Geoenergy Science and Engineering最新文献

{"title":"Permeability characteristics of hydrate-bearing sediments during hydrate formation and depressurization decomposition processes","authors":"Hui-e Chen ,&nbsp;Wenchong Shan ,&nbsp;Yueqiang Ma","doi":"10.1016/j.geoen.2025.214099","DOIUrl":"10.1016/j.geoen.2025.214099","url":null,"abstract":"<div><div>The permeability of hydrate-bearing sediment (HBS) reservoirs governs fluid migration and directly influences the efficiency of gas hydrate extraction. In this study, HBS samples with varying hydrate saturations were prepared using two distinct methods: direct hydrate formation (Method A) and depressurization-induced decomposition (Method B). Permeability measurements were conducted under effective confining pressures ranging from 1.5 to 4.5 MPa. Hydrate growth modes during formation and decomposition were characterized using the Kozeny grain model (KGM), enabling mechanistic analysis of permeability evolution. Key findings reveals that the permeability decreases with increasing hydrate saturation and effective confining pressure. Under an effective stress of 4.5 MPa, permeability values decline to 3.76 mD (at <em>S</em>_<em>h</em> = 29.30 %), 9.44 mD (at <em>S</em>_<em>h</em> = 19.66 %), and 13.3 mD (at <em>S</em>_<em>h</em> = 11.27 %), respectively, closely matching field-scale observations. Notably, HBS samples subjected to hydrate formation and subsequent decomposition exhibit higher permeability than those without hydrate decomposition, highlighting the irreversible impact of hydrate dynamics on pore structure. Method B, simulating depressurization mining conditions, induces distinct hydrate growth modes, which critically alter permeability behavior. This method better replicates field-scale hydrate dissociation processes, demonstrating its superiority in predicting reservoir responses during gas extraction.</div></div>","PeriodicalId":100578,"journal":{"name":"Geoenergy Science and Engineering","volume":"255 ","pages":"Article 214099"},"PeriodicalIF":0.0,"publicationDate":"2025-07-19","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"144680560","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":"MEOR-on-Chip: Lab-scale visualization of dynamics and mechanisms in microbial enhanced oil recovery via microfluidic technology","authors":"Wu-Juan Sun ,&nbsp;Ya-Ting Deng ,&nbsp;Zhi-Hui Jiang ,&nbsp;Xiao-Jun Wang ,&nbsp;Yong Gao ,&nbsp;Zhi-Rui Liu ,&nbsp;Cong-Yu Ke ,&nbsp;Si-Chang Wang ,&nbsp;Qun-Zheng Zhang ,&nbsp;Rui-Fei Wang","doi":"10.1016/j.geoen.2025.214082","DOIUrl":"10.1016/j.geoen.2025.214082","url":null,"abstract":"<div><div>Microbial enhanced oil recovery (MEOR) technology has made significant strides in both theoretical research and practical applications, yet gaps persist in understanding its mechanism. This study utilizes a microfluidic chip to delve into the microbial flooding process, simulating MEOR and employing in-situ monitoring through microscopic visualization. The on-chip microbial flooding experiments feature a composite microbial community which swiftly reproduces using petroleum hydrocarbons as the sole carbon source, producing biosurfactants, organic acids, and biogas with notable emulsification and viscosity reduction effects on crude oil. Microbial flooding, building on primary water flooding, elevates oil recovery by 16.7 %. In-situ imaging examines oil displacement, residual oil morphology, microbial dynamics, and MEOR mechanisms across displacement processes. Conclusions highlight microbial strains' robust growth and metabolite effects, with the composite community enhancing viscosity reduction by 74.1 %. Facilitated by microfluidic technology, mechanistic studies reveal microorganisms' interactions with oil, leading to emulsification and dispersion. Microorganisms primarily utilize petroleum hydrocarbons at the oil/water interface for growth, whilst use dissolved hydrocarbons in the aqueous phase as carbon sources. Microbial transportation in the reservoir during water injection reveals migration patterns across channels and blind ends, underscoring MEOR complexities. These findings enrich MEOR theory and inform future research and application endeavors.</div></div>","PeriodicalId":100578,"journal":{"name":"Geoenergy Science and Engineering","volume":"255 ","pages":"Article 214082"},"PeriodicalIF":0.0,"publicationDate":"2025-07-19","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"144680561","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":"Optimization of carbon capture and storage technology using sodium alginate through response surface methodology","authors":"Muhammad Arqam Khan ,&nbsp;Shaine Mohammadali Lalji ,&nbsp;Moiz Ali Khan Sial ,&nbsp;Areeba Batool ,&nbsp;Mohsin Ayubi ,&nbsp;Syed Imran Ali ,&nbsp;Muhammad Mustafa ,&nbsp;Mei-Chun Li","doi":"10.1016/j.geoen.2025.214095","DOIUrl":"10.1016/j.geoen.2025.214095","url":null,"abstract":"<div><div>The increasing demand for sustainable carbon capture technologies necessitates the exploration of novel solvents for CO₂ absorption. Carbon Capture and Storage (CCS) is a critical technology for controlling greenhouse gas emissions and tackling climate change. This study investigated the efficiency of sodium alginate (Na-Alg) as a bio-based solvent in carbon capture technology using the simulation software, Aspen Plus. The model was developed to simulate the absorption of CO₂ in a tray column, and the performance of sodium alginate solution was analyzed using various key parameters, including temperature, pressure, and solvent flow rate, to maximize the carbon capture efficiency. The simulation was then validated with the help of existing literature and experimental data and was found to be in good correlation. The carbon capture efficiency of CO₂ was observed at 97 % using sodium alginate solution. The relations between process parameters and their influence on CO₂ capture were evaluated by applying response surface methodology, identifying optimal conditions at 10–20 °C, 10 bar pressure, and a solvent flow rate of 20–25 kmol/h. These findings highlight the potential of sodium alginate as an effective, eco-friendly solvent for CCS, offering both environmental and operational advantages. The study also demonstrates the utility of simulation and optimization techniques in enhancing CCS performance.</div></div>","PeriodicalId":100578,"journal":{"name":"Geoenergy Science and Engineering","volume":"255 ","pages":"Article 214095"},"PeriodicalIF":0.0,"publicationDate":"2025-07-19","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"144680565","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":"Key mechanical properties of hydrate bearing sediment: state of the art and prospects","authors":"Qing Yang,&nbsp;Jiaolong Xu,&nbsp;Yubin Ren,&nbsp;Yunrui Han,&nbsp;Chen Zhou,&nbsp;Gang Yang,&nbsp;Yin Wang,&nbsp;Long Yu","doi":"10.1016/j.geoen.2025.214079","DOIUrl":"10.1016/j.geoen.2025.214079","url":null,"abstract":"<div><div>Natural gas hydrates (NGH), as an exceptionally promising source of clean alternative energy, are widely stored in the seabed. Insufficient understanding of the mechanical behavior of hydrate-bearing sediments (HBS) may increase the risk probability of triggering geological disasters and threatening safe exploitation. The objective of this paper is to make a comprehensive review of the key mechanical characteristics of HBS. Firstly, the preparation technology of HBS samples, including in-situ sampling and indoor synthesis technology was introduced. Then, the compressive characteristics of HBS were systematically concentrated from experimental research, mechanism analysis, numerical simulation and mathematical model. It was followed by the summaries of static mechanical properties, including the current development of test equipment, typical shear behavior of HBS at different conditions, and the major influencing factors. In particular, the research progress of the dynamic mechanical properties of HBS was generalized mainly from two aspects of large or small strain conditions and numerical simulation. Finally, the summary of this review and the shortcomings of the current research, as well as the prospects were made and proposed. This review is expected to deepen the understanding of the mechanical behavior of HBS for subsequent researchers and provide reference for future exploitation.</div></div>","PeriodicalId":100578,"journal":{"name":"Geoenergy Science and Engineering","volume":"255 ","pages":"Article 214079"},"PeriodicalIF":0.0,"publicationDate":"2025-07-19","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"144711223","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 investigation on improving sweep efficiency through temperature-resistant gel foam in heavy oil reservoirs","authors":"Bin Zhang ,&nbsp;You Zhou ,&nbsp;Bojun Wang ,&nbsp;Changfeng Xi ,&nbsp;Weifeng Lv ,&nbsp;Pengcheng Liu","doi":"10.1016/j.geoen.2025.214117","DOIUrl":"10.1016/j.geoen.2025.214117","url":null,"abstract":"<div><div>As global demand for crude oil increases, the problem of steam channeling faced in the thermal recovery of heavy oil reservoirs seriously affects the oil recovery and operation cost. Due to the limitations of profile control in traditional foams, the aim of this experimental investigation is to develop a high-temperature-resistant gel foam system to plug steam channeling paths. Gel foam can compensate for the defect of poor thermal stability in single-component foam, and shows great potential in oil reservoir development. This paper mainly expounds that the gel foam system (0.5 wt% foaming agent AOS + 0.5 wt% polymer HPAM + 0.4 wt% crosslinker PE + 0.5 wt% stabilizer), as a profile control agent for improving the recovery, has better performance than the single foaming agent AOS. Through the experiments on the foam volume and the half - life of liquid separation, the foaming agent AOS has the highest foam complex index both at room temperature and under the high temperature condition of 200 °C. Subsequently, AOS is selected to be compounded with the gel, and the formula of the gel foam system with good gel - forming performance is determined: 0.5 wt% AOS +0.5 wt% HPAM +0.4 wt% PE + 0.5 wt% stabilizer. In the profile control experiment, when the gas-liquid ratio is 1:1, the addition of AOS to the gel can increase its resistance factor by 14 times, which confirms that compared with AOS, this system can effectively block the high - permeability dominant channels and improve the sweep volume, demonstrating great potential for enhancing oil recovery. Moreover, after the gel foam system is aged at 200 °C for 48 h and then subsequent water flooding of 15 PV is carried out, the plugging rate of the gel foam system is still as high as 86.4 %, which also indicates that this system can carry out long - term and effective profile control. Moreover, the heavy oil recovery of the gel foam slug is 6.3 % higher than that of the AOS slug. Therefore, as a profile control agent for improving the sweep efficiency, the gel foam system has greater advantages than AOS profile control.</div></div>","PeriodicalId":100578,"journal":{"name":"Geoenergy Science and Engineering","volume":"255 ","pages":"Article 214117"},"PeriodicalIF":0.0,"publicationDate":"2025-07-18","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"144704279","PeriodicalName":null,"FirstCategoryId":null,"ListUrlMain":null,"RegionNum":0,"RegionCategory":"","ArticlePicture":[],"TitleCN":null,"AbstractTextCN":null,"PMCID":"","EPubDate":null,"PubModel":null,"JCR":null,"JCRName":null,"Score":null,"Total":0}

{"title":"CO2 plume monitoring and visualization using pathlines, source cloud and time cloud","authors":"Hongquan Chen,&nbsp;Ao Li","doi":"10.1016/j.geoen.2025.214093","DOIUrl":"10.1016/j.geoen.2025.214093","url":null,"abstract":"<div><div>Effective monitoring of subsurface fluid motion is crucial for successful carbon sequestration. While streamlines are commonly used to visualize fluid flow, they are based on instantaneous velocity fields and do not account for changing field conditions. To address this problem, pathlines are introduced to track the history of individual fluid particles as they move in a changing velocity field.</div><div>This paper presents the development and application of pathlines for flow visualization in CO₂ storage projects. By splicing streamline segments over time, pathlines can trace the trajectory of a particle under a changing velocity field. In addition, streaklines and timelines can be visualized from pathlines. Streaklines represent all fluid particles emitted at the same location, while timelines show the contour formed by all fluid particles emitted at the same instant, representing the fluid front movement. In 3D, these concepts are visualized in groups of points, referred to as source cloud and time cloud.</div><div>To test the effectiveness of our proposed injection monitoring methods, we conducted experiments on 3D synthetic CO₂ storage models. The results show that pathlines, source cloud and time cloud provide a more accurate display of the CO₂ plume than streamlines, particularly in field situations where well schedules are changing.</div><div>Finally, we applied the proposed method to visualize the CO₂ plume in a sequestration model based on Norway's Sleipner site. Under dynamic injection, the pathline-based swept volume closely matched the CO₂ saturation-defined volume (95 % overlap), while the streamline-based volume overestimated it by 127 %. This highlights the effectiveness of pathlines, source cloud, and time cloud for CCUS visualization.</div></div>","PeriodicalId":100578,"journal":{"name":"Geoenergy Science and Engineering","volume":"255 ","pages":"Article 214093"},"PeriodicalIF":0.0,"publicationDate":"2025-07-18","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"144704379","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":"Microscopic performance evaluation of hyperbranched polyamine for sodium montmorillonite hydration inhibition in water-based drilling mud systems","authors":"Jiafang Xu ,&nbsp;Justine Kiiza ,&nbsp;Johann Peter Plank ,&nbsp;Zhehui Jin ,&nbsp;Xiaolong Yang ,&nbsp;Hualin Liao","doi":"10.1016/j.geoen.2025.214115","DOIUrl":"10.1016/j.geoen.2025.214115","url":null,"abstract":"<div><div>Deep to ultra-deep drilling operations are vital strategies for global energy security, requiring high-performance drilling fluid systems. Water-based drilling fluids/muds (WBDFs/WBDMs), especially clay-containing muds, often degrade under extreme wellbore conditions owing to clay mineral hydration, necessitating advanced inhibition strategies and effective additives to minimize expansion and ensure wellbore stability. Amine-based additives are known for their remarkable inhibitive features. Molecular dynamics simulation was used to evaluate the inhibition performance of a hyperbranched polyamine on sodium montmorillonite (Na-Mnt) hydration in WBDFs. This polyamine demonstrated good solubility and effectively interacts, adsorbs and coats the Na-Mnt surface. Adsorption occurs primarily through H-bonding and electrostatic attractions, with minimal van der Waals (vdW) contributions, forming a protective surface layer/film on the Na-Mnt that modifies its hydrophilic properties by layering the surface. Two adsorption configurations were identified: a stable amine head group and a dimethylamine group. The addition of the polyamine reduced counterion and water mobility, minimizing their coordination as the aqueous NH₄⁺ ions replaced Na ⁺ ions and water molecules, reducing the counterion and Na-Mnt hydration, consequently, weakening the Na-Mnt/water H-bonding network and interaction energy, and thus reducing surface hydration. Temperature had a significant impact on the interaction strength and inhibition performance, while high pressure played a minimal role at elevated temperatures. Overall, the hyperbranched polyamine demonstrated splendid inhibition performance under HT/HP conditions (478 K/75 MPa) for enhancing WBDFs performance and supporting safer, stable and more efficient well drilling works.</div></div>","PeriodicalId":100578,"journal":{"name":"Geoenergy Science and Engineering","volume":"255 ","pages":"Article 214115"},"PeriodicalIF":0.0,"publicationDate":"2025-07-18","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"144686167","PeriodicalName":null,"FirstCategoryId":null,"ListUrlMain":null,"RegionNum":0,"RegionCategory":"","ArticlePicture":[],"TitleCN":null,"AbstractTextCN":null,"PMCID":"","EPubDate":null,"PubModel":null,"JCR":null,"JCRName":null,"Score":null,"Total":0}

{"title":"CO2-responsive system for preventing gas channeling during CO2 flooding in low permeability reservoirs","authors":"Rui Liu ,&nbsp;Canghai Chen ,&nbsp;Yang Tao ,&nbsp;Zezhou Chen","doi":"10.1016/j.geoen.2025.214094","DOIUrl":"10.1016/j.geoen.2025.214094","url":null,"abstract":"<div><div>At present, CO₂ flooding is extensively used in low-permeability reservoirs to enhance oil recovery (EOR). However, due to the serious heterogeneity of the formation, the gas is prone to escape along large pores during CO₂ flooding. Conventional CO₂ anti-channeling systems have some defects such as poor stability, weak retention capacity and inferior plugging effect. Therefore, it is critical to develop a novel type of CO₂ anti-channeling system for low-permeability reservoirs. Herein, four kinds of systems with amine groups are tested to identify the most effective CO₂-responsive system, which consists of poloxamer, dimethylaminoethyl acrylate, nano carbon powder, acrylamide and initiator. Subsequently, physicochemical properties of the optimum system are researched systematically by rheological experiments, CO₂-responsive processes and structural characterization. The results indicate that the viscosity of the system increases from 4.2 mPa s to approximately 67.8 mPa s as a result of increasing temperature and CO₂ injection. Meanwhile it can be reversibly cycled between low viscosity and high viscosity by alternately introducing and removing CO₂, which indicates the gas response behavior of the system is reversible. Furthermore, the plugging performance and EOR are evaluated using low permeability cores. The experiments demonstrate that the system can effectively restrain gas channeling and enhance recovery factor by as high as 22 % - significantly outperforming conventional water-alternating-gas (WAG) flooding which provided only a 10.62 % enhancement under comparable conditions. We expect our work can provide a new system and method for CO₂ anti-channeling in low-permeability reservoirs.</div></div>","PeriodicalId":100578,"journal":{"name":"Geoenergy Science and Engineering","volume":"255 ","pages":"Article 214094"},"PeriodicalIF":0.0,"publicationDate":"2025-07-18","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"144695423","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 fluid saturation on the elastic properties of carbonate rocks with different pore structures in a strike-slip fault zone","authors":"Fei Gong ,&nbsp;Yichen Song ,&nbsp;Lianbo Zeng ,&nbsp;Suping Peng ,&nbsp;Guangui Zou ,&nbsp;Guowei Wang","doi":"10.1016/j.geoen.2025.214110","DOIUrl":"10.1016/j.geoen.2025.214110","url":null,"abstract":"<div><div>Understanding the elastic characteristics of fault-controlled carbonate rocks under dry and water saturated conditions is still rare, despite being essential for hydrocarbon exploration and development. To study the influences of stress and fluid on the elastic characteristics of carbonate rocks controlled by a strike-slip fault, four samples were studied by combining microscopic observation, ultrasonic analysis and theoretical modeling. The results show that significant heterogeneity can be found in the characteristics of carbonate rocks with pore structure differences. The porosity and permeability of the fault core are 3–6 times and 2-3 orders of magnitude greater than those of the damage zone, while velocities are significantly lower. The velocity pressure sensitivity of the saturated samples is less than that of dry ones, because the compressibility of microcracks is greatly reduced under water saturated conditions. The DKT model can simulate the elastic moduli of carbonate strike-slip fault rocks by three equivalent pore geometries, which can qualitatively identify the fault structure. After saturation, the S-wave velocity generally decreases in the fault core and increases in the damage zone. Fault core samples show shear softening after saturation, while the damage zone samples show shear stiffening. The Gassmann's equations may not be valid anymore in this situation. The changes in shear moduli after saturation are affected by the combination of the pore structure and the confining pressure, and the potential mechanisms are also discussed.</div></div>","PeriodicalId":100578,"journal":{"name":"Geoenergy Science and Engineering","volume":"255 ","pages":"Article 214110"},"PeriodicalIF":0.0,"publicationDate":"2025-07-18","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"144670349","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":"Strength development of phosphoaluminate cements in a CO2-containing environments at 110 °C: synergistic evolution of compressive strength, hydration products and micro-morphology, and carbonation mechanism","authors":"Bin Yuan,&nbsp;Shuo Yang,&nbsp;Xingyang Zhang,&nbsp;Zehao Zheng,&nbsp;Bihua Xu","doi":"10.1016/j.geoen.2025.214122","DOIUrl":"10.1016/j.geoen.2025.214122","url":null,"abstract":"<div><div>Phosphoaluminate cements are able to meet the high temperature and high CO₂ content environments faced by oil and gas well cementing, owing to their high temperature and corrosion resistance. However, up to now, there is no research to clarify its compressive strength, hydration product changes and corrosion mechanism in such complex environments. Therefore, this paper analyzes the compressive strength and type of hydration products of phosphoaluminate cement stones at 110 °C and CO₂ environments with different curing times and after corrosion. It was shown that the permeability of phosphoaluminate cement stone first decreased and then increased with the increase of the curing time, while the compressive strength kept increasing, and the specimens' compressive strength after corrosion still maintains a very high level. The stable existence of hydroxyapatite (Ca₅(PO₄)₃OH) and hydrated aluminate (C₃AH₆), as well as the persistent generation of main hydration products (hydrated phosphate (CPH) and hydrated phosphoaluminate (CAPH)), and their morphology always maintains a uniform distribution of flakes and fibers, together guarantee the stable growth of compressive strength. The corrosion mechanism shows that Al(OH)₃ and CaCO₃, generated by the corrosion of CPH, CAPH with C₃AH₆ and CAP with CA, had a positive affect on pore development. At the same time, Ca₁₀(PO₄)₆CO₃ generated by the corrosion of some Ca₅(PO₄)₃OH will maintain the original hexagonal structure to form a protective layer, and H₃PO₄ released by the corrosion of hydration products and reactive minerals will lead to an increasingly acidic solution. This prevents the diffusion of CO₂ toward the internal cement stone, which in turn further inhibits corrosion.</div></div>","PeriodicalId":100578,"journal":{"name":"Geoenergy Science and Engineering","volume":"255 ","pages":"Article 214122"},"PeriodicalIF":0.0,"publicationDate":"2025-07-18","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"144665526","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}