Geoenergy Science and Engineering最新文献

{"title":"The formation mechanisms and management techniques of carbonate scale in CO2-rich coalbed methane wells","authors":"Linan Su ,&nbsp;Qian Wang ,&nbsp;Xiaoming Wang","doi":"10.1016/j.geoen.2025.213780","DOIUrl":"10.1016/j.geoen.2025.213780","url":null,"abstract":"<div><div>Scale deposition during the drainage of coalbed methane (CBM) can significantly damage both coal reservoirs and wellbore utilities, consequently impairing well productivity. The mechanisms underlying scale formation in carbon dioxide (CO₂)-rich CBM wells, however, remain inadequately understood. This study incorporates laboratory experiments with field production data to systemically investigate the formation mechanisms and management techniques for scale in CO₂-rich CBM wells. Initial investigations involved acid dissolution experiments and X-ray diffraction (XRD) analyses of scale samples from two CBM wells to determine their mineral compositions. The results reveal that carbonate scale is the predominant component, with a minor presence of iron oxide scale. Further laboratory experiments were performed to simulate the formation of carbonate scale and examine its controlling factors. The findings demonstrate that the CO₂ partial pressure significantly influences carbonate scale formation. Specifically, higher initial CO₂ partial pressures enhance the dissolution of CO₂ in the water, leading to the generation of more carbonate ions under alkaline conditions. These carbonate ions then react with calcium ions to form CaCO₃ precipitates upon the release of gas pressure. In contrast, lower initial CO₂ partial pressures result in reduced dissolution of CO₂ and a smaller amount of CaCO₃ precipitate following gas pressure release. Field production data from two CBM wells confirm that gas drainage gradually decreases both bottom-hole pressure and CO₂ partial pressure, thus facilitating significant carbonate scale formation. Based on these insights and outcomes of field acid stimulation operations in a CBM well, this study concludes that maintaining higher CO₂ partial pressure during the initial gas drainage stage and utilizing acid treatments are effective methods for preventing and removing carbonate scale.</div></div>","PeriodicalId":100578,"journal":{"name":"Geoenergy Science and Engineering","volume":"249 ","pages":"Article 213780"},"PeriodicalIF":0.0,"publicationDate":"2025-02-17","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"143444518","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":"Semi-dimensionless approach for simulating heat transfer of wellbore to optimize the temperature drop","authors":"Shahab Ghasemi,&nbsp;Saeid Khasi,&nbsp;Apostolos Kantzas","doi":"10.1016/j.geoen.2025.213769","DOIUrl":"10.1016/j.geoen.2025.213769","url":null,"abstract":"<div><div>A reliable prediction of temperature changes in a wellbore is crucial for maximizing the efficacy of the geothermal energy extraction. Modeling such changes across a wellbore is a complex task that poses numerous challenges which require sophisticated numerical models and advanced computational tools. To simulate the real condition of a well, high fidelity simulations are needed due to the large well length to well radius ratio. This limitation causes high computational cost for each run. This study aims to develop and validate a computational model to optimize temperature predictions in geothermal wellbores while reducing computational costs. To reduce such time complexity while keeping calculation error below a reasonable bound, a novel approach is proposed in this paper. To validate the proposed model, an experimental setup of a closed loop system was designed. The experimental data and results obtained from simulations were in a good agreement. Based on the validated model, different controlling parameters of a wellbore were investigated to maximize the heat recovery from a geothermal well. Under two different scenarios from tubing or annulus space, different wellbore depths, and tubing to annulus size ratios, the extracted thermal energies were calculated. The study analyzed a range of injection rates from 0.1 kg/s to 100 kg/s, revealing the intricate relationship between injection rate, heat transfer, and heat loss in fluid-casing systems. The research also considered geothermal power generation systems to assess the potential of generated energy under various operating conditions. Annulus injection consistently resulted in higher outlet temperatures than tubing injection, especially at lower injection rates and deeper wells. The impact of tubing insulation and the tubing-to-annulus area ratio was also analyzed, showing that insulating the tubing significantly increased outlet temperatures by reducing heat loss.</div></div>","PeriodicalId":100578,"journal":{"name":"Geoenergy Science and Engineering","volume":"249 ","pages":"Article 213769"},"PeriodicalIF":0.0,"publicationDate":"2025-02-17","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"143465301","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":"Temperature and pressure characteristics of the deepwater riserless drilling in the polar cold sea","authors":"Zhong Li ,&nbsp;Li-yuan Xing ,&nbsp;Jin-long Wang ,&nbsp;Ren-jun Xie ,&nbsp;Meng-bo Li ,&nbsp;Zhi-ming Yin ,&nbsp;Fu-xin Yu ,&nbsp;Guo-ming Chen ,&nbsp;Xiu-quan Liu","doi":"10.1016/j.geoen.2025.213777","DOIUrl":"10.1016/j.geoen.2025.213777","url":null,"abstract":"<div><div>The riserless drilling system offers superior well control, aiding in the prevention of drilling accidents and compliance with environmental standards in the polar cold sea. Predicting the temperature and pressure in such systems is crucial for operational safety. However, the behavior of drilling temperature and pressure in the polar cold sea remains unclear. This study applies non-Newtonian fluid mechanics and thermodynamic principles, considering the effects of mechanical energy input, hydraulic energy, and rock fragmentation at the drill bit to develop a coupled mathematical model for the temperature and pressure of riserless drilling systems in the polar cold sea. Using state-space methodology and control theory, the temporal distribution patterns of the temperature and pressure were determined. Sensitivity analysis revealed that flow rate significantly affect system temperature, with an optimal value for cooling at the wellbore bottom. Beyond this value, the heat removed by the drilling fluid diminishes. In polar cold sea regions at depths exceeding 600 m, increasing the input temperature of the drilling fluid has minimal effect on maintaining the fluidity of the drilling fluid at the seabed. The influence of cold seawater on the pressure loss of the drilling fluid within the pipeline is minimal, with a pressure increase of 0.9% after stopping the pump for 1 h. In contrast, cold air significantly impacts the pressure loss, resulting in a 12.5% increase after stopping the pump for 1 h. Insulation can maintain the fluidity of the drilling fluid, reducing the opening pump pressure required for operations.</div></div>","PeriodicalId":100578,"journal":{"name":"Geoenergy Science and Engineering","volume":"249 ","pages":"Article 213777"},"PeriodicalIF":0.0,"publicationDate":"2025-02-17","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"143452801","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":"Evaluating and predicting deliverability of natural gas storage sites using stacking machine learning models","authors":"Wei Wei ,&nbsp;Jian Hou ,&nbsp;Xingqi Liu","doi":"10.1016/j.geoen.2025.213771","DOIUrl":"10.1016/j.geoen.2025.213771","url":null,"abstract":"<div><div>Underground natural gas storage (UNGS) is crucial for balancing energy supply and demand, and supporting renewable energy integration. This study evaluates the distribution and deliverability of UNGS sites across the United States from 2014 to 2024, focusing on depleted fields, salt domes, and aquifers. A stacking model that integrates Random Forest, XGBoost, Support Vector Regression, and K-Nearest Neighbors is proposed, with the input parameters including total field capacity, base gas capacity, working gas capacity, surface temperature, site location, and company ownership type. Results show that UNGS sites in the Northeast region have the highest number of storage facilities, whereas the South-Central region exhibits significant capacity and variability. Depleted fields are the most common sites and generally have relatively low median capacities but present the potential for high-capacity storage in specific fields. Interstate pipeline companies and independent operators demonstrate high median deliverability and great variability. The stacking model can achieve superior accuracy across all storage types and outperform individual models. The SHapley Additive exPlanations (SHAP) sensitivity analysis shows that working gas capacity is the dominant factor influencing deliverability, followed by location, base gas capacity, and total field capacity. These findings offer valuable insights for optimizing UNGS operations and guiding strategic energy decisions.</div></div>","PeriodicalId":100578,"journal":{"name":"Geoenergy Science and Engineering","volume":"249 ","pages":"Article 213771"},"PeriodicalIF":0.0,"publicationDate":"2025-02-17","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"143456006","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 research on fracture initiation and propagation behavior in argillaceous silt hydrate reservoirs","authors":"Chengyu Hui ,&nbsp;Yiqun Zhang ,&nbsp;Youkeren An ,&nbsp;Zhaowen Hu ,&nbsp;Xiaoying Zhuang ,&nbsp;Jinshan Wang ,&nbsp;Yu Qin ,&nbsp;Gensheng Li","doi":"10.1016/j.geoen.2025.213774","DOIUrl":"10.1016/j.geoen.2025.213774","url":null,"abstract":"<div><div>Natural gas hydrates hold great promise as an environmentally friendly energy resource, yet the trial production capacity remains an order of magnitude below the threshold for commercial development. Scholars have verified the effectiveness and viability of applying hydraulic fracturing stimulation technology to hydrate reservoirs through laboratory experiments and numerical simulations. However, the unique low-temperature and high-pressure environment of hydrates complicates the initiation and propagation characteristics of hydraulic fractures in unconsolidated argillaceous sediments. Building on previous researches, we conducted true triaxial fracturing experiments using hydrate-bearing sediments (HBS) substitute in both vertical and radial wells. The results indicate that radial well fracturing provides enhanced stimulation effects compared to vertical well fracturing, increasing the stimulated volume and fracture complexity by 27% and 5%, respectively. Due to the weak physical properties of the hydrate reservoir, drilling multiple radial wells in the same horizontal layer causes reservoir degradation to form weak bedding planes, inducing fractures to initiate and propagate in the horizontal direction. Employing high injection rates and low-viscosity fracturing fluids can boost fracture complexity by approximately 10%, facilitating proppant placement and transport and thereby maintaining the efficient, long-term, and safe development of hydrates. Our study offers insights and theoretical frameworks to facilitate the implementation of hydraulic fracturing techniques in the exploitation of hydrate reservoirs.</div></div>","PeriodicalId":100578,"journal":{"name":"Geoenergy Science and Engineering","volume":"249 ","pages":"Article 213774"},"PeriodicalIF":0.0,"publicationDate":"2025-02-17","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"143452804","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":"Potential kinetic effects of wax on clathrate hydrate formation: A review","authors":"Jiaqiang Jing ,&nbsp;Hang Yang ,&nbsp;Jie Sun ,&nbsp;Jiatong Tan","doi":"10.1016/j.geoen.2025.213765","DOIUrl":"10.1016/j.geoen.2025.213765","url":null,"abstract":"<div><div>Waxes and hydrates may coexist in oil-gas-water multiphase mixed transport pipelines. They all occur at low temperatures and may have kinetic influences mutually. The impact of waxes on hydrates has been a topic of considerable discussion, yet a consensus has not been reached. Recently published studies have compiled and found that the uncertainty may be attributed to the inherent complexity of oil-water mixtures. Consequently, the impact of waxes on the entirety of the hydrate formation process in the presence/absence of emulsifiers is deliberated, and the effect of emulsifiers on hydrate formation in the presence of waxes is discussed by comparison. The wax on hydrate nucleation is discussed by analyzing the induction period, the microstructure of emulsion and hydrate. The growth and aggregation properties are inferred by gas transformation, adhesion forces, and rheological properties. Further, the effect of waxes on hydrate formation is discussed at the molecular scale. The results show that waxes have a negative effect on the whole process of hydrate formation under the stable W/O emulsion system. In contrast, waxes have a promoting effect on hydrate formation in the O/W emulsion system under high-content conditions. The impact of waxes on hydrate formation remained uncertain in the absence of emulsifiers due to the disordered distribution of oil and water when no emulsifier was present. Eight potential forms of wax crystals in oil-water mixtures are summarized, and their influence on hydrate formation is discussed. The coexistence of multiple forms of wax will lead to complex results in terms of the effect of wax on hydrates. Existing research's shortcomings and challenges are emphasized, which can be expected to allow rapid development of this direction.</div></div>","PeriodicalId":100578,"journal":{"name":"Geoenergy Science and Engineering","volume":"249 ","pages":"Article 213765"},"PeriodicalIF":0.0,"publicationDate":"2025-02-17","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"143453196","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":"Uncertainty analysis for CO2 geological storage due to reservoir heterogeneity based on stochastic numerical model","authors":"Lisong Zhang ,&nbsp;Menggang Jiang ,&nbsp;Qingchun Yang ,&nbsp;Yinghui Bian ,&nbsp;Chuanyin Jiang","doi":"10.1016/j.geoen.2025.213772","DOIUrl":"10.1016/j.geoen.2025.213772","url":null,"abstract":"<div><div>Due to uncertainties of permeability and porosity in actual heterogeneous saline aquifers, CO₂ geological storage exhibit the significant uncertainties for the critical parameters, such as horizontal migration distance, CO₂ dissolved amount, gas CO₂ amount per unit distribution volume and pore pressure. To investigate uncertainties for CO₂ storage, Sequential Gaussian method was introduced to generate stochastic fields of porosity and permeability, under which the governing equation for CO₂ geological storage was re-derived, to establish the stochastic numerical model, which was validated by theoretical solution by comparing CO₂ horizontal migration distance. By conducting the stochastic simulation, the effect of heterogeneity on CO₂ storage was concluded with the faster horizontal migration rate, farther horizontal migration distance, higher CO₂ dissolved amount, lower gas CO₂ amount per unit distribution volume and relatively smaller pore pressure compared to homogeneous model, indicating that the homogeneous model may be not accurate enough and would result in significant deviations in predicting the critical parameters for CO₂ storage in actual heterogeneous aquifers. Furthermore, the total of 100,000 times of stochastic numerical simulations was performed to determine uncertainties of critical parameters for CO₂ storage. The probability distributions and the expected values were obtained for critical parameters for CO₂ storage, and the confidence intervals of critical parameters were obtained under the confidence level of 95 %.</div></div>","PeriodicalId":100578,"journal":{"name":"Geoenergy Science and Engineering","volume":"249 ","pages":"Article 213772"},"PeriodicalIF":0.0,"publicationDate":"2025-02-17","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"143444516","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":"Friction characteristics and grinding model of cemented carbide for drilling bit affected by WC grain size and rotational speed","authors":"Weiguo Zhang ,&nbsp;Jun Tian ,&nbsp;Hongbo Liu ,&nbsp;Jinyun Yuan ,&nbsp;Nengzhong Lei ,&nbsp;Yulin Wang ,&nbsp;Xiang Sun ,&nbsp;Xiaowei Wu ,&nbsp;Junpeng Xu","doi":"10.1016/j.geoen.2025.213770","DOIUrl":"10.1016/j.geoen.2025.213770","url":null,"abstract":"<div><div>Rotary drilling remains a common geological drilling technique, and drilling costs have increased significantly due to the wear of cemented carbide (WC/Co) drill bits. Material selection and optimization of drilling parameters are effective ways to reduce bit wear. To investigate the wear pattern of cemented carbide materials for drill bits applicable to different soft and hard formations under different rotational speeds, and to provide references for reducing the wear of drill bits from the perspectives of material selection and drilling rotational speed selection. In this study, the effect on WC/Co drill bit wear rate (<em>W</em>_<em>r</em>) of WC grain size and rotational speed is investigated. The findings indicate a positive correlation between <em>W</em>_<em>r</em> and rotational speed, whereas the coefficient of friction (<em>f</em>_<em>c</em>) displays a negative correlation with rotational speed. The G0.5, G1, and G1.5 have the highest wear rates at rotational speeds of up to 500 r/min, which are 0.38 %, 0.55 % and 0.63 %, respectively. The results demonstrated a positive correlation between the grain size of WC in WC/Co and <em>W</em>_<em>r</em>. The <em>W</em>_<em>r</em> of G1.5 reaches the maximum at rotational speeds (i.e.,100, 200, 300, 400, and 500 r/min), with 0.19 %, 0.21 %, 0.29 %, 0.52 %, and 0.63 %, respectively. The WC/Co material, which exhibits a fine WC grain size, displays a low <em>f</em>_<em>c</em>. It is observed that as the rotational speed and WC grain size increased, the width and depth of the wear marks also increased. The oxide layer produced by frictional heat generation has a friction-reducing effect at low speeds, but at high speeds, the oxide layer will peel off. Compared to WC/Co with coarse WC grains, fine WC grains retain their particle integrity during wear, this results in a reduction in the temperature rise caused by the friction of WC fragments. A grinding model of WC/Co is constructed, which better predicts the change rule of <em>W</em>_<em>r</em> with rotational speed and WC grain size. The results offer a theoretical foundation for the selection of drill bit materials and drilling process parameters.</div></div>","PeriodicalId":100578,"journal":{"name":"Geoenergy Science and Engineering","volume":"249 ","pages":"Article 213770"},"PeriodicalIF":0.0,"publicationDate":"2025-02-17","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"143452800","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 new interpretation approach to detect induced fracture opening with pressure transient analysis of step-rate tests","authors":"Joshua Mugisha ,&nbsp;Anton Shchipanov ,&nbsp;Alf Midtbø Øverland","doi":"10.1016/j.geoen.2025.213759","DOIUrl":"10.1016/j.geoen.2025.213759","url":null,"abstract":"<div><div>Step-Rate Test (SRT) is a way to monitor induced fracturing and fracture opening after it was created. Nowadays, many modern wells are equipped with permanent downhole gauges (PDG) that provide real-time measurements such as pressure and temperature that has revolutionized well testing and monitoring. Permanent pressure monitoring and flow-metering enable interpretation of flowing periods in combination with shut-ins, providing insights from the start of operations and widely used for monitoring of induced fracturing and fracture opening through time-lapse SRTs during injection operations. This paper proposes a new interpretation approach for early detection of induced fracturing by developing further existing SRT analysis practices using the advantage of permanent pressure measurements available now in many wells.</div><div>This paper proposes a new SRT interpretation approach for early detection of induced fracturing or fracture opening using Pressure Transient Analysis (PTA). Proposed PTA-SRT approach is based on step-by-step technique introduced previously for reservoir flow evaluations and is developed further and tested in this study for induced fracture monitoring using a combination of existing analytical and numerical flow simulations. The flow simulations have revealed a new specific signature of induced fracture creation or opening in the Bourdet derivative of flowing transients, which is further used as theoretical basis of the PTA-SRT approach. This study suggests the concept of uncertainty envelope for practical applications of PTA-SRT for on-the-fly fracture monitoring separating the signature of induced fracture from measurement noise. The PTA-SRT approach has been tested and verified on a real SRT data from a vertical well injecting water in a sandstone reservoir confirming the capabilities of the PTA-SRT approach for early detection of induced fracture opening. The paper concludes with potential application areas of the interpretation approach for well and reservoir containment monitoring in different industries including automated workflows.</div></div>","PeriodicalId":100578,"journal":{"name":"Geoenergy Science and Engineering","volume":"249 ","pages":"Article 213759"},"PeriodicalIF":0.0,"publicationDate":"2025-02-15","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"143436563","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":"A novel stochastic simulation method for sedimentary facies based on the generative adversarial network with a spatially-adaptive conditioning module and comprehensive attention mechanisms","authors":"Lei Liu ,&nbsp;Dali Yue ,&nbsp;Wei Li ,&nbsp;Degang Wu ,&nbsp;Jian Gao ,&nbsp;Qian Zhong ,&nbsp;Wurong Wang ,&nbsp;Jiagen Hou","doi":"10.1016/j.geoen.2025.213758","DOIUrl":"10.1016/j.geoen.2025.213758","url":null,"abstract":"<div><div>Accurate characterization of sedimentary facies using limited observations is essential for reservoir development. Subsurface observations are crucial inputs for sedimentary facies simulation, serving both as constraints and indispensable prior knowledge. Effectively preserving and utilizing this valuable prior information during the simulation is an urgent issue. Furthermore, the complexity and variability of subsurface facies models present significant challenges to comprehensively focus on critical features and accurately reproduce geological patterns. In this work, we propose an innovative stochastic simulation method for complex sedimentary facies based on the generative adversarial network (GAN) integrating with a spatially-adaptive conditioning module (SPACM) and comprehensive attention mechanisms (CAMs), named CSPA-CAGAN. The SPACM is specifically designed to adaptively modulate extracted geological feature maps based on the layout of sparse conditioning data, thereby adequately propagating the conditioning information through the network and significantly enhancing conditional facies modeling. Additionally, CAMs, comprising various attention mechanisms, are employed to comprehensively capture key spatial patterns, feature channels, and multi-scale coordinate features, improving the ability to characterize complex sedimentary facies. The performance of the proposed method is validated through experiments on fluvial and deltaic reservoirs. Statistical metrics, including facies proportion distributions, multi-dimensional scaling plots, connectivity functions, and variograms, are employed to quantitatively evaluate the generated realizations. The evaluation results demonstrate that the realizations successfully reproduce various geological patterns, proving that our method can accurately reconstruct heterogeneous sedimentary facies models with superior pattern diversity.</div></div>","PeriodicalId":100578,"journal":{"name":"Geoenergy Science and Engineering","volume":"249 ","pages":"Article 213758"},"PeriodicalIF":0.0,"publicationDate":"2025-02-14","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"143465300","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}