were processed using advanced inversion techniques to derive resistivity cross-sections. These cross-sections provided fundamental insights into the subsurface electrical layer characteristics, revealing distinct geoelectric structure layers and the spatial distribution of granitic masses. The results clearly demonstrate that the resistivity cross-sections obtained through the WFEM distinctly outline the geoelectric-structure-layer framework of the 'Quaternary and Neogene – Paleogene, Cretaceous, and Paleozoic – basement granites' system. Additionally, these cross-sections accurately represent the geological structure characteristics of the Xuwen Bulge, Maichen Depression, Liushagang Bulge, Wushi Depression, and Qishui Bulge. Furthermore, the granites buried between 1800 m and 4900 m are mainly found in specific locations: along GY1 from station 0–8000 m and from station 18,000 to 51,000 m, along GY2 from station 6000 to 15,600 m, and encompassing GY3 and GY4. These findings provide a solid foundation for selecting favorable target areas for deep geothermal resources and strategically planning the locations for geothermal wells.</div></div>","PeriodicalId":100578,"journal":{"name":"Geoenergy Science and Engineering","volume":"251 ","pages":"Article 213888"},"PeriodicalIF":0.0,"publicationDate":"2025-04-08","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"143807976","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":"Preparation, characterization and application of modified barite grafted with lipophilic polymers for oil-based drilling fluids","authors":"Li-Li Yang,&nbsp;Yun-Peng Wu,&nbsp;Ze-Yu Liu,&nbsp;Zhi-Ting Ou,&nbsp;Hao-Zhe Chen,&nbsp;Guan-Cheng Jiang,&nbsp;Teng-fei Dong,&nbsp;Chang-Jiang Yu,&nbsp;Shang-Jiang Feng","doi":"10.1016/j.geoen.2025.213882","DOIUrl":"10.1016/j.geoen.2025.213882","url":null,"abstract":"<div><div>With the increasing exploration and development of deep oil and gas resources, the applications of oil-based drilling fluids (OBDFs) have become increasingly prevalent. Accordingly, it places higher demands on drilling fluid density for drilling deep and ultra-deep wells. Conventional weighting materials exhibit limitations in achieving stable dispersion in OBDFs, which often results in poor wall-building performance, unstable viscosity and yield point, and poses risks to drilling operation safety. In this paper, a modified API barite (mAB) was prepared for OBDFs by chemically grafting a lipophilic polymer onto API barite. The mAB was designed to partially replace traditional barite as a multifunctional weighting material. Experimental results demonstrated that the addition of mAB significantly improved the stability of OBDFs, exhibiting a density difference of less than 0.132 g/cm³ and a static sag factor (SF) within 0.53. It indicates superior suspension stability compared to conventional weighting materials, ensuring uniform particle distribution under static conditions. The rheological properties remained stable after aging at 180 °C for 16 h without the addition of wetting agent. Additionally, mAB enhanced the compactness of mud cake, forming a denser and thinner mud cake with reduced filtration loss. Meanwhile, the mAB/OBDFs also exhibited excellent lubricity and reservoir protection performance, achieving a sticking coefficient of 0.0437 and a permeability recovery rate of 95 %. These findings suggest that the mAB developed in this study can serve as a novel multifunctional weighting material for OBDFs, providing an effective approach to optimize the comprehensive performance of high-density drilling fluids.</div></div>","PeriodicalId":100578,"journal":{"name":"Geoenergy Science and Engineering","volume":"251 ","pages":"Article 213882"},"PeriodicalIF":0.0,"publicationDate":"2025-04-08","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"143815828","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 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}