Geoenergy Science and Engineering最新文献

{"title":"Developing robust machine learning techniques to predict oil recovery: A comprehensive field and experimental study","authors":"Wahib Yahya ,&nbsp;Yang Baolin ,&nbsp;Ayman Mutahar AlRassas ,&nbsp;Wang Yuting ,&nbsp;Harith Al-Khafaji ,&nbsp;Riadh Al Dawood","doi":"10.1016/j.geoen.2025.213853","DOIUrl":"10.1016/j.geoen.2025.213853","url":null,"abstract":"<div><div>The volatility in the oil industry driven by significant market demand and notable resource reduction, underscores the crucial requirement for developing a reliable and robust framework to promote oil recovery strategy. This study integrated various robust Machine Learning (ML) algorithms including the Decision Tree (DT), Random Forest (RF), K-Nearest Neighbors (KNN), Support Vector Regression (SVR), Gradient Boosting Regression (GBR), and Multilayer Perceptron (MLP) to predict oil recovery based on field and experimental data. Leveraging these models enhances prediction efficiency and reduces reliance on traditional methods. The performance of the integrated ML models with oilfield and experimental datasets, as well as the impact of multiple input parameters against traditional decline curve analysis (DCA) models, was evaluated. The findings reveal that RF, DT, and GBR models have achieved remarkable performance in contrast with other ML models and traditional DCA methods. The RF model has achieved the highest performance, reflected by a coefficient of determination (R²) value of 0.99 for both field Datasets (A) and experimental Datasets (B). More so, we accurately assess the ML model's robustness and performance by leveraging various metrics performance, including the Bayesian Information Criterion (BIC) and Akaike Information Criterion (AIC), to prove the robust alignment with a remarkable merit of accuracy and complexity across the integrated ML models. Ultimately, the results supported the RF model, which obtained the lowest AIC and BIC values among all the models for oil recovery prediction in Datasets (A) and (B).</div></div>","PeriodicalId":100578,"journal":{"name":"Geoenergy Science and Engineering","volume":"250 ","pages":"Article 213853"},"PeriodicalIF":0.0,"publicationDate":"2025-03-20","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"143679308","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 simulation of pre-Darcy flow in porous media","authors":"Sen Wang ,&nbsp;Liyang Chen ,&nbsp;Qihong Feng ,&nbsp;Tangqi Yang ,&nbsp;Li Chen ,&nbsp;Jiyuan Zhang ,&nbsp;Zhengwu Tao ,&nbsp;Zhengjun Zhu","doi":"10.1016/j.geoen.2025.213852","DOIUrl":"10.1016/j.geoen.2025.213852","url":null,"abstract":"<div><div>Fluid flow in porous media, the theoretical basis of which is a linear law proposed by Darcy, plays a vital role in the energy industry. Much evidence suggests that the correlation of velocity and pressure gradient deviates from Darcy's law in the low-flux region due to the existence of viscous (sticky) boundary layers (also termed pre-Darcy flow). Using Darcy's law to characterize the fluid flow process will impede the efficient exploitation of unconventional resources and energy utilization. However, the pore-scale simulation method of pre-Darcy flow was less reported. Based on microtube experiments, we first built a mathematical model of boundary layer thickness, accounting for the effect of pressure gradient and the viscosity difference of distinct regions. Then we incorporated this model into a lattice Boltzmann framework to simulate the pre-Darcy flow and analyzed the influences of different factors. Our results indicate that the boundary layer thickness and throat aperture dominate the pre-Darcy flow behavior, but the boundary layer viscosity shows less impact. As the boundary layer thickness increases, the apparent liquid permeability of porous media decreases, and the pseudo-threshold pressure gradient alters distinctly. In comparison to classical Darcy flow, the streamlines in the pre-Darcy flow are concentrated in the central region of the throat and may redistribute in some throats under the boundary layer effect. This study advances our understanding of pre-Darcy flow and provides a useful methodology to simulate the process in porous media, which is favorable for understanding the transport physics in shale and tight matrices, and vital for accurate dynamic performance prediction and production optimization in unconventional reservoirs.</div></div>","PeriodicalId":100578,"journal":{"name":"Geoenergy Science and Engineering","volume":"250 ","pages":"Article 213852"},"PeriodicalIF":0.0,"publicationDate":"2025-03-20","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"143704532","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":"Analytical solution of oil and water two-phase Buckley-Leverett equation in inclined stratified heterogeneous reservoirs","authors":"Yuxin Peng ,&nbsp;Yizhong Zhang ,&nbsp;Maolin Zhang ,&nbsp;Bin Ju ,&nbsp;Chaofeng Pang ,&nbsp;Depei Xu","doi":"10.1016/j.geoen.2025.213849","DOIUrl":"10.1016/j.geoen.2025.213849","url":null,"abstract":"<div><div>Water flooding technology is widely applied in medium-to high-permeability reservoirs and plays a crucial role in global oilfield development. The traditional Buckley-Leverett theory provides a theoretical foundation for water flooding. However, its assumptions, such as reservoir homogeneity and the neglect of gravity effects, present limitations in practical applications. In inclined reservoirs, gravity segregation causes the injected water to preferentially advance along the lower part of the reservoir, resulting in the formation of a water cone or water ridge. This reduces vertical sweep efficiency and limits the effective displacement of crude oil. In high-permeability layers, the advance speed of the water front is much faster than in low-permeability layers, leading to a premature breakthrough of the injected water, which reduces the plane sweep efficiency and weakens the water drive effect. Therefore, addressing the issues of gravity effects and reservoir heterogeneity is key to achieving efficient water flooding development. This paper establishes the Buckley-Leverett equation for water flooding in tilted, layered, heterogeneous reservoirs. The implicit solution is derived using fractional flow theory, and the explicit analytical solution is estimated using the Lambert W function. The analytical solution provides guidance for addressing gravity effects and heterogeneity in two-phase flow. A comparison between the analytical results and numerical simulation results for different permeability values and varying reservoir dip angles reveals a good match between the two. The analysis shows that as the reservoir inclination angle and permeability heterogeneity increase, the water drive breakthrough time lengthens, the front advance distance decreases, and micro-displacement efficiency diminishes. The analytical model presented in this paper accurately describes the two-phase flow behavior in reservoirs, considering both gravity differentiation and heterogeneity, and offers valuable insights for optimizing reservoir development strategies. Using this model, the position changes of the water front can be predicted, facilitating the formulation of more effective development plans that enhance sweep and recovery efficiencies.</div></div>","PeriodicalId":100578,"journal":{"name":"Geoenergy Science and Engineering","volume":"251 ","pages":"Article 213849"},"PeriodicalIF":0.0,"publicationDate":"2025-03-20","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"143739899","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 theoretical research on the feasibility of oil storage in sediment voids for salt cavern oil storage (SCOS)","authors":"Xinxing Wei ,&nbsp;Xilin Shi ,&nbsp;Yinping Li ,&nbsp;Shengnan Ban ,&nbsp;Hongling Ma ,&nbsp;Chunhe Yang","doi":"10.1016/j.geoen.2025.213851","DOIUrl":"10.1016/j.geoen.2025.213851","url":null,"abstract":"<div><div>Large-scale underground oil storage is crucial for national development. One effective method, underground salt cavern oil storage (SCOS), is utilized in the US, France, Canada, and Germany, but China currently lacks SCOS facilities. The significant difference between China's lacustrine salt rock and the marine salt rock found elsewhere leads to substantial sediment particles accumulation at the bottom of the caverns, wasting valuable underground storage space. To address this, a new method called sediment void oil storage (SVOS) is proposed. To assess SVOS's feasibility, custom equipment was created and a series of experiments (including oil loss, sediment structure, and component tests) were conducted. An oil loss theoretical model was developed, and the engineering potential of SVOS was analyzed. Results indicate that sediment voids can effectively store oil, with capacity influenced by sediment grain composition and lithology. Three oil loss modes—oil absorption, adhesion, and siltation—affect SVOS's operation, which is also related to sediment pore structure and granular characteristics (such as surface texture, sphericity, and roundness). The maximum oil recovery rates for oil-immersed mudstone and gypsum sediments reached 99.97 % and 99.93 %, respectively. The research contributes valuable insights for advancing underground salt cavern oil storage.</div></div>","PeriodicalId":100578,"journal":{"name":"Geoenergy Science and Engineering","volume":"250 ","pages":"Article 213851"},"PeriodicalIF":0.0,"publicationDate":"2025-03-20","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"143679307","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":"Review of advances and applications of weighted fracturing fluid technology","authors":"Yang Bai ,&nbsp;Lingfeng Wu ,&nbsp;Pingya Luo ,&nbsp;Daoxiong Li ,&nbsp;Yujie Chen","doi":"10.1016/j.geoen.2025.213847","DOIUrl":"10.1016/j.geoen.2025.213847","url":null,"abstract":"<div><div>The increasing demand for energy has prompted exploration into deep and ultra-deep oil and gas reservoirs, where traditional fracturing fluids face limitations under high-temperature and high-pressure conditions. To address these challenges, weighted fracturing fluids have been developed, offering improved friction reduction, enhanced pressure control, and superior proppant transport. This review focuses on the recent advancements in weighted fracturing fluids, including the development of delayed crosslinking technologies, salt-resistant formulations, and high-temperature stable systems. Innovations such as enhanced crosslinkers and the use of nanomaterials have significantly improved the performance of fracturing fluids under extreme conditions, ensuring they maintain optimal viscosity and efficiency in deep well operations. These advancements not only enhance operational efficiency but also contribute to better wellbore stability, making weighted fracturing fluids a crucial technology in the sustainable development of deep and ultra-deep oil and gas resources. This review highlights the key research areas and the future outlook for weighted fracturing fluid technology in meeting the demands of complex reservoir environments.</div></div>","PeriodicalId":100578,"journal":{"name":"Geoenergy Science and Engineering","volume":"250 ","pages":"Article 213847"},"PeriodicalIF":0.0,"publicationDate":"2025-03-19","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"143703944","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 rock-breaking instability characteristics and spin deflection effects of asymmetric water jet impact","authors":"Lipeng He ,&nbsp;Yanbao Liu ,&nbsp;Quanbin Ba ,&nbsp;Peng Weng ,&nbsp;Moujin Lin","doi":"10.1016/j.geoen.2025.213842","DOIUrl":"10.1016/j.geoen.2025.213842","url":null,"abstract":"<div><div>The asymmetric nozzle arrangement can further reduce the size of the water jet drill bit, enhancing its suitability for confined downhole spaces while simultaneously improving rock-breaking efficiency. Existing self-rotating water jet drill bits predominantly utilize combined nozzle arrangements, yet systematic investigations into asymmetric configurations remain limited. Building upon the theory of high-pressure water jet impact dynamics and the spherical cavity expansion model, this study establishes a rock-breaking model for asymmetric water jets, revealing the instability characteristics of rock failure induced by asymmetric water jet impacts. An optimized asymmetric nozzle arrangement was designed, with Fluent simulations employed to determine the optimal nozzle combination for rock fragmentation. Rotational flow field experiments of asymmetric water jets were conducted, and MATLAB-based numerical processing was implemented to validate the rotational-speed-dependent variations in the flow field. Key findings demonstrate that under identical nozzle quantities, asymmetric water jet impacts exhibit more pronounced rock failure instability characteristics along with enhanced rock-breaking width. The optimized angular configuration was identified as 20° (first nozzle), 30° (second nozzle), and 60° (third nozzle). Notably, a significant rotational deviation effect emerges during asymmetric water jet rotation. Both experimental and numerical analyses suggest that beyond 800 rpm, the rotational deviation effect saturates concurrently with intensified water jet atomization. Therefore, rotational speed regulation is critical to prevent rock-breaking efficiency degradation caused by excessive velocities.</div></div>","PeriodicalId":100578,"journal":{"name":"Geoenergy Science and Engineering","volume":"250 ","pages":"Article 213842"},"PeriodicalIF":0.0,"publicationDate":"2025-03-19","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"143679310","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":"Pore-scale insights into CO2-EOR performance in depleted oil reservoirs by miscibility – compared with WAG injection","authors":"Yongqi Wang ,&nbsp;Zhiqiang Fan ,&nbsp;Chunlong Yang ,&nbsp;Hao Weng ,&nbsp;Kun He ,&nbsp;Dayong Wang","doi":"10.1016/j.geoen.2025.213839","DOIUrl":"10.1016/j.geoen.2025.213839","url":null,"abstract":"<div><div>Accurate evaluation of effectiveness and performance of CO₂ miscible flooding in depleted oil reservoirs requires a deep understanding of temporal-spatial evolution in the contact-miscibility-displacement processes between the injected CO₂ and highly-disperse residual oil in heterogeneous porous rocks. In this study, we conducted a pore-scale investigation on CO₂ miscible flooding in a heterogeneous high-water-cut sandstone based on our self-developed lattice-Boltzmann models which have been rigorously validated against theoretical and molecular dynamics analyses. Our results reveal that: 1) Prior to CO₂ breakthrough, CO₂-water displacement dominates three-phase CO₂-oil-water flooding process, creating the preferential displacement path. Under compression, pore water has infiltrated into some adjacent pores from the edge of the preferential displacement path, setting the stage for subsequent CO₂ entry, and accordingly creating necessary conditions for oil-CO₂ contact; 2) After CO₂ breakthrough, more CO₂ penetrates the pores outside the preferential displacement path, strengthening CO₂-oil contact, and gradually expanding local miscible zones. This makes the oil miscible with CO₂ continue to be displaced at a gradually decreasing rate until CO₂ flooding reaches stable state. The efficiency of CO₂ miscible flooding is limited mainly by some specific pore structures where too narrow pore entrance impedes either CO₂-oil contact or fluid migration; 3) The performance advantage of immiscible flooding mode is mainly manifested in the post-breakthrough stage. The final residual oil saturation is significantly decreased compared to immiscible flooding mode, only half of the latter. At this stage, adopting the optimized water-alternating-gas (WAG) injection strategy can enhance oil recovery in immiscible flooding systems to the equivalent level with miscible flooding mode. However, its performance for enhancing the occupancy of CO₂ on pore space oscillates periodically, and is generally inferior to miscible flooding, with extended injection duration increasing costs and smaller CO₂ density reducing storage mass.</div></div>","PeriodicalId":100578,"journal":{"name":"Geoenergy Science and Engineering","volume":"250 ","pages":"Article 213839"},"PeriodicalIF":0.0,"publicationDate":"2025-03-19","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"143679312","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":"Adaptive economic model predictive control with safety constraints for an Electric Submersible Pump Lifted Well","authors":"João Bernardo Aranha Ribeiro ,&nbsp;José Dolores Vergara Dietrich ,&nbsp;Julio Elias Normey-Rico","doi":"10.1016/j.geoen.2025.213831","DOIUrl":"10.1016/j.geoen.2025.213831","url":null,"abstract":"<div><div>We propose an economic adaptive predictive controller based on an output modifier adaptation (EMPC-MA) for controlling an electric submersible pump (ESP) lifted oil well. The modifiers constantly adapted the linear MPC model to handle the plant’s nonlinear behavior. A gradient-based approach approximates the economic function rendering an easy-to-solve quadratic programming (QP) problem. Furthermore, a zone control strategy prioritizes operation within time-varying safety constraints. To handle feasibility issues, artificial and slack variables are used in the terminal constraints. The controller is analyzed coupled with an Extended Kalman Filter based on a static model (SEKF) for estimation purposes since we assume that only a linear dynamic model and a rigorous static model are available for optimization and control purposes, which is the standard in the industry. Thus, the proposed approach does not need to linearize the model at each time step. Finally, the EMPC-MA + SEKF is compared to controllers without safety constraints and adaptation. Results reveal that some form of adaptation is necessary to handle nonlinearities and that pump safety conflicts with profit maximization. Moreover, the proposed controller always tends toward the economic optimal even when disturbances, noise, and parametric uncertainties are present.</div></div>","PeriodicalId":100578,"journal":{"name":"Geoenergy Science and Engineering","volume":"250 ","pages":"Article 213831"},"PeriodicalIF":0.0,"publicationDate":"2025-03-19","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"143679315","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":"Drill tool recognition and detection with SERep-CCNet: A lightweight model approach","authors":"XinYa Wu ,&nbsp;Qi Li ,&nbsp;XiaoRong Gao ,&nbsp;Peng Li ,&nbsp;Shuai Guo","doi":"10.1016/j.geoen.2025.213844","DOIUrl":"10.1016/j.geoen.2025.213844","url":null,"abstract":"<div><div>With the advancement of digital transformation in oilfields, the demand for automation in drilling tool management has become increasingly prominent, serving as a critical driver for improving operational efficiency and achieving refined management. In this context, intelligent inspection robots have been preliminarily deployed in some oilfield management applications. Despite significant progress in object detection algorithms for tool recognition and positioning, the implementation of these technologies on low-power edge devices remains constrained by limited computational resources. This poses challenges for achieving both efficient and accurate tool classification and positioning in resource-constrained environments, thereby limiting the overall level of operational automation. To address this issue, this study proposes an automatic identification method for lightweight drilling tools based on SERep-CCNet. The method is designed to optimize computing resource consumption while maintaining detection accuracy, facilitating efficient deployment on edge devices. Firstly, Squeeze and Excitation Network Version 2 (SENetV2) is integrated into the backbone model to enhance its ability to capture inter-channel dependencies by incorporating multi-layer perceptrons (MLPs), thereby improving feature representation while maintaining high parameter efficiency. Secondly, the high-speed prediction head (RepHead) module is utilized to reconfigure the You Only Look Once (YOLO) head, leveraging the predictive structural advantages of the YOLOX model to improve inference speed, making it particularly suitable for detecting fast-moving objects. Lastly, a cross-scale feature fusion (CCFF) module is introduced to further reduce the network's parameter count and computational complexity without compromising detection accuracy. The experimental results indicate that the lightweight automatic identification method for drilling tools based on SERep-CCNet significantly outperforms the baseline network YOLOv8n. The proposed method reduces the number of parameters (Params) to 1.77M and floating-point operations (FLOPs) to 5.5G, making it highly efficient for edge computing applications. On a custom drilling tool dataset specifically designed for this study, the model achieves a mean Average Precision (mAP) of 69.3 % at IoU thresholds ranging from 0.5 to 0.95 ([email protected]:.95), representing an 11.1 % improvement over YOLOv8n. These results highlight the effectiveness and robustness of SERep-CCNet in addressing the challenges of drilling tool detection in resource-constrained environments.</div></div>","PeriodicalId":100578,"journal":{"name":"Geoenergy Science and Engineering","volume":"250 ","pages":"Article 213844"},"PeriodicalIF":0.0,"publicationDate":"2025-03-19","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"143679413","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":"Investigate on mechanical properties and fracture characteristics of sandstone under different liquid nitrogen treatment states","authors":"Shanjie Su ,&nbsp;Shengcheng Wang ,&nbsp;Peng Hou ,&nbsp;Menglin Du ,&nbsp;Yongjie Ren ,&nbsp;Teng Teng ,&nbsp;Xue Yi ,&nbsp;Xiangxiang Zhang ,&nbsp;Xuan Jiang","doi":"10.1016/j.geoen.2025.213836","DOIUrl":"10.1016/j.geoen.2025.213836","url":null,"abstract":"<div><div>Tight sandstone gas reservoirs can potentially be developed more efficiently with the use of liquid nitrogen (LN₂) fracturing. In order to evaluate the effects of LN₂ freeze-thaw on the physical and mechanical properties, as well as the failure behavior of sandstone, the research involved conducting a range of experiments and numerical simulations on sandstone samples subjected to various LN₂ treatment conditions. The results indicated that the freeze-thaw process had a detrimental effect on the physical and mechanical properties of the sandstone, leading to varied degrees of weakening. The reduction percentages of tensile strength and fracture toughness, which are two key indicators, were found to be 14 % and 21.4 % respectively. Furthermore, there were the bigger degree of volume fracture, multiple branching and tortuous macroscopic cracks and macro fracture surface with larger roughness (increased by15 %) in the freeze-thaw sandstone after destruction. The physical mechanical properties of the freezing sandstone were significantly enhanced, but the complexity of the tensile failure path increased. Numerical simulations indicate that a large temperature gradient leads to the formation of damage zones within the sandstone matrix, and microscopic observations show a significant increase in the length and width of microcracks within the matrix. This indicates that the low temperature of LN₂ fully releases the damage potential of initial defects in sandstone, the damage area participates in the formation of crack propagation paths and increases the randomness of path direction selection, which increases the degree of sandstone volume fracture. The research results are anticipated to offer a scientific foundation and data references for the efficient development of tight sandstone gas resources.</div></div>","PeriodicalId":100578,"journal":{"name":"Geoenergy Science and Engineering","volume":"250 ","pages":"Article 213836"},"PeriodicalIF":0.0,"publicationDate":"2025-03-19","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"143679309","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}