Geoenergy Science and Engineering最新文献

{"title":"Numerical simulation on geosystem Thermal-Hydro-Mechanical-Chemical coupling: A review","authors":"Cheng Hsin Liu,&nbsp;Osama Massarweh,&nbsp;Ahmad S. Abushaikha","doi":"10.1016/j.geoen.2025.214059","DOIUrl":"10.1016/j.geoen.2025.214059","url":null,"abstract":"<div><div>With the increasing demand for efficient and safe underground storage of CO<span><math><msub><mrow></mrow><mrow><mn>2</mn></mrow></msub></math></span> and hydrogen, understanding the complex interactions in geological systems has become a key research focus. This review paper provides a systematic overview of numerical simulation techniques used to model multi-field coupling in geosystems, particularly Thermal-Hydro-Mechanical-Chemical (THMC) interactions relevant to Carbon Capture, Utilization, and Storage (CCUS), and Underground Hydrogen Storage (UHS). The review summarizes the governing equations of THMC processes, including stress balance, mass conservation, energy transfer, and chemical reactions, while discussing various coupling schemes such as fully coupled, iterative, and loose approaches for their applicability and computational efficiency. Furthermore, different numerical methods, including continuum media and discontinuum media methods, are evaluated based on their strengths and limitations in multi-field coupling simulations. Challenges such as high computational costs, effective mesh strategies, handling non-linearities, and the integration of advanced technologies like machine learning are highlighted. The paper concludes by identifying key research gaps and suggesting future directions to enhance the accuracy and efficiency of THMC modeling in geological storage systems.</div></div>","PeriodicalId":100578,"journal":{"name":"Geoenergy Science and Engineering","volume":"254 ","pages":"Article 214059"},"PeriodicalIF":0.0,"publicationDate":"2025-06-30","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"144523791","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":"Whole process simulation for efficient proppant placement technology","authors":"Yuxuan Liu ,&nbsp;Liansong Wu ,&nbsp;Jianchun Guo ,&nbsp;Yutong Wu ,&nbsp;Dingli Yan ,&nbsp;Tao Zhang","doi":"10.1016/j.geoen.2025.214045","DOIUrl":"10.1016/j.geoen.2025.214045","url":null,"abstract":"<div><div>This study used computational fluid dynamics (CFD) and discrete element method (DEM) to simulate the whole process of efficient proppant placement technology. The aggregation, dispersion, and deposition behaviors of fiber-proppant clusters in fractures were analyzed, exploring the mechanisms of fiber influence on proppant transport and flowback, and evaluating fracture conductivity. Fiber geometry is modeled with a multi-node structure, simulating fiber flexibility, while an adhesion force model describes surface modification. Model accuracy is validated with sedimentation and transport experiments in fiber suspensions.</div><div>Results show that forming fiber-proppant clusters changes the proppant placement pattern and improves fracture conductivity. During transport, fibers form a mesh that collides with proppants, reducing settling velocity. This promotes clustering and rapid migration to the fracture's far end, increasing the effective proppant placement area. During flowback, fibers interlace among particles, enhancing inter-particle bonding and stabilizing the sand pack. The cluster structure increases proppant porosity, improving oil and gas flow. Compared to the no-fiber case, adding 0.5 % fibers by proppant mass increases proppant placement by 58.63 %, reduces flowback by 17.2 %, and enhances fracture permeability by 1–2 orders of magnitude. Further analysis reveals the effects of fiber concentration, length, injection method, flowback velocity, and viscosity on proppant transport and flowback. The findings provide theoretical insights for optimizing fracturing parameters and developing modified fibers.</div></div>","PeriodicalId":100578,"journal":{"name":"Geoenergy Science and Engineering","volume":"254 ","pages":"Article 214045"},"PeriodicalIF":0.0,"publicationDate":"2025-06-24","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"144480093","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":"Evaluation of a low carbon cement containing calcined clay for oil well cementing","authors":"Vlada Kovalchuk ,&nbsp;Zichen Guo ,&nbsp;Alexey Cheremisin ,&nbsp;Johann Plank","doi":"10.1016/j.geoen.2025.214061","DOIUrl":"10.1016/j.geoen.2025.214061","url":null,"abstract":"<div><div>Well cements play a key role in zonal isolation of wellbores and preventing fluid or gas migration on oil, gas and geothermal wells. Creating an environmentally safe cement with excellent placement and sealing properties presents a major goal of the petroleum and geothermal industry. Unfortunately, common API (American Petroleum Institute) Class oil well cement exhibits a relatively high CO₂ footprint of ∼800 kg CO₂/ton cement. To reduce this significant CO₂ emission in the production of oil well cement, calcined clay (CC) presents an option as a clinker substitute. To this end, in this study, a 50:50 wt/wt. blend of API Class G cement and a calcined clay was investigated with respect to its rheological and thickening behavior and its response to common oil well cement additives (dispersant, retarder, fluid loss additives (FLA)). Experiments were carried out at water-to-cement blend ratios of 0.44 and 0.50, respectively and at low to medium temperatures (27 ^°C, 50 ^°C and 80 ^°C). It was found that calcined clay increases water demand and plastic viscosity while yield point is decreased. Moreover, owed to the lower reactivity of calcined clay, it prolongs thickening time (pumping time) and requires less retarder. The results signify that within the temperature range tested here, this cement blend could achieve excellent pumpability, adjustable thickening times using a lignosulfonate retarder, and low fluid loss rates when a common FLA was applied. Furthermore, a climate-neutral cement exhibiting a CO₂ footprint of ∼450 kg CO₂/ton binder can be achieved, yet it requires a clinker substitution rate of 70 % and increased dispersant dosage. It is demonstrated that calcined clay presents a technically feasible and environmentally preferable alternative to OPC (Ordinary Portland Cement) clinker in oil well cements, and that it can significantly reduce the CO₂ footprint of well cements.</div></div>","PeriodicalId":100578,"journal":{"name":"Geoenergy Science and Engineering","volume":"254 ","pages":"Article 214061"},"PeriodicalIF":0.0,"publicationDate":"2025-06-23","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"144480094","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":"Risk assessment framework for closed wellbore sealing integrity failure under corrosion environment in CO2 geological sequestration","authors":"Haoyan Peng ,&nbsp;Zhao-Dong Xu ,&nbsp;Hongfang Lu ,&nbsp;Zhiheng Xia ,&nbsp;Xin Wang","doi":"10.1016/j.geoen.2025.214064","DOIUrl":"10.1016/j.geoen.2025.214064","url":null,"abstract":"<div><div>Ensuring the long-term sealing integrity of closed wellbores is of crucial significance during the process of CO₂ geological sequestration. However, under the intense corrosive environment, the combined structure of cement plugs and casings may be damaged. This study presents a comprehensive risk assessment framework for sealing integrity failure through a variety of methodology: Initially, a numerical simulation-derived dataset was generated to characterize system behavior under multi-physics coupling conditions. Subsequently, a hybrid machine learning architecture integrating K-means clustering and Radial Basis Function Network (K-RBFN) was developed for remaining life prediction. The failure probability was then quantified via Monte Carlo simulations. Ultimately, risk assessment was achieved through consequence-of-failure weighted probability integration. The analysis results demonstrate that the average failure probability shows a continuous upward trend, and growth rate gradually accelerates, with the probability of failure increasing by 1 per cent after one century. The risk of failure is generally divided into three phases over the course of a century: (1) a latent risk period of 0–30 years (2) a slow growth period of 30–70 years (3) a rapid growth period after 70 years. Finally, through the established risk assessment framework, the failure probability and failure risk under three geological condition scenarios and five reservoir depths scenarios were analyzed. The failure risk assessment framework for the sealing integrity of closed wellbores under the corrosive environment of CO₂ geological sequestration established in this paper can provide a basis for the safety of engineering practice and help prevent potential engineering disasters.</div></div>","PeriodicalId":100578,"journal":{"name":"Geoenergy Science and Engineering","volume":"254 ","pages":"Article 214064"},"PeriodicalIF":0.0,"publicationDate":"2025-06-23","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"144500860","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":"Influence of supercritical CO2 and its aqueous solution on the seepage characteristics of the niutitang shale","authors":"Qiao Lyu ,&nbsp;Yushuai Shi ,&nbsp;Yijun Shen ,&nbsp;Lulu Yan ,&nbsp;Yonggang Ding ,&nbsp;Bingbin Xie ,&nbsp;Gan Feng ,&nbsp;Jingqiang Tan","doi":"10.1016/j.geoen.2025.214065","DOIUrl":"10.1016/j.geoen.2025.214065","url":null,"abstract":"<div><div>The influence of supercritical CO₂ and its aqueous fluids on shale permeability is crucial during supercritical CO₂-enhanced shale gas extraction and CO₂ geological storage in shale gas reservoirs. The research on the effects of supercritical CO₂ on shale permeability, particularly under formation temperature and pressure conditions with and without water, remains insufficiently explored. Therefore, this study conducted one-month immersion experiments involving supercritical CO₂-shale, deionized water-shale, and supercritical CO₂-deionized water-shale interactions at 80 °C and 15 MPa.The influence of supercritical CO₂ on the seepage characteristics of shale under both water-bearing and water-absent conditions was investigated and revealed by examining changes in shale mineral composition and microscopic pore structures. The results indicated that permeability increased by 10 times following deionized water immersion, by 28 % after supercritical CO₂ immersion, and by 86 times following supercritical CO₂+deionized water immersion. Shale minerals experienced varying degrees of chemical dissolution depending on the immersion fluid, with the supercritical CO₂+deionized water solution resulting in the most significant dissolution, far exceeding the effects of the other two fluids. The change in plane porosity was most pronounced following immersion in the supercritical CO₂+deionized water solution, which corresponded to the highest observed permeability increase. Therefore, in the process of supercritical CO₂-enhanced shale gas extraction and carbon sequestration, the combined influence of supercritical CO₂ and formation water on the seepage characteristics of shale formations should be given special attention.</div></div>","PeriodicalId":100578,"journal":{"name":"Geoenergy Science and Engineering","volume":"254 ","pages":"Article 214065"},"PeriodicalIF":0.0,"publicationDate":"2025-06-23","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"144480096","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":"An improved data-driven method for the prediction of elastic properties in unconventional shales from SEM images","authors":"Sai Kiran Maryada,&nbsp;Deepak Devegowda,&nbsp;Chandra Rai,&nbsp;Mark Curtis,&nbsp;David Ebert,&nbsp;Gopichandh Danala","doi":"10.1016/j.geoen.2025.214043","DOIUrl":"10.1016/j.geoen.2025.214043","url":null,"abstract":"<div><div>This paper demonstrates a quick look approach to estimate rock mechanical properties, such as Young's modulus, from SEM images of drill cuttings acquired from several unconventional plays across North and South America. Unlike traditional methods that involve extensive lab measurements or interpretive well logs, our approach leverages image-based analyses, significantly reducing the subjectivity and computational burden often encountered in previous strategies.</div><div>In our analysis, we processed SEM images from 14 plays to extract both textural and shape-based features. Textural attributes such as entropy, homogeneity, contrast, and energy provide insights into the disorder and mineralogical contrasts within the rock. There exist several shape-based features such as area, aspect ratio, circularity, solidity, extent, eccentricity, Euler number, and orientation which can describe the geometric properties of mineral constituents. We utilize both textural attributes and pore aspect ratios and integrate deep learning inputs to construct various predictive models.</div><div>Our models correlate these features with empirically measured Young's modulus values using non-parametric regression. This integrated approach has shown to provide a robust and generalizable model capable of estimating Young's modulus across a diverse set of geological formations with high reliability, even when tested against previously unseen images.</div><div>This study acknowledges that mineralogy and the juxtaposition of various minerals may be unable to fully account for the variations seen in the Young's modulus. Complex pore systems such as lenticular pores may lead to overestimation of elastic moduli. Therefore, the inclusion of both textural and shape attributes as proxies for mineralogy and their spatial arrangement addresses key controls in the mechanical behavior of rock samples, thereby enhancing the model's applicability across varied mineralogical and porosity conditions.</div><div>Our findings indicate that the combination of texture and shape analyses, coupled with machine learning techniques, can efficiently and accurately predict mechanical properties in tight rocks. This method represents a significant advancement over traditional approaches, providing a fast, non-subjective, and computationally efficient tool for preliminary rock mechanics analysis. This work underscores the potential of using SEM image analyses as a powerful tool for rapid screening and detailed rock mechanics studies, moving towards more streamlined and data-driven exploration and production strategies.</div></div>","PeriodicalId":100578,"journal":{"name":"Geoenergy Science and Engineering","volume":"254 ","pages":"Article 214043"},"PeriodicalIF":0.0,"publicationDate":"2025-06-23","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"144500859","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":"Evaluation method of rock mechanical parameters and brittleness characteristics based on rock cuttings fractal theory","authors":"Hu Yang ,&nbsp;Yuhe Shi ,&nbsp;Shengchi Xu ,&nbsp;Ruihua Wei ,&nbsp;Qiao Liu ,&nbsp;Guoliang Liu ,&nbsp;Wei Liang ,&nbsp;Qiuyu Pan ,&nbsp;Xiangguo Liu","doi":"10.1016/j.geoen.2025.214031","DOIUrl":"10.1016/j.geoen.2025.214031","url":null,"abstract":"<div><div>In the process of oil and gas exploration and development, it is fundamental to obtain formation information in time to optimize fracturing construction. To quickly evaluate the rock mechanical parameters, drillability grades and the brittleness index of the formation, this paper introduces the rock cuttings fractal theory. Among them, the rock mechanical parameters include compressive strength, static Young’s modulus, static Poisson’s ratio, cohesion, and internal friction coefficient. In this work, the rock fragment distribution model based on the mass-frequency relationship of the rock was established. Then the rock mechanical parameters and the drillability grades were obtained through uniaxial and triaxial compression tests and drillability measurements. The brittleness index was calculated using Young’s modulus and Poisson’s ratio. After testing, the cores were standardized and screened, and the fractal dimensions of rock cuttings were obtained using the rock fragment distribution model. Based on the above research, the rock mechanical parameters were correlated with the fractal dimension of cuttings and the in-situ logging data, respectively. This resulted in the establishment of the logging interpretation model and the fractal model of the rock cuttings mechanical properties in the study area. The models were implemented on the MZ402 well for the purposes of comparison and validation. The results demonstrate that the margin of error is within 12.37%, and that the error meets the engineering standards. Then, taking the Fengcheng Formation of Ma125 well as an example, the real time evaluation method of the rock mechanical parameters and the brittleness index based on cutting fractal theory while drilling was developed. The fractal dimension and the brittleness index of the rock cuttings were employed as samples to determine the <em>k</em> of 3 using elbow method, and the reservoir engineering sweet spot was divided into three types. Subsequently, the K-means clustering method was employed for the purpose of dividing the engineering sweet spot range. This method facilitates the precise identification of the reservoir engineering sweet spot and provides a foundation for the optimization of the fracturing construction.</div></div>","PeriodicalId":100578,"journal":{"name":"Geoenergy Science and Engineering","volume":"254 ","pages":"Article 214031"},"PeriodicalIF":0.0,"publicationDate":"2025-06-20","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"144480095","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 shear deformation and activation mechanisms of micro-faults in shale formation—Based on a similar physical model for simulating the fracture process of multi-scale fault","authors":"Ziyun Zheng ,&nbsp;Hucheng Deng ,&nbsp;Hao Xu ,&nbsp;Kun Li ,&nbsp;Jianhua He ,&nbsp;Naier Deng ,&nbsp;Yuzhe Li","doi":"10.1016/j.geoen.2025.214058","DOIUrl":"10.1016/j.geoen.2025.214058","url":null,"abstract":"<div><div>The study of shear mechanical response and deformation mechanisms of micro-faults is of significant importance for guiding the safety and efficiency during the CO₂ storage process. In this study, physical simulation experiments of the small deformation were employed. Combined with acoustic emission and digital image correlation methods, the influence of geometric properties on the macro mechanical behavior, damage patterns, and crack propagation of micro-faults were clarified. The shear mechanical mechanisms and tip damage zone characteristics of micro-faults were revealed and finally, the model's comparability was verified. The results indicate that: (1) The experimental model was suitable for simulating shear deformation of micro-faults in shale. It exhibited nonlinear elastic-plastic-frictional characteristics and replicated shear and tensile fracture mechanisms. (2) Faults geometric features controlled the mechanical stability of fractured rock masses. When faults were aligned at 0° or 90° to the shear direction, filled with minerals, and of smaller scale, small-scale shear cracks predominantly developed, leading to stronger overall stability. In contrast, when faults intersected obliquely with the shear direction, large-scale tensile cracks became dominant, making them more prone to shear instability. (3) The fracture types of the experimental model were highly similar to the Riedel shear model, with prevalent Riedel shear (R) and shears parallel to the PDZ (Y). Fault geometric features and stress states controlled the differences in mechanical mechanisms of shear zone formation. (4) Variations in stress-strain differences at the tips of faults with different orientations lead to the formation of complex tip damage zones. The en-echelon fractures formed by the connection of R-shear and Y-shear at different stages exhibit the highest degree of development.</div></div>","PeriodicalId":100578,"journal":{"name":"Geoenergy Science and Engineering","volume":"254 ","pages":"Article 214058"},"PeriodicalIF":0.0,"publicationDate":"2025-06-19","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"144330074","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":"CO2 flow blockage in the near-wellbore zone: Fresh water stimulation against the salting-out effect","authors":"Andrey Afanasyev,&nbsp;Sergey Grechko","doi":"10.1016/j.geoen.2025.214038","DOIUrl":"10.1016/j.geoen.2025.214038","url":null,"abstract":"<div><div>We consider the injection of CO<span><math><msub><mrow></mrow><mrow><mn>2</mn></mrow></msub></math></span> into a saline aquifer through a vertical well. We assume that the well is stimulated by the fresh water treatment to reduce the salting-out effect. We aim at an in-depth investigation of the situations when such a treatment performed prior to the injection of CO<span><math><msub><mrow></mrow><mrow><mn>2</mn></mrow></msub></math></span> can substantially improve the injectivity. By using a radial reservoir model, we simulate the increase in the skin factor caused by the salt precipitation and deposition in the near-wellbore zone. By analyzing the simulation results, we demonstrate that the capillary-driven backflow can magnify the skin factor by orders of magnitude as compared to the case with zero capillary pressure. It can eventually lead to a complete clogging of the porous medium. We introduce the capillary number, which characterizes the influence of the capillary pressure and the intensity of halite deposition. We demonstrate that there exists the critical capillary number separating two qualitatively different scenarios of CO<span><math><msub><mrow></mrow><mrow><mn>2</mn></mrow></msub></math></span> injection presented here for the first time. At the supercritical numbers, the injection cannot be blocked by the salt deposition, although the skin factor monotonically increases with the volume of injected CO<span><math><msub><mrow></mrow><mrow><mn>2</mn></mrow></msub></math></span>. The flow blockage cannot occur in such cases. At the subcritical numbers, the conditions of the complete clogging and zero well injectivity are always reached at a finite time. The fresh water stimulation can only postpone the flow blockage in time, but it cannot exclude such a negative manifestation. The derived estimates for the critical capillary number can be useful for predicting the evolution of the CO<span><math><msub><mrow></mrow><mrow><mn>2</mn></mrow></msub></math></span> well injectivity and mitigating the development of the situations with the complete flow blockage.</div></div>","PeriodicalId":100578,"journal":{"name":"Geoenergy Science and Engineering","volume":"254 ","pages":"Article 214038"},"PeriodicalIF":0.0,"publicationDate":"2025-06-19","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"144470093","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":"Lattice Boltzmann simulations of non-Newtonian fluids in annular geometries","authors":"Espen Jettestuen ,&nbsp;Olav Aursjø ,&nbsp;Eric Cayeux","doi":"10.1016/j.geoen.2025.214039","DOIUrl":"10.1016/j.geoen.2025.214039","url":null,"abstract":"<div><div>A lattice Boltzmann scheme is introduced to model the interaction between a drill string and a non-Newtonian drilling fluid, as fluid–drill–string interactions can give significant force contributions on the drill string. The method uses a fast look-up-table approach to include non-Newtonian rheological behavior. In addition, an immersed boundary method was developed to model the interaction between the fluid and the drill string.</div><div>The method is used on both Newtonian and Quemada fluids for a prescribed drill-string motion. The analysis of the simulations shows that the fluid viscosity had less influence on the integrated forces from the fluid on the drill string, for fairly rapid changes in the drill string center of mass movement, than on the integrated torque on the drill string. A comparison between a quasi two dimensional radial annular geometry and a true three dimensional annular geometry was conducted for a Quemada fluid. Also here we observed that the differences were most pronounced in the integrated torque measurements.</div><div>The fluid motion is complex, but there is a noticeable correlations between the drill-string kinetics and the integrated forces and torques acting on the drill string from the fluid. And, even though this model is too computational demanding to be used in real-time drilling operations, it will make a good basis for data driven reduced order methods that can be used in actual real time applications.</div></div>","PeriodicalId":100578,"journal":{"name":"Geoenergy Science and Engineering","volume":"254 ","pages":"Article 214039"},"PeriodicalIF":0.0,"publicationDate":"2025-06-19","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"144470268","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}