Geoenergy Science and Engineering最新文献

{"title":"Recent applications of carbonic anhydrase and its mimics in CO2 capture and utilization technologies","authors":"Yan Xie ,&nbsp;Michelle Tiong ,&nbsp;Qi Liu ,&nbsp;Chunkai Wang ,&nbsp;Wanzhen Xue ,&nbsp;Tong Wu ,&nbsp;Shengwei Zhang ,&nbsp;Ning Hao","doi":"10.1016/j.geoen.2025.213958","DOIUrl":"10.1016/j.geoen.2025.213958","url":null,"abstract":"<div><div>The continued rise in atmospheric carbon dioxide (CO₂) concentrations, driven primarily by fossil fuel combustion, remains as a main contributor to global climate change. Carbon Capture, Utilization, and Storage (CCUS) technologies, particularly CO₂ capture approach, represents an essential strategy to mitigate this challenge. Among these methods, Carbonic anhydrase (CA), a natural enzyme catalyzing CO₂ hydration into bicarbonate, has emerged as a promising candidate for efficient CO₂ capture and conversion. Despite its high catalytic efficiency, its industrial application is limited by challenges related to stability and high production costs at large scales. To overcome these limitations, researchers have explored three primary strategies, which are CA modification, immobilization techniques, and the development of carbonic anhydrase mimics (CAMs). These approaches collectively enhance enzymatic stability, reusability and operational flexibility under industrial conditions. This review systematically examines the biological characteristics of CA, analyzes how the immobilization materials influence the catalytic performance, and synthesize the recent advancements in CO₂ capture and conversion technologies. Finally, the potential of CAMs as next-generation carbon reduction technologies is evident. Improving ligand and metal center design is essential to optimize their durability and catalytic performance, making this a key frontier for future research in sustainable carbon management.</div></div>","PeriodicalId":100578,"journal":{"name":"Geoenergy Science and Engineering","volume":"252 ","pages":"Article 213958"},"PeriodicalIF":0.0,"publicationDate":"2025-05-06","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"143927970","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 study on the mechanical properties of sandstone under different temperatures and cooling methods","authors":"Jinsong Zhang ,&nbsp;Jialing Huang ,&nbsp;Yishun Bu ,&nbsp;Yu Lu ,&nbsp;Xiangyang Zhang","doi":"10.1016/j.geoen.2025.213960","DOIUrl":"10.1016/j.geoen.2025.213960","url":null,"abstract":"<div><div>To explore the damage mechanism of sandstone mechanical properties under the coupling effect of high temperature and water cooling during the geothermal exploitation of hot dry rock, this paper conducts comparative experiments of natural cooling and water cooling on sandstone treated at 200–600 °C, and combines uniaxial compression mechanical tests with microscopic morphology analysis to systematically reveal the macroscopic and microscopic damage evolution laws of sandstone under the combined effect of temperature and cooling. The research shows that with the increase of temperature, the peak stress and elastic modulus of sandstone show a phased decline, and 400 °C is the threshold temperature for the sudden change of mechanical properties. Water cooling aggravates thermal damage compared with natural cooling. At 600 °C, the peak stress reduction of water-cooled samples is 1.8 times that of naturally cooled samples, and the volume expansion rate increases by 37 %. Microscopic analysis indicates that water cooling induces thermal mismatch stress between mineral particles, which leads to a more significant increase in the proportion of transgranular cracks at 600 °C. The established polynomial model can accurately characterize the temperature dependence of mechanical parameters. The research results provide a theoretical basis for the regulation of thermal fracturing in hot dry rock reservoirs and the assessment of wellbore stability.</div></div>","PeriodicalId":100578,"journal":{"name":"Geoenergy Science and Engineering","volume":"252 ","pages":"Article 213960"},"PeriodicalIF":0.0,"publicationDate":"2025-05-05","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"143911521","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":"Intelligent prediction of favorable shale oil areas based on deep learning and batch normalization","authors":"Sun Shihui ,&nbsp;Wang Yilin ,&nbsp;Sun Xiaofeng ,&nbsp;Chang Huilin ,&nbsp;Wang Biao","doi":"10.1016/j.geoen.2025.213955","DOIUrl":"10.1016/j.geoen.2025.213955","url":null,"abstract":"<div><div>The evaluation and prediction of favorable zones are essential for accurate shale oil resource assessments and achieving profitable development. The geological conditions of GL shale oil are complex, highly heterogeneous, and have unclear geophysical response characteristics, creating difficulties in classifying and evaluating enriched shale oil layers. This study uses productivity as the primary criterion for favorable-zone evaluation. By leveraging the nonlinear mapping capabilities of deep learning algorithms, we establish an intelligent prediction method for identifying favorable zones that functions based on well fracturing segment productivity as labeled data and seismic attributes as feature data. This method calculates the contribution of individual fracturing intervals based on oil-phase tracer concentrations, decomposing the total oil production of a single well into the productivity of each fracturing segment. The connection between fracturing segment productivity and seismic attributes depends on geodetic coordinates derived from borehole trajectory survey calculations. We analyze the seismic attributes that most strongly influence productivity to develop an intelligent prediction and evaluation model for favorable shale oil zones. This model integrates deep learning techniques and batch normalization algorithms to comprehensively explore the relationships between multiple seismic attributes and productivity. This proposed approach enables efficient and intelligent prediction of favorable zones in the shale oil G9 layer, achieving an accuracy rate of 82.61 % for favorable-zone predictions based on the productivity of completed wells. The results of this study may provide theoretical and technical support for optimizing well location deployment, well numbers, and horizontal segment length to effectively improve the drilling success rates of high-quality reservoirs. They also offer significant guidance and practical application value for the efficient development of shale oil.</div></div>","PeriodicalId":100578,"journal":{"name":"Geoenergy Science and Engineering","volume":"252 ","pages":"Article 213955"},"PeriodicalIF":0.0,"publicationDate":"2025-05-05","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"143916861","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":"Well interference analysis based on transient-flow analysis using an improved embedded discrete fracture model","authors":"Biao Zhou ,&nbsp;Zhiming Chen ,&nbsp;Zhigang Song ,&nbsp;Bin Wang ,&nbsp;Kamy Sepehrnoori","doi":"10.1016/j.geoen.2025.213950","DOIUrl":"10.1016/j.geoen.2025.213950","url":null,"abstract":"<div><div>The use of hydraulic fracturing technology has led to common issues such as well interference. Currently, there is a lack of comprehensive analysis of the pressure transient behaviors considering natural fractures and well interference. This may lead to an inability to accurately estimate reservoir and fracture parameters. To address this limitation, an improved modified embedded discrete fracture model (AEDFM) was used to study well interference based on the pressure transient behaviors of multi-stage fractured horizontal wells (MFHW).</div><div>The transient correction factor for the transmissibility of oil–water two-phase flow in the EDFM was modified to accurately simulate the transient pressure behavior under the influence of two-phase flow. The model was validated by pressure matching with the standard software package KAPPA. Then, the well interference coefficient was defined to quantitatively analyze the impact of well interference. The phenomenon of well interference has been examined under a range of interference mechanisms, including interference through the matrix, natural fractures, connected hydraulic fractures and connected natural fractures. Furthermore, it has been demonstrated that the production rate exerts the most significant influence on well interference, with the well interference coefficient achieving a maximum of 81.5 % when the production rate ratio is elevated to 5. Finally, a field application was conducted using the type-curve analysis method, and the well interference coefficient in the late testing stage was 18.4 %, demonstrating the practicality of the proposed model. This paper provides a new insight into the analysis of well interference.</div></div>","PeriodicalId":100578,"journal":{"name":"Geoenergy Science and Engineering","volume":"252 ","pages":"Article 213950"},"PeriodicalIF":0.0,"publicationDate":"2025-05-05","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"143949111","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 the \"multi branch relay\" chemical flooding mode for improving oil recovery in high water content and high heterogeneity reservoirs","authors":"Peng Li ,&nbsp;Leiting Shi ,&nbsp;Xiao Wang ,&nbsp;Hongya Gao ,&nbsp;Shan Ge ,&nbsp;Shikai Wang","doi":"10.1016/j.geoen.2025.213951","DOIUrl":"10.1016/j.geoen.2025.213951","url":null,"abstract":"<div><div>The issues associated with high water cut and highly heterogeneous reservoirs, such as strong heterogeneity, rapid water cut increase, and the insufficient or difficult mobilization of medium- and low-permeability layers, are addressed. Based on the resistance and residual resistance factors of chemical agents, branched polymers, amphiphilic polymers, and polymer surfactants are classified as high residual resistance, medium resistance, and low resistance systems, respectively. A \"multi-branch relay\" chemical flooding model is proposed to improve the recovery factor. Through physical and microscopic oil displacement experiments, the dynamic characteristics of the flooding process, as well as the mechanisms of microscopic expansion of sweep efficiency and residual oil mobilization, are analyzed. The physical oil displacement experiments show that the \"high residual resistance-medium resistance-low resistance-medium resistance\" combination improves the recovery factor by 6.40% compared to continuous polymer flooding. The dynamic characteristics of displacement are observed to have an increasing trend in the production pressure differential, reaching a stable-like state, while the water cut decreases in a \"V\" shape. Microscopic oil displacement experiments indicate that the \"high residual resistance-medium resistance-low resistance- medium resistance\" combination improves the sweep efficiency by 33.24% over water flooding. The primary mechanism for mobilizing residual oil involves the segmentation of continuous residual oil patches and the promotion of scattered residual oil reaggregation to form an oil wall. The \"multi-branch relay\" chemical flooding model effectively addresses the difficulties in initiating and mobilizing oil from medium- and low-permeability layers.</div></div>","PeriodicalId":100578,"journal":{"name":"Geoenergy Science and Engineering","volume":"252 ","pages":"Article 213951"},"PeriodicalIF":0.0,"publicationDate":"2025-05-05","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"143922851","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 structure analysis by mercury intrusion and nitrogen adsorption after LN2 treatment: An experimental study for granite rocks in ‘O’ field, Kazakhstan","authors":"Sotirios Nik Longinos","doi":"10.1016/j.geoen.2025.213953","DOIUrl":"10.1016/j.geoen.2025.213953","url":null,"abstract":"<div><div>This research investigates for first time granite from almost (4000 m) from an active oil field in west Kazakhstan (‘O’ field), the effects of LN₂ treatment on the pore structures of granite aiming at an environmentally friendly hydraulic fracturing process. Mercury Intrusion Porosimetry (MIP) and Low-Pressure Nitrogen Gas Adsorption (LN2GA) isotherms were used to assess how varying freezing durations and freeze-thaw cycles affect the pore characteristics. Total pore volume, assessed through nitrogen adsorption and mercury intrusion methods, grew with more prolonged exposure durations, reaching maximum levels in samples subjected to 20 freezing-thawing cycles. The widening of the hysteresis loop suggested an increase in average pore size. The surface area of pores expands during freezing, indicating the formation of more small pores. Freezing-thawing cycles form macropores and pore networks better as temperatures increase than the freezing time method.</div></div>","PeriodicalId":100578,"journal":{"name":"Geoenergy Science and Engineering","volume":"252 ","pages":"Article 213953"},"PeriodicalIF":0.0,"publicationDate":"2025-05-04","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"143916940","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 semi-analytical model considering two-phase flow and full thermal–hydraulic–mechanical (THM) coupling for the mechanical response of formation in hydrate production","authors":"Jiajia Huang ,&nbsp;Mingjing Jiang ,&nbsp;Shasha Song ,&nbsp;Huaning Wang","doi":"10.1016/j.geoen.2025.213943","DOIUrl":"10.1016/j.geoen.2025.213943","url":null,"abstract":"<div><div>Marine natural gas hydrate exploitation involves complex thermal–hydraulic–mechanical–chemical (THMC) coupling. However, the influence of the full hydraulic–mechanical (HM) coupling on formation stability in hydrate exploitation is absent in the published analytical/semi-analytical models. This study proposed a new semi-analytical model with full THM coupling and two-phase flow to analyze the influence of the full HM coupling and some key factors on formation stability in hydrate production by depressurization, heat injection and their combination, focusing on the full THM coupling, especially for the influence of the mechanical field on pore pressure due to volumetric strain change rate and variations in permeability/porosity. The semi-analytical model is validated by a finite element model with the same conditions, experimental results and complex numerical model. The full HM coupling has a significant influence on the mechanical response of the formation. Compared with the solutions of partial HM coupling, the pore pressure increases by 23.43 % relative to the pressure gradient, incremental radial displacement decreases by 46.89 %. Wellbore stability is minimally influenced by HM coupling due to the constant production pressure, whereas stability at the dissociation front is improved as a result of HM coupling.</div></div>","PeriodicalId":100578,"journal":{"name":"Geoenergy Science and Engineering","volume":"252 ","pages":"Article 213943"},"PeriodicalIF":0.0,"publicationDate":"2025-05-03","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"143943306","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":"Fracture initiation and propagation behaviours of supercritical CO2 enhanced fracturing in layered shale of horizontal wells","authors":"Lei Han ,&nbsp;Xian Shi ,&nbsp;Hongjian Ni ,&nbsp;Xin Chang ,&nbsp;Vladimir Poplygin ,&nbsp;Bo Wang ,&nbsp;Botao Zhang","doi":"10.1016/j.geoen.2025.213938","DOIUrl":"10.1016/j.geoen.2025.213938","url":null,"abstract":"<div><div>Globally, shale oil/gas has become an important alternative energy for conventional oil and gas. The potential advantages of supercritical CO₂ (ScCO₂) make it an ideal substitute for hydraulic fracturing, which is used for shale reservoir stimulation. However, its poor proppant carrying capacity and viscous fingering limit its application. This article proposes an experimental method for ScCO₂ enhanced fracturing, which is divided into three stages: first, ScCO₂ fracturing is used to form microcracks around the wellbore (at which point the rock is not fractured); Afterwards, maintain the pressure constant, stop the pump and soak the well, use CO₂ to react with the rock to soak the surrounding area, reduce the fracturing pressure, and increase the energy of the formation; Finally, hydraulic fracturing is used to induce fractures and increase their width and complexity. Research has shown that: (1) Compared with ScCO₂ fracturing, the fracture pressure of ScCO₂ enhanced fracturing is reduced by 13 %. (2) Compared with hydraulic fracturing and ScCO₂ fracturing, the fracture morphology of ScCO₂ enhanced fracturing is more complex, and can produce approximate “cross fractures”, indicating that ScCO₂ enhanced fracturing may break through the constraints of geostress and generate the complex fracture network desired on site. (3) The total length of ScCO₂ fracturing fractures is about 1.34 times that of hydraulic fracturing, and the total length of ScCO₂ enhanced fracturing fractures is about 3.48 times that of hydraulic fracturing, with more branching fractures appearing. (4) The fracture width of ScCO₂ enhanced fracturing is 1.93 times that of hydraulic fracturing and 4.10 times that of ScCO₂ fracturing. In summary, ScCO₂ enhanced fracturing has significant advantages in increasing fracture complexity, expanding fracture width, and reducing fracture pressure. The research results have demonstrated the technical feasibility of ScCO₂ enhanced fracturing, which is of great significance for shale gas development.</div></div>","PeriodicalId":100578,"journal":{"name":"Geoenergy Science and Engineering","volume":"252 ","pages":"Article 213938"},"PeriodicalIF":0.0,"publicationDate":"2025-05-02","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"143935103","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":"Sensitivity analysis and optimization of operational parameters during CO2 huff and puff in the shale oil reservoir: A case study","authors":"Zhizeng Xia ,&nbsp;Hongjun Yin ,&nbsp;Xuewu Wang ,&nbsp;Jing Fu ,&nbsp;Dayou Shi","doi":"10.1016/j.geoen.2025.213948","DOIUrl":"10.1016/j.geoen.2025.213948","url":null,"abstract":"<div><div>To investigate the comprehensive impact of operational parameters on the performance of CO₂ huff and puff (CO₂-HNP) in shale oil reservoirs, the workflows of parameter sensitivity analysis and optimization were proposed. Firstly, three objective functions reflecting the different aspects of CO₂-HNP's performance were proposed and simulation schemes were designed using Latin hypercube sampling method. Subsequently, sensitivity analysis was conducted using Sobol method for each objective function. Finally, the operational parameters were optimized for each objective function using the particle swarm optimization algorithm. Moreover, a field case of CO₂-HNP was presented. The results demonstrate that: 1) The CO₂-HNP timing and CO₂ injection amount have the greatest influence on the oil recovery degree. The CO₂ injection amount has the greatest influence on the CO₂ storage ratio. Moreover, the CO₂-HNP timing and the soaking time have significant influence on the composite indicator of the oil recovery degree and CO₂ storage ratio. There exist certain interactions among these operational parameters. 2) Early CO₂-HNP timing, large CO₂ injection amount, long soaking time, and high injection rate are conducive to enhancing the oil recovery degree. While late CO₂-HNP timing, small CO₂ injection amount, long soaking time, and medium injection rate are conducive to increasing the CO₂ storage ratio. 3) Early CO₂-HNP timing, large CO₂ injection amount, long soaking time, and medium CO₂ injection rate are conducive to achieving an optimal equilibrium between the oil recovery and CO₂ storage ratio. 4) Compared with the field data, the cumulative oil production is increased by 1520t under the global optimal parameter combination, showing a significantly enhanced development effect.</div></div>","PeriodicalId":100578,"journal":{"name":"Geoenergy Science and Engineering","volume":"252 ","pages":"Article 213948"},"PeriodicalIF":0.0,"publicationDate":"2025-04-29","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"143902556","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":"Numerical simulation of CO2-SO2 co-sequestration in shale gas reservoirs coupled with enhanced gas recovery at reservoir scale","authors":"Danqing Liu ,&nbsp;Zexing Zhang ,&nbsp;Qi Yu ,&nbsp;Ramesh Agarwal ,&nbsp;Yilian Li","doi":"10.1016/j.geoen.2025.213939","DOIUrl":"10.1016/j.geoen.2025.213939","url":null,"abstract":"<div><div>Due to the favorable affinity of SO₂ adsorption on shale over CO₂ and CH₄, CO₂-SO₂ co-sequestration in shale gas reservoirs coupled with enhanced natural gas recovery has been proposed recently. To evaluate the feasibility of injection impure CO₂ containing SO₂ for shale gas recovery and CO₂ storage at reservoir scale, we established a field-scale shale gas production model which incorporates multiple fluid flowing mechanisms including the slip flow, viscous flow, Knudsen diffusion and also gas adsorption/desorption, based on accurate CO₂-SO₂-CH₄ mixtures properties prediction. Results show that the presence of 3 mol% SO₂ in the CO₂ stream can increase CH₄ production by 9.55 % via increasing the pressure differential of the production well and promoting the migration of CO₂ with displacement and replacement and it has negligible impact on CO₂ sequestration. The CH₄ production capacity increases with the SO₂ content in the CO₂ stream. However, excessive adsorption of SO₂ over CO₂ on shale is not advantageous for shale gas recovery because high adsorption of SO₂ in the CO₂ stream can alleviate the pressure build-up induced by fluid injection and hinder SO₂ migration. In addition, larger reservoir pressure and temperature, artificial fracture half-length, fracture permeability and lower reservoir permeability can exaggerate the positive impact of SO₂ on CH₄ production. The increase of the aforementioned factors plays negative role in CO₂ storage security with the exception of temperature.</div></div>","PeriodicalId":100578,"journal":{"name":"Geoenergy Science and Engineering","volume":"252 ","pages":"Article 213939"},"PeriodicalIF":0.0,"publicationDate":"2025-04-28","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"143894467","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}