Gas Science and Engineering最新文献

{"title":"Cryogenic fracturing of coal with LN2 treatment: A sustainable approach for enhancing coalbed methane extraction in water-scarce regions","authors":"Sotirios Nik Longinos ,&nbsp;Dastan Begaliyev ,&nbsp;Mohammad Asif ,&nbsp;Mirlan Tuleugaliyev","doi":"10.1016/j.jgsce.2025.205686","DOIUrl":"10.1016/j.jgsce.2025.205686","url":null,"abstract":"<div><div>Alteration of the pore space in coal fractured by liquid nitrogen (LN₂) significantly influences the coalbed methane (CBM) process to overall porosity, effective permeability, pore rugosity, and adsorption capacity. The impact of LN₂ treatment on the pore structures of coal samples from the Karaganda Coal Basin, Kazakhstan, was analyzed to enhance CBM extraction. This study employs Mercury Intrusion Porosimetry (MIP) and Low-Pressure Nitrogen Gas Adsorption (LN2GA) isotherm for analyzing the effects of varying freezing times and freezing-thawing cycles on the pore structure of coal. The maximum nitrogen adsorption capacity (25.02 cc/g) and the total injected mercury volume (0.226 cc/g) in the specimens were positively correlated (R² = 0.98) with the total freezing time and the number of freezing-thawing cycles. As LN₂ freezing time increases, fractal dimensions decrease, indicating a more uniform pore structure. The values drop from D1 = 2.43, D2 = 2.80 (0 min) to D1 = 2.17, D2 = 2.62 (180 min), suggesting reduced roughness and complexity. The peak intrusion volumes increased from 0.185 cm³/g (0 min) to 0.217 cm³/g (180 min), indicating that prolonged freezing expands the coal structure to create additional pores. Ejection efficiency improved from 68.32 % (0 min) to 77.22 % (180 min), reflecting better pore connectivity as the freezing duration increases. This study is paramount in the cryogenic fracturing of coal formation and may be opted against hydraulic fracturing for various industrial applications in water-scare regions.</div></div>","PeriodicalId":100568,"journal":{"name":"Gas Science and Engineering","volume":"142 ","pages":"Article 205686"},"PeriodicalIF":0.0,"publicationDate":"2025-06-09","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"144241595","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 investigation of particle migration and pore clogging during methane hydrate extraction in porous media","authors":"Tuo Wang ,&nbsp;Mengli Li","doi":"10.1016/j.jgsce.2025.205687","DOIUrl":"10.1016/j.jgsce.2025.205687","url":null,"abstract":"<div><div>Sand production is an important research direction in hydrate extraction, which involves particle migration and pore clogging mechanism in gas-liquid two-phase flow. This study employs a coupled resolved CFD-DEM-VOF (computational fluid dynamics, discrete element method, and volume of fluid) approach to simulate particle dynamics in a microfluidic chip with a column matrix. The work elucidates the mechanisms of particle migration and pore clogging in gas-liquid two-phase flow through porous media, while systematically evaluating the effects of key multiphase parameters. The results indicate that when gas is injected, the water flow creates a fluid channel between the bubbles, accelerating the fluid velocity within the channel. As a result, particles migrate along the fluid channel, leading to increased aggregation and a higher probability of pore clogging. In contrast, the fluid velocity outside the channel is slower. Many particles in the low velocity regions are unable to migrate, further contributing to the risk of pore clogging. Parameter analysis reveals that both high and low gas injection fractions reduce the likelihood of pore clogging. Additionally, both excessively high and low contact angles negatively impact particle migration. Furthermore, the probability of pore clogging increases with rising surface tension and particle injection rate.</div></div>","PeriodicalId":100568,"journal":{"name":"Gas Science and Engineering","volume":"142 ","pages":"Article 205687"},"PeriodicalIF":0.0,"publicationDate":"2025-06-09","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"144264099","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":"Enhancing gas geo-storage capacity in carbonate saline formations using fluorinated surfactants: Experimental investigation and implications for sustainable energy solutions","authors":"Payam Moradi ,&nbsp;Mohammad Chahardowli ,&nbsp;Mohammad Simjoo","doi":"10.1016/j.jgsce.2025.205690","DOIUrl":"10.1016/j.jgsce.2025.205690","url":null,"abstract":"&lt;div&gt;&lt;div&gt;Large-scale gas geo-storage has the potential to be a key component in achieving a sustainable energy solution. Carbonate saline formations can be considered promising geological structures for this purpose. However, they are naturally water-wet, characterized by very low permeability and high brine salinity. To enhance the gas storage potential of carbonate saline formations, two key issues need to be addressed: modifying the rock surface wettability and reducing capillary entry pressure. For this purpose, a systematic experimental study utilizing a fluorinated surfactant was conducted. First, a comprehensive analysis of the rock surface morphology was conducted using SEM, EDAX, XRD, and AFM tests. This analysis aimed to elucidate the surface adsorption phenomena and investigate the morphological changes in the rock surface resulting from the wettability modification process. Second, brine/gas contact angle and surface tension were measured in different salinities and surfactant concentrations. Third, imbibition and flooding experiments were carried out to analyse the effect of the surfactant's modification of wettability and assess the enhanced storage performance. The findings revealed a significant decrease in the surface tension between brine and gas, as well as a change in the gas/brine contact angle, both of which are linked to the inclusion of the fluorinated surfactant in the aqueous phase. Specifically, the brine/gas surface tension dropped from 60.6 mN/m to 16.1 mN/m, while the contact angle decreased from 131° to 110°. Moreover, in the spontaneous imbibition experiments, the plug sample treated with the surfactant, exhibited reduced and slower water imbibition compared to the untreated plug, i.e., the volume of imbibed water was dropped from 28 cc to 10 cc. This indicates that a greater volume of gas remained within the core sample, thereby corresponding to an enhanced storage capacity. Moreover, during the experiments of core flooding conducted at a constant outlet pressure, the treated sample exhibited a lower injection pressure (higher pressure drop) compared to the untreated sample. For instance, the pressure drop in the treated sample was 40 psi, whereas it was 31 psi in the untreated sample. Overall, the reduction in surface tension and the modification of wettability resulted in a decreased capillary entry pressure and facilitating easier gas-brine displacement. The results demonstrated that the fluorinated surfactant reduced injection pressure, indicating better gas injectivity, while allowing a greater volume of gas to be stored within the core, thereby increasing gas storage capacity. All experimental findings align and together show that fluorinated surfactants have the potential to greatly enhance gas geo-storage capacity in carbonate saline formations. The results of this study hold wider significance and can be applied to multiple geo-storage applications, including Underground Hydrogen Storage (UHS), Carbon Ca","PeriodicalId":100568,"journal":{"name":"Gas Science and Engineering","volume":"142 ","pages":"Article 205690"},"PeriodicalIF":0.0,"publicationDate":"2025-06-09","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"144264101","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":"Extended Søreide-Whitson equation of state for CO2-brine equilibrium using an ion-specific parameterisation","authors":"Sonja A.M. Smith,&nbsp;Erling H. Stenby,&nbsp;Wei Yan","doi":"10.1016/j.jgsce.2025.205684","DOIUrl":"10.1016/j.jgsce.2025.205684","url":null,"abstract":"<div><div>Carbon capture and storage (CCS) initiatives rely on understanding the behaviour of CO₂ in saline aquifers, where solubility trapping is a key mechanism. Experimental data, while critical for model validation, are resource-intensive to obtain. Thermodynamic models, such as the Søreide-Whitson framework, offer an efficient alternative for evaluating CO₂ solubility under reservoir conditions. In this work a generalised Søreide-Whitson model is presented to calculate the solubility of CO₂ in pure water and brine solutions on an ion-specific basis across a wide range of temperatures (273–473 K), pressures (up to 50 MPa), and salinities (up to 6 mol⋅kg⁻¹). The updated model includes expressions for <span><math><mrow><mi>N</mi><msup><mi>a</mi><mo>+</mo></msup></mrow></math></span>, <span><math><mrow><msup><mi>K</mi><mo>+</mo></msup></mrow></math></span>, <span><math><mrow><msup><mtext>Mg</mtext><mrow><mn>2</mn><mo>+</mo></mrow></msup></mrow></math></span>, <span><math><mrow><msup><mtext>Ca</mtext><mrow><mn>2</mn><mo>+</mo></mrow></msup></mrow></math></span>, <span><math><mrow><msup><mtext>Cl</mtext><mo>−</mo></msup></mrow></math></span>, <span><math><mrow><msubsup><mtext>SO</mtext><mn>4</mn><mrow><mn>2</mn><mo>−</mo></mrow></msubsup></mrow></math></span>, and <span><math><mrow><msubsup><mtext>NO</mtext><mn>3</mn><mo>−</mo></msubsup></mrow></math></span>.</div><div>The modified model introduces generalised expressions for the α-function and phase-dependent binary interaction parameter <span><math><mrow><msubsup><mi>k</mi><mrow><mi>i</mi><mi>j</mi></mrow><mtext>AQ</mtext></msubsup></mrow></math></span> based on individual concentrations of ions rather than salts. This approach significantly improves the accuracy of CO₂ solubility predictions in brines containing multiple salts, as demonstrated through comparisons with experimental data. The generalised model maintains its robustness for mixed-salt brines and is readily implementable in simulation tools, expanding its applicability for CCS evaluations.</div></div>","PeriodicalId":100568,"journal":{"name":"Gas Science and Engineering","volume":"142 ","pages":"Article 205684"},"PeriodicalIF":0.0,"publicationDate":"2025-06-07","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"144306249","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":"Impacts of rock components on the competitive adsorption of carbon dioxide and methane in organic shales","authors":"Ibrahim Gomaa,&nbsp;Isa Silveira de Araujo,&nbsp;Zoya Heidari,&nbsp;D. Nicolas Espinoza","doi":"10.1016/j.jgsce.2025.205681","DOIUrl":"10.1016/j.jgsce.2025.205681","url":null,"abstract":"<div><div>The competitive adsorption of CO₂ and CH₄ on kerogen and clay surfaces significantly affects CO₂ sequestration and enhanced gas recovery (EGR) in organic shale-gas reservoirs. Conventional laboratory methods struggle to quantify individual gas adsorption in CO₂:CH₄ mixtures. To address this challenge, we aim to quantify (a) the effects of kerogen type, pore structure, and thermal maturity on CO₂:CH₄ competitive adsorption, (b) the impact of clay surface chemistry on the adsorption capacity of organic shale formations, and (c) the influence of different moisture and oil contents on the adsorption capacity of kerogen and clay structures. We used Grand Canonical Monte Carlo (GCMC) simulations (verified against previously documented experimental measurements) to investigate how kerogen composition, pore structure, and thermal maturity, water/oil saturation, and clay surface chemistry influence CO₂ adsorption under reservoir conditions.</div><div>Results suggest that changing kerogen from type I to III increases CO₂ adsorption from 1.42 mmol/g to 5.56 mmol/g at 330 K and 20 MPa. Increasing thermal maturity significantly affected CO₂ adsorption, though raising reservoir pressure from 1 MPa to 20 MPa reduces CO₂/CH₄ selectivity. Moreover, the presence of moisture and oil decrease maximum CO₂ adsorption. For clay minerals, the positively charged K-illite enhances CO₂ adsorption by 133 % compared to negatively charged illite and exhibits a CO₂/CH₄ selectivity of 17.2 versus 1.48 in kaolinite. These findings emphasize that reservoir conditions as well as composition critically affect adsorption capacity and selectivity. The introduced molecular simulation framework enabled extensive sensitivity analyses of factors influencing CO₂ storage at conditions that extend beyond the reach of conventional laboratory experiments, which potentially enables the optimization of CO₂ storage strategies in organic shale-gas reservoirs.</div></div>","PeriodicalId":100568,"journal":{"name":"Gas Science and Engineering","volume":"142 ","pages":"Article 205681"},"PeriodicalIF":0.0,"publicationDate":"2025-05-30","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"144272405","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":"Effect of pulsation frequencies on the fracture characteristics of CO2 foam fractured coal: An experimental study","authors":"Yangfeng Zheng ,&nbsp;Cheng Zhai ,&nbsp;Aikun Chen ,&nbsp;Hexiang Xu ,&nbsp;Xinyu Zhu ,&nbsp;Shuxun Sang ,&nbsp;Meng Wang ,&nbsp;Shiqi Liu ,&nbsp;Xu Yu ,&nbsp;Jizhao Xu ,&nbsp;Yong Sun ,&nbsp;Yuzhou Cong ,&nbsp;Wei Tang ,&nbsp;Yujie Li ,&nbsp;Yu Wang ,&nbsp;Yongshuai Lai","doi":"10.1016/j.jgsce.2025.205668","DOIUrl":"10.1016/j.jgsce.2025.205668","url":null,"abstract":"<div><div>The pulsating CO₂ foam fracturing technology represents an efficacious approach to enhance coalbed methane recovery, exhibiting considerable potential for widespread application. However, the influence of pulsation frequency on the acoustic emission response characteristics and fracture propagation mechanism during CO₂ foam fracturing of coal remains elusive, impeding the engineering application. To address the issues above, a self-built pulsating CO₂ foam fracturing experiment system was used to conduct the experiments of CO₂ foam fracturing with different pulsation frequencies (0–20 Hz), with simultaneous acquisition of pressure-time curves and acoustic emission signals throughout the process. The results show that as the pulsation frequency increases, the average breakdown pressure of fractured coal exhibits a cubic polynomial decrease, while the average fracturing duration increases. Concurrently, the cumulative energy of acoustic emission increases gradually, and the number of acoustic emission location points grows exponentially. The macroscopic cracks in coal exhibit a symmetrical “wing-shaped” distribution on both sides of the borehole. The fracture type of fractured coal is dominated by tensile failure and supplemented by shear failure, and the larger the pulsation frequency, the higher the proportion of tensile failure. Notably, before the formation of macroscopic fractures in the coal, the improved <em>b</em>-value of acoustic emission exhibits a significant decrease. The fracture propagation of pulsating CO₂ foam fractured coal results from the synergistic effects of multiple factors, including pulsating fatigue impact, cold shock from the fracturing fluid, mineral dissolution by carbonic acid and surfactants, CO₂ adsorption-induced coal matrix expansion, and CO₂ phase transition. In conclusion, the pulsating CO₂ foam fracturing technology significantly enhances the fracture complexity and pore connectivity of coal through high-frequency pulsation and modification synergy, and effectively enhances the coalbed methane recovery, as well as reduces the consumption of water resources and realizes the CO₂ sequestration, which provides an innovative solution for the economic and efficient development of low-permeability coal beds and the reduction of greenhouse gas emissions. The research results can provide basic theoretical support for the engineering application of pulsating CO₂ foam fracturing, which is of great significance for the prevention and control of coal mine gas disasters and the enhancement of coalbed methane recovery.</div></div>","PeriodicalId":100568,"journal":{"name":"Gas Science and Engineering","volume":"141 ","pages":"Article 205668"},"PeriodicalIF":0.0,"publicationDate":"2025-05-23","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"144168764","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":"Modification effect of supercritical CO2 on coal microstructure and its influence on CH4/CO2 adsorption and diffusion","authors":"Hongqing Hu,&nbsp;Ziwen Li,&nbsp;Xiaoguang Qiao,&nbsp;Yinji Wang,&nbsp;Yabin Gao,&nbsp;Fazhi Yan,&nbsp;Tianze Gao,&nbsp;Zhaoqiang Yan","doi":"10.1016/j.jgsce.2025.205669","DOIUrl":"10.1016/j.jgsce.2025.205669","url":null,"abstract":"<div><div>During the process of injecting CO₂ into coal seams to increase the production of coalbed methane (CBM), the CO₂ will present a supercritical state due to the increase in depth. Supercritical CO₂, with its high diffusivity characteristic of gases and strong dissolving capacity typical of liquids, possesses exceptional extraction properties capable of substantially modifying the physicochemical characteristics of coal, consequently impacting the adsorption and diffusion behaviors of coalbed methane (CBM). In this paper, the effect of modification treatment on the physicochemical structure of coal samples has been analyzed through supercritical CO₂ modification experiments using elemental analysis, low-temperature nitrogen adsorption, FTIR, and ¹³C-NMR. Meanwhile, the molecular model of coal before and after modification is constructed, and molecular dynamics simulation has been used to investigate the effect of modification on the adsorption and diffusion properties of CO₂/CH₄ adsorption. The results show that the supercritical CO₂ modification led to the shortening of the length of the fatty chains and the increase of the degree of condensation of the aromatic structure in coal samples, which contributed to a more organized coal structure. Supercritical CO₂ has little effect on the pore morphology of the coal body, promotes the formation of smaller pores, and improves the porosity. The adsorption capacity of the modified coals for CH₄ and CO₂ increases significantly, and CO₂ still dominates in the competitive adsorption process. In addition, supercritical CO₂ modification greatly enhances the diffusion performance of CH₄ and CO₂ in coal, especially the diffusion effect of CO₂ is more significant.</div></div>","PeriodicalId":100568,"journal":{"name":"Gas Science and Engineering","volume":"141 ","pages":"Article 205669"},"PeriodicalIF":0.0,"publicationDate":"2025-05-22","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"144154995","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 high-temperature CO2 in hot flue gas on the wettability of coal surface: Experimental and molecular simulation study","authors":"Shunqing Ma ,&nbsp;Baiquan Lin ,&nbsp;Jiajia Zhao ,&nbsp;Xiangliang Zhang ,&nbsp;Qian Liu ,&nbsp;Ting Liu","doi":"10.1016/j.jgsce.2025.205671","DOIUrl":"10.1016/j.jgsce.2025.205671","url":null,"abstract":"<div><div>Competitive wetting is a key factor influencing capillary forces, CO₂, and water adsorption, and gas desorption and migration. Aiming at uncovering the patterns and mechanisms of water wettability changes with coal pores and fractures under high-temperature and high-pressure CO₂ injection (333–413 K, 4 MPa), this paper presents experiments on the T₂ spectra of moisture within coal pores and fractures, the adsorption characteristics of CO₂ in coal, and the coal-water-gas interfacial property parameters, an analysis on Scanning Electron Microscope (SEM) images of coal surfaces treated with CO₂ at different temperatures, as well as molecular dynamics simulations on CO₂ injection into slits of water-bearing rough coal. The experimental and simulation results disclose that, under high-temperature CO₂ injection, the water wettability within coal pores changes in three stages from the injection well toward the interior of the coal seam, characterized by a “decrease–increase–decrease” pattern. These three stages are governed by different mechanisms: initially by strong activation arising from the temperature field, followed by moderate activation, and finally by CO₂-moisture competitive wetting. Additionally, a water film of appropriate thickness on the coal surface is beneficial for CO₂ adsorption. The three-phase contact angle (<em>θ</em>) cannot serve as a sole basis for accurately judging changes in water wettability within the flow channels of micropores and fractures in coal. Instead, it only effectively reflects changes in droplet wettability caused by competitive adsorption of CO₂ molecules on the coal surface. This study provides guidance on the optimal injection temperature for hot flue gas, which is beneficial for CO₂ capture and improves the extraction efficiency of CBM.</div></div>","PeriodicalId":100568,"journal":{"name":"Gas Science and Engineering","volume":"140 ","pages":"Article 205671"},"PeriodicalIF":0.0,"publicationDate":"2025-05-20","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"144125215","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":"Mutual influence of bubble evolution and seepage flow in heterogeneous porous matrices","authors":"Linlin Gu ,&nbsp;Shicai Sun ,&nbsp;Rundong Zhang ,&nbsp;Rongtao Yan ,&nbsp;Yonghao Yin ,&nbsp;Guanru Gong","doi":"10.1016/j.jgsce.2025.205666","DOIUrl":"10.1016/j.jgsce.2025.205666","url":null,"abstract":"<div><div>The seepage characteristics of sediments dynamically alter with the evolution of gas bubbles, significantly affecting the safety and efficiency of engineering processes such as oil and gas extraction, natural gas hydrate exploitation, and geological carbon dioxide sequestration. Based on the phase-field approach, pore-scale models simulate the gas bubble interface evolution and its influence on pore-water flow in individual pores and continuous porous medium. Simulations show that the average velocity peaks of single pore can be observed during bubble influx and splitting, or when the bubble head plugs the pore channel. As the upstream velocity decreases, bubble evolution trajectory shifts from the path of intra-pore coalescence, extra-pore bubble influx, coalescence, and (splitting) production to the path of intra-pore coalescence, inter-pore ripening, and retention. Residual bubbles in continuous media pores reduce permeability by 98.7 %–99.9 %. Bubbles tend to stagnate at high-to-low permeability medium junctions due to inadequate upstream pressure. Conversely, bubbles retain within high-permeability medium's pores during the low-to-high permeability medium flow. Furthermore, interlayer seepage flux of gas and water increases significantly during bubble interporosity flow. Higher upstream pressure shortens the time for bubble evolution, maturation, and interlayer seepage, accelerating the stabilization of the flow field. In summary, the research results reveal the bubble evolution trajectories and seepage characteristic during interporosity flow of heterogeneous reservoirs.</div></div>","PeriodicalId":100568,"journal":{"name":"Gas Science and Engineering","volume":"140 ","pages":"Article 205666"},"PeriodicalIF":0.0,"publicationDate":"2025-05-20","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"144125213","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":"Temporary sealing of porous media through bio-clogging","authors":"Hossein Younesian Farid,&nbsp;Ali Mahmoodi,&nbsp;Armin Abdollahi Chahardah Cheriki,&nbsp;Hamidreza M. Nick","doi":"10.1016/j.jgsce.2025.205664","DOIUrl":"10.1016/j.jgsce.2025.205664","url":null,"abstract":"<div><div>Ensuring the safe abandonment of a hydrocarbon or geological carbon storage reservoirs requires plugging the wells by installing fluid barriers within the wellbore. A pressure rise due to reservoir fluid flow poses a significant challenge. To prevent the fluid flow, temporary sealing of the porous medium surrounding the wellbore is essential. A promising approach for clogging the porous medium is the bio-mineralization technique. This study employs a large-scale model to simulate the permeability reduction patterns through microbially induced caclite precipitation (MICP). The focus is to provide realistic predictions by verifying the simulation with the results of batch and core-scale experimental analysis. The simulation domains include different systems with heterogeneous porosity and permeability distributions. This study characterizes the different biofilm development patterns in porous medium depending on the fluid velocity (up to 200 cm/h in this study), bacterial concentration and ionic strength of the bacterial solution. Additionally, the study analyses the uncertainties associated with bacterial growth and encapsulation. The simulation results show a significant variability in urea conversion factor during sequential treatment cycles, which ranged from 8 % to 83 % depending on the bacteria concentration, flow rate, and urea concentration. The results underscore the importance of estimating the critical pore diameter to more accurately predict clogging behavior in porous media with both high and low permeability values. This, in turn, enhances the reliability of treatment plan designs, which reduces the costs and material consumption.</div></div>","PeriodicalId":100568,"journal":{"name":"Gas Science and Engineering","volume":"141 ","pages":"Article 205664"},"PeriodicalIF":0.0,"publicationDate":"2025-05-20","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"144154993","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}