International Journal of Greenhouse Gas Control最新文献

{"title":"Mudrock wettability at pressure and temperature conditions for CO2 geological storage","authors":"Mohamed M. Awad,&nbsp;D. Nicolas Espinoza","doi":"10.1016/j.ijggc.2024.104160","DOIUrl":"https://doi.org/10.1016/j.ijggc.2024.104160","url":null,"abstract":"<div><p>Structural trapping provided by seals is one of the key components of CO₂ geological storage systems. Clay-rich caprocks and fault gouge are expected to be water-wet at supercritical CO₂ conditions and to create a positive capillary pressure <span><math><mrow><msub><mi>P</mi><mrow><mi>C</mi><msub><mi>O</mi><mn>2</mn></msub></mrow></msub><mo>−</mo><mspace></mspace><msub><mi>P</mi><mi>w</mi></msub><mo>&gt;</mo><mn>0</mn><mspace></mspace></mrow></math></span>MPa to ensure trapping of buoyant CO₂. This paper presents the results of water imbibition experiments in resedimented clay mudrocks immersed in supercritical CO₂ at temperature <em>T</em> ≥ 60 °C and pressure <span><math><msub><mi>P</mi><mrow><mi>C</mi><msub><mi>O</mi><mn>2</mn></msub></mrow></msub></math></span> ≥ 25 MPa. The samples used in this work include kaolinite clay and Anahuac shale from the Gulf of Mexico Coast. Additional validation tests include Berea sandstone and silane-treated Berea sandstone. The results show spontaneous and rapid imbibition of water droplets into resedimented and rock samples initially saturated with wet supercritical CO₂ for all cases. This outcome provides indirect evidence that typical siliciclastic caprock building minerals remain water-wet to CO₂ at typical storage pressure and temperature conditions. The results and analysis indicate that siliciclastic caprock and fault gouge are expected to develop a positive capillary entry and breakthrough pressure to hold buoyant CO₂ by capillary forces. These results validate expectations of buoyant CO₂ structural trapping and field observations from natural analogues.</p></div>","PeriodicalId":334,"journal":{"name":"International Journal of Greenhouse Gas Control","volume":"135 ","pages":"Article 104160"},"PeriodicalIF":3.9,"publicationDate":"2024-05-23","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"141084603","PeriodicalName":null,"FirstCategoryId":null,"ListUrlMain":null,"RegionNum":3,"RegionCategory":"工程技术","ArticlePicture":[],"TitleCN":null,"AbstractTextCN":null,"PMCID":"","EPubDate":null,"PubModel":null,"JCR":null,"JCRName":null,"Score":null,"Total":0}

{"title":"Failure mechanism of carbon dioxide transport infrastructure: A comprehensive review","authors":"Haoyan Peng ,&nbsp;Hongfang Lu ,&nbsp;Zhao-Dong Xu ,&nbsp;Dongmin Xi ,&nbsp;Guojin Qin","doi":"10.1016/j.ijggc.2024.104144","DOIUrl":"https://doi.org/10.1016/j.ijggc.2024.104144","url":null,"abstract":"<div><p>Carbon dioxide capture and storage (CCS), the bottom covering technology for environmental protection and energy transformation, plays a vital role in reducing CO₂ emissions and has become an international research hotspot. The safe operation of CO₂ transport infrastructure is crucial to ensure the smooth implementation of carbon reduction actions. However, the understanding of disasters in carbon transmission infrastructure is not comprehensive and profound enough since CCS is still developing, which leads to few engineering standards on disaster prevention and mitigation of CO₂ transport infrastructure. This paper provides detailed reviews, including the composition and characteristics of carbon transmission infrastructure, failure mechanisms. It is concluded that the characteristics of CO₂ transport infrastructure damage fundamentally stems from the working fluid and environment, and novelty pointed out that future research hotspots are damage under multi-field coupling, damage detection and monitoring, design to reduce damage and repair after damage. The summary of existing research will be helpful for future academic research and engineering practice of CO₂ transport infrastructure disaster prevention and mitigation.</p></div>","PeriodicalId":334,"journal":{"name":"International Journal of Greenhouse Gas Control","volume":"135 ","pages":"Article 104144"},"PeriodicalIF":3.9,"publicationDate":"2024-05-22","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"141078598","PeriodicalName":null,"FirstCategoryId":null,"ListUrlMain":null,"RegionNum":3,"RegionCategory":"工程技术","ArticlePicture":[],"TitleCN":null,"AbstractTextCN":null,"PMCID":"","EPubDate":null,"PubModel":null,"JCR":null,"JCRName":null,"Score":null,"Total":0}

{"title":"Heuristic algorithms for design of integrated monitoring of geologic carbon storage sites","authors":"Alexander C. Hanna ,&nbsp;Jonathan Whiting ,&nbsp;Brian Huang ,&nbsp;Delphine Appriou ,&nbsp;Xianjin Yang ,&nbsp;Julia de Toledo Camargo ,&nbsp;Seunghwan Baek ,&nbsp;Diana Bacon ,&nbsp;Catherine Yonkofski","doi":"10.1016/j.ijggc.2024.104157","DOIUrl":"https://doi.org/10.1016/j.ijggc.2024.104157","url":null,"abstract":"<div><p>Designs for Risk Evaluation and Management (DREAM) is a tool developed under the National Risk Assessment Partnership (NRAP) to enhance geologic carbon storage safety and efficiency. Using potential leakage scenarios generated externally by the users preferred history-matching approach, DREAM constructs ideal combinations of sensor locations in the right place at the right time to detect as many leaks as possible, detect them as early as possible, and minimize cost. This user-friendly tool, developed in Java, features a window-based GUI for input and a 3D visualization tool for viewing the domain space and optimized monitoring plans. DREAM's latest version accommodates real-world usage by allowing for joint optimization of wellbore point sensor placements and surface geophysics survey geometries, and by using more efficient multi-objective optimization algorithms. In an example shown here, these two improvements combined allow us to support containment assurance and go from detecting 80–90 % of the potential CO₂ leakage to +99.7 %, a step-change improvement that can make the deciding difference in whether a site is suitable for geologic carbon storage. Though developed for geologic carbon storage, this tool would be equally applicable in many surface or offshore environmental monitoring projects.</p></div>","PeriodicalId":334,"journal":{"name":"International Journal of Greenhouse Gas Control","volume":"135 ","pages":"Article 104157"},"PeriodicalIF":3.9,"publicationDate":"2024-05-22","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"141084599","PeriodicalName":null,"FirstCategoryId":null,"ListUrlMain":null,"RegionNum":3,"RegionCategory":"工程技术","ArticlePicture":[],"TitleCN":null,"AbstractTextCN":null,"PMCID":"","EPubDate":null,"PubModel":null,"JCR":null,"JCRName":null,"Score":null,"Total":0}

{"title":"The role of cryogenic carbon capture in future carbon-neutral societies","authors":"Hossein Asgharian ,&nbsp;Daniel Lemos Marques ,&nbsp;Florin Iov ,&nbsp;Vincenzo Liso ,&nbsp;Mads Pagh Nielsen ,&nbsp;Jakob Zinck Thellufsen ,&nbsp;Henrik Lund","doi":"10.1016/j.ijggc.2024.104161","DOIUrl":"https://doi.org/10.1016/j.ijggc.2024.104161","url":null,"abstract":"<div><p>Utilizing CO₂ capture technologies is an essential part of achieving a future carbon-neutral Society. So far, amine-based technologies, which are the most mature post-combustion CO₂ capture technologies, have been predominantly applied in large-scale CO₂ capture applications. However, the cryogenic process has also been proven to be a potential CO₂ capture technology suitable for large-scale applications. Cryogenic carbon capture offers two potential advantages over amine-based technology. First, the efficiency is higher and thus the energy penalty is lower. Next, the flexibility of system integration is also higher, and thus the technology carries the potential of better balancing variable renewable electricity productions. By using the software tool EnergyPLAN and dedicated scenarios of achieving a carbon-neutral Denmark, this paper quantitatively estimates these benefits. It is observed that, from a system perspective, utilizing cryogenic technologies to capture 90 % of CO₂ emissions in 2045 can reduce the demand for wind power by approximately 47 %, leading to a decrease in annual system costs by nearly 45 %.</p></div>","PeriodicalId":334,"journal":{"name":"International Journal of Greenhouse Gas Control","volume":"135 ","pages":"Article 104161"},"PeriodicalIF":3.9,"publicationDate":"2024-05-22","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"https://www.sciencedirect.com/science/article/pii/S175058362400104X/pdfft?md5=c917eaf2333463d2373389849b7a28d5&pid=1-s2.0-S175058362400104X-main.pdf","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"141078597","PeriodicalName":null,"FirstCategoryId":null,"ListUrlMain":null,"RegionNum":3,"RegionCategory":"工程技术","ArticlePicture":[],"TitleCN":null,"AbstractTextCN":null,"PMCID":"OA","EPubDate":null,"PubModel":null,"JCR":null,"JCRName":null,"Score":null,"Total":0}

{"title":"Criteria and workflow for selecting saline formations for carbon storage","authors":"Catherine Callas ,&nbsp;J. Steve Davis ,&nbsp;Sarah D. Saltzer ,&nbsp;Sam S. Hashemi ,&nbsp;Gege Wen ,&nbsp;Peter O. Gold ,&nbsp;Mark D. Zoback ,&nbsp;Sally M. Benson ,&nbsp;Anthony R. Kovscek","doi":"10.1016/j.ijggc.2024.104138","DOIUrl":"https://doi.org/10.1016/j.ijggc.2024.104138","url":null,"abstract":"<div><p>Carbon capture and storage (CCS) is an essential greenhouse gas mitigation strategy. Consolidating CO₂ sources and sinks can enable the widespread adoption of CCS, and the success of hub-scale projects depends on finding an appropriate sequestration complex. This work developed a criteria-driven framework to assess the potential suitability of saline formations for carbon storage. The workflow uses a three-stage process that screens, ranks, and characterizes potential saline storage formations based on three categories: (1) capacity and injectivity optimization, (2) retention and geomechanical risk minimization, and (3) siting and economic constraints. In this framework, data confidence has been incorporated into site ranking, which provides the user with information about the degree of uncertainty associated with the evaluation. The methodology can be applied to sites in various geological and geographical environments and incorporates general and project-specific criteria. This quantitative, criteria-driven approach was applied to two areas of interest in the Gulf of Mexico, and one site was identified for further assessment. In addition, this workflow was applied to four existing CCS projects— Sleipner, IBDP, In Salah, and Snøhvit—to see how they would have scored and ranked pre-development.</p></div>","PeriodicalId":334,"journal":{"name":"International Journal of Greenhouse Gas Control","volume":"135 ","pages":"Article 104138"},"PeriodicalIF":3.9,"publicationDate":"2024-05-21","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"141078599","PeriodicalName":null,"FirstCategoryId":null,"ListUrlMain":null,"RegionNum":3,"RegionCategory":"工程技术","ArticlePicture":[],"TitleCN":null,"AbstractTextCN":null,"PMCID":"","EPubDate":null,"PubModel":null,"JCR":null,"JCRName":null,"Score":null,"Total":0}

{"title":"Application of deep learning through group method of data handling for interfacial tension prediction in brine/CO2 systems: MgCl2 and CaCl2 aqueous solutions","authors":"G. Reza Vakili-Nezhaad,&nbsp;Reza Yousefzadeh,&nbsp;Alireza Kazemi,&nbsp;Ahmed Al Shaaili,&nbsp;Adel Al Ajmi","doi":"10.1016/j.ijggc.2024.104147","DOIUrl":"https://doi.org/10.1016/j.ijggc.2024.104147","url":null,"abstract":"<div><p>Capillary/residual CO₂ trapping is one of the main mechanisms of CO₂ storage in underground formations. Therefore, it is required to estimate the brine/CO₂ interfacial tension under different conditions. Although many methods have been proposed so far, the error of estimation is still high. This paper proposes a novel deep learning method to estimate the brine/CO₂ interfacial tension at various temperatures, pressures, and salinities. The proposed method is a neural network with the Group Method of Data Handling (GMDH) learning method. The GMDH has the advantage of handling the structural and parametric optimization of the network automatically. The proposed method is tested on an experimental dataset of brine/CO₂ interfacial tension with CalCl₂ and MgCl₂ salts. The results of the proposed method were compared with four of the best performing methods in the literature. The Average Absolute Percentage Error (AAPE) of the method on the training, testing and all data was 1.3 %, 2.95 %, 1.73 %, respectively, while the best method from the literature could reach an AAPE of 8.16 % on all data. Therefore, the proposed method performs far better than the existing methods. Also, a sensitivity analysis was done to determine the most influential inputs to estimate the output. The contribution of this work is to show the applicability of the GMDH method to construct more optimal data-driven models to estimate the brine/CO₂ interfacial tension. Also, the utilized dataset is collected under a wide range of pressure, temperature and salinity conditions that increases the generality of the model.</p></div>","PeriodicalId":334,"journal":{"name":"International Journal of Greenhouse Gas Control","volume":"135 ","pages":"Article 104147"},"PeriodicalIF":3.9,"publicationDate":"2024-05-17","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"141067091","PeriodicalName":null,"FirstCategoryId":null,"ListUrlMain":null,"RegionNum":3,"RegionCategory":"工程技术","ArticlePicture":[],"TitleCN":null,"AbstractTextCN":null,"PMCID":"","EPubDate":null,"PubModel":null,"JCR":null,"JCRName":null,"Score":null,"Total":0}

{"title":"Process optimization of high purity CO2 compression and purification system from oxygen-rich combustion flue gas","authors":"Lijin Ma ,&nbsp;Yawei Du ,&nbsp;Xiaojun Guo ,&nbsp;Wuao Zhou ,&nbsp;Huining Deng ,&nbsp;Shaofeng Zhang","doi":"10.1016/j.ijggc.2024.104146","DOIUrl":"https://doi.org/10.1016/j.ijggc.2024.104146","url":null,"abstract":"<div><p>The CO₂ compression and purification units (CO2CPU) is an effective process to capture CO₂ from oxygen-rich combustion flue gas. However, the quality of CO₂ products needs to be improved for high-value-added utilization. In this study, the CO2CPU with high concentration of impurities (SO_X, NO_X, H₂O) was optimized by Aspen Plus and Matlab with genetic algorithm. The model is validated with similar experiment from reference. The results showed that under the compressor pressure of 30 bar and condensation temperature of −36 °C, the liquid CO₂ product with a high purity of 99.9991 % with the total cost of 26.98 $/tCO₂ could be obtained. Sensitivity analysis was utilized to investigate the influences of key parameters on the system performance, including the number of plates of towers, pressure, reflux ratio, and gasification fraction. The required cooling capacity and performance of compressor are closely related to the ambient temperature. One impurities removal tower with sideline extraction was used to further improve the process performance. Energy consumption and total cost are reduced by 140.55 kW and 0.23 $/t CO₂, respectively. Methanol is introduced as the hydrate inhibitor for icing protection. Despite the additional three towers, the total cost is reduced by 1.86 % with heat coupling.</p></div>","PeriodicalId":334,"journal":{"name":"International Journal of Greenhouse Gas Control","volume":"135 ","pages":"Article 104146"},"PeriodicalIF":3.9,"publicationDate":"2024-05-16","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"140951501","PeriodicalName":null,"FirstCategoryId":null,"ListUrlMain":null,"RegionNum":3,"RegionCategory":"工程技术","ArticlePicture":[],"TitleCN":null,"AbstractTextCN":null,"PMCID":"","EPubDate":null,"PubModel":null,"JCR":null,"JCRName":null,"Score":null,"Total":0}

{"title":"Synergizing shale enhanced oil recovery and carbon sequestration: A novel approach with dual lateral horizontal wells","authors":"Khaled Enab,&nbsp;Ian Lopez,&nbsp;Youssef Elmasry","doi":"10.1016/j.ijggc.2024.104155","DOIUrl":"https://doi.org/10.1016/j.ijggc.2024.104155","url":null,"abstract":"<div><p>The dual challenge of enhancing oil recovery while sequestering carbon dioxide (CO₂) in oil reservoirs is a pivotal concern in the energy sector. CO₂ injection is recognized for its ability to decrease oil density and viscosity, thereby improving oil mobility and recovery rates. Traditionally, efforts have been concentrated either on enhancing oil recovery (EOR) or carbon storage, but not many efforts spent to couple EOR and CO₂ sequestration. Hence, novel techniques to optimize engineering designs to synergize EOR with CO₂ sequestration is the best approach to maximize the opportunities of storing emission gas and contribute to the global world decarbonization goals.</p><p>This study introduces an innovative dual lateral horizontal well design, aimed at simultaneously boosting oil recovery from shale reservoirs and enhancing CO₂ retention. By integrating a conceptual understanding of oil recovery mechanisms with empirical data from the field, this research contrasts the proposed dual lateral design with the conventional Huff-n-Puff gas injection technique, commonly employed in shale oil formations.</p><p>Our findings demonstrate that the dual lateral horizontal wells significantly outperform other injection methods in both oil recovery and CO₂ storage. Upon optimization, the dual lateral injection design continues to surpass the Huff-n-Puff method in terms of CO₂ storage, oil recovery, and net present value (NPV). This investigation not only presents innovative gas injection strategies in shale reservoirs but also provides insights into optimizing gas injection methods to enhance production efficiency and contribute to climate change mitigation through improved carbon capture and storage capacities.</p><p>Through comprehensive numerical simulations and empirical data analysis, the study explores the optimization of well spacing, revealing that a dual lateral well with optimized spacing between 20 and 30 feet achieves the best outcomes in terms of oil recovery, CO₂ retention, and net present value (NPV). The research presents a unique coupling of economic and environmental benefits, supported by economic analysis that includes the potential impact of CO₂ tax credits.</p><p>The novelty of this research is underscored by its integrated approach to CO₂-EOR, the development of a dual lateral well design, and the optimization of well spacings for maximized efficiency. By providing a scalable solution that is both economically viable and environmentally sustainable, this research contributes a significant paradigm shift in the field of EOR and CO₂ sequestration, with implications for policy and investment strategies in the energy sector. The findings propose a new direction for shale reservoir exploitation, promising to enhance production efficiency while contributing to global efforts in greenhouse gas reduction.</p></div>","PeriodicalId":334,"journal":{"name":"International Journal of Greenhouse Gas Control","volume":"135 ","pages":"Article 104155"},"PeriodicalIF":3.9,"publicationDate":"2024-05-16","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"https://www.sciencedirect.com/science/article/pii/S1750583624000987/pdfft?md5=7f7581da8d98bf3773f6376473c856b9&pid=1-s2.0-S1750583624000987-main.pdf","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"140951502","PeriodicalName":null,"FirstCategoryId":null,"ListUrlMain":null,"RegionNum":3,"RegionCategory":"工程技术","ArticlePicture":[],"TitleCN":null,"AbstractTextCN":null,"PMCID":"OA","EPubDate":null,"PubModel":null,"JCR":null,"JCRName":null,"Score":null,"Total":0}

{"title":"Relative permeability evolution with thermo-poromechanical process during N2 and scCO2 injection in brine saturated Deadwood sandstone from Aquistore","authors":"A. Haghi,&nbsp;R. Chalaturnyk","doi":"10.1016/j.ijggc.2024.104159","DOIUrl":"https://doi.org/10.1016/j.ijggc.2024.104159","url":null,"abstract":"<div><p>This study delves into the intrinsic and multiphase flow properties, specifically steady-state drainage relative permeability, of a subsurface Deadwood sandstone from the Aquistore CO₂ storage site in Canada. Consecutive core-flooding experiments were conducted utilizing N₂- and scCO₂-brine pairs across a broad range of temperatures (20–70 °C) and isotropic effective stress (0–30 MPa). Moreover, we monitored crack initiation and propagation of the sandstone during uniaxial loading at an elevated temperature using an integrated approach that combines microCT scanning with an in-situ heating/loading test. Our findings reveal a 54 % decrease and a 3 % increase in the absolute permeability of the sandstone through isothermal compaction followed by thermal expansion processes, respectively. Elevating the temperature from 20 °C to 70 °C results in a systematic 24 % increase in irreducible brine saturation and nearly doubles the end-point N₂ mobility, indicating an increased tendency of the rock surface towards the brine phase with temperature. Substituting N₂ with scCO₂ demonstrates a leftward shift in relative permeability and a decrease in irreducible brine saturation (from 0.36 to 0.31), consistent with low interfacial tension and the de-wetting effect during cyclic scCO₂-brine injections. Micro-CT image analysis reveals micro-crack initiation at 10 MPa stress and 70 °C temperature, suggesting that a mixed impact of induced cracks, dynamic wettability, and thermo-mechanical deformation is responsible for the substantial increase in well injectivity over time in Aquistore. This novel experimental program provides indispensable insight into thermo-poromechanical and wettability controls on multiphase flow at the Aquistore injection site in Canada, with potential applicability to similar scenarios globally.</p></div>","PeriodicalId":334,"journal":{"name":"International Journal of Greenhouse Gas Control","volume":"135 ","pages":"Article 104159"},"PeriodicalIF":3.9,"publicationDate":"2024-05-14","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"https://www.sciencedirect.com/science/article/pii/S1750583624001026/pdfft?md5=eb186c64966fb4e7df6a2f462e7e8ddb&pid=1-s2.0-S1750583624001026-main.pdf","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"140917853","PeriodicalName":null,"FirstCategoryId":null,"ListUrlMain":null,"RegionNum":3,"RegionCategory":"工程技术","ArticlePicture":[],"TitleCN":null,"AbstractTextCN":null,"PMCID":"OA","EPubDate":null,"PubModel":null,"JCR":null,"JCRName":null,"Score":null,"Total":0}

{"title":"Impacts of irregularly-distributed acidified brine flow on geo-chemo-mechanical alteration in an artificial shale fracture under differential stress","authors":"Samantha J. Fuchs ,&nbsp;Dustin Crandall ,&nbsp;Johnathan E. Moore ,&nbsp;Mayandi Sivaguru ,&nbsp;Bruce W. Fouke ,&nbsp;D. Nicolas Espinoza ,&nbsp;Ange-Therese Akono ,&nbsp;Charles J. Werth","doi":"10.1016/j.ijggc.2024.104127","DOIUrl":"https://doi.org/10.1016/j.ijggc.2024.104127","url":null,"abstract":"<div><p>The efficacy of geological carbon sequestration is reliant on the integrity of the caprock and its resistance to physical and chemical alteration. Caprocks with high abundance of reactive carbonates like calcite are susceptible to acid-promoted dissolution and can result in structural weakening. This work investigates the effect of acidified brine flow through an artificially fractured, high-carbonate (30 % by XRD) shale under differential compressive stress. Cylindrical samples were cut in half vertically and milled to create an artificial fracture with interlocking asperities and open channels. Samples were sheared with a single applied stress in a custom flow cell housed within an industrial CT scanner. Either acidic (pH 4) or reservoir-simulated (pH 9.5) brine was flowed through the artificial fracture for 7–8 days under reservoir pressure and room temperature. Model simulations indicate flow mainly occurred in open channels, with limited flow between overlapping asperities. Analysis of fracture surfaces by optical and scanning electron microscopy show increased surface alteration and roughness after exposure to pH 4 versus pH 9.5 brine indicating mineral dissolution/loss, and this effect is greater in areas that receive the highest brine flows. Similarly, surface analysis by scratch testing shows fracture toughness decreases more after exposure to acidic versus reservoir-simulated brine, with the greatest alteration in areas of highest acidic brine flows. Despite weakening, no shear slip occurred. Overall, the results indicate that acidified brine can result in significant physical and geomechanical alteration of irregular fracture surfaces in shale caprock, with greatest effects in preferential flow regions.</p></div>","PeriodicalId":334,"journal":{"name":"International Journal of Greenhouse Gas Control","volume":"135 ","pages":"Article 104127"},"PeriodicalIF":3.9,"publicationDate":"2024-05-14","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"140917852","PeriodicalName":null,"FirstCategoryId":null,"ListUrlMain":null,"RegionNum":3,"RegionCategory":"工程技术","ArticlePicture":[],"TitleCN":null,"AbstractTextCN":null,"PMCID":"","EPubDate":null,"PubModel":null,"JCR":null,"JCRName":null,"Score":null,"Total":0}