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The role of cryogenic carbon capture in future carbon-neutral societies 低温碳捕获在未来碳中和社会中的作用
IF 3.9 3区 工程技术 Q2 ENERGY & FUELS Pub Date : 2024-05-22 DOI: 10.1016/j.ijggc.2024.104161
Hossein Asgharian , Daniel Lemos Marques , Florin Iov , Vincenzo Liso , Mads Pagh Nielsen , Jakob Zinck Thellufsen , Henrik Lund

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 %.

利用二氧化碳捕集技术是实现未来碳中和社会的重要组成部分。迄今为止,胺类技术是最成熟的燃烧后二氧化碳捕获技术,主要应用于大规模二氧化碳捕获。不过,低温工艺也已被证明是一种适合大规模应用的潜在二氧化碳捕获技术。与基于胺的技术相比,低温碳捕集具有两个潜在优势。首先,效率更高,因此能源损耗更低。其次,系统集成的灵活性也更高,因此该技术有可能更好地平衡可再生能源发电量的变化。通过使用软件工具 EnergyPLAN 和实现丹麦碳中和的专用方案,本文对这些效益进行了量化估算。从系统角度来看,利用低温技术在 2045 年捕获 90% 的二氧化碳排放,可减少约 47% 的风电需求,从而使每年的系统成本降低近 45%。
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引用次数: 0
Criteria and workflow for selecting saline formations for carbon storage 选择碳封存盐层的标准和工作流程
IF 3.9 3区 工程技术 Q2 ENERGY & FUELS Pub Date : 2024-05-21 DOI: 10.1016/j.ijggc.2024.104138
Catherine Callas , J. Steve Davis , Sarah D. Saltzer , Sam S. Hashemi , Gege Wen , Peter O. Gold , Mark D. Zoback , Sally M. Benson , Anthony R. Kovscek

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.

碳捕集与封存(CCS)是一项重要的温室气体减排战略。整合二氧化碳源和汇可以促进 CCS 的广泛采用,而中心规模项目的成功取决于找到合适的封存综合体。这项工作开发了一个标准驱动框架,用于评估盐碱地层用于碳封存的潜在适宜性。该工作流程采用三阶段流程,根据三个类别对潜在的盐类封存地层进行筛选、排序和特征描述:(1)容量和注入率优化;(2)保留和地质力学风险最小化;(3)选址和经济限制。在这一框架中,数据置信度被纳入选址排名,为用户提供了与评估相关的不确定性程度的信息。该方法可应用于各种地质和地理环境中的地点,并包含一般标准和特定项目标准。这种以标准为导向的定量方法被应用于墨西哥湾的两个相关区域,其中一个地点被确定为需要进一步评估的地点。此外,该工作流程还应用于四个现有的 CCS 项目--Sleipner、IBDP、In Salah 和 Snøhvit,以了解它们在开发前的评分和排名情况。
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引用次数: 0
Application of deep learning through group method of data handling for interfacial tension prediction in brine/CO2 systems: MgCl2 and CaCl2 aqueous solutions 通过分组数据处理方法将深度学习应用于盐水/二氧化碳体系的界面张力预测:氯化镁和氯化钙水溶液
IF 3.9 3区 工程技术 Q2 ENERGY & FUELS Pub Date : 2024-05-17 DOI: 10.1016/j.ijggc.2024.104147
G. Reza Vakili-Nezhaad, Reza Yousefzadeh, Alireza Kazemi, Ahmed Al Shaaili, Adel Al Ajmi

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.

毛细管/残余二氧化碳捕集是地下地层封存二氧化碳的主要机制之一。因此,需要估算不同条件下盐水/CO2 的界面张力。虽然目前已经提出了很多方法,但估算误差仍然很大。本文提出了一种新型深度学习方法,用于估算不同温度、压力和盐度下的盐水/二氧化碳界面张力。该方法是一种采用数据处理组法(GMDH)学习方法的神经网络。GMDH 具有自动处理网络结构和参数优化的优点。所提出的方法在盐水/CO2 与 CalCl2 和 MgCl2 盐的界面张力实验数据集上进行了测试。将所提方法的结果与文献中性能最好的四种方法进行了比较。该方法在训练、测试和所有数据上的平均绝对百分比误差(AAPE)分别为 1.3%、2.95% 和 1.73%,而文献中最好的方法在所有数据上的平均绝对百分比误差可达 8.16%。因此,拟议方法的性能远远优于现有方法。此外,还进行了敏感性分析,以确定对估计输出影响最大的输入。这项工作的贡献在于展示了 GMDH 方法在构建更优化的数据驱动模型以估算盐水/二氧化碳界面张力方面的适用性。此外,所使用的数据集是在各种压力、温度和盐度条件下收集的,这增加了模型的通用性。
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引用次数: 0
Process optimization of high purity CO2 compression and purification system from oxygen-rich combustion flue gas 富氧燃烧烟气中高纯度二氧化碳压缩和净化系统的工艺优化
IF 3.9 3区 工程技术 Q2 ENERGY & FUELS Pub Date : 2024-05-16 DOI: 10.1016/j.ijggc.2024.104146
Lijin Ma , Yawei Du , Xiaojun Guo , Wuao Zhou , Huining Deng , Shaofeng Zhang

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 (SOX, NOX, 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.

二氧化碳压缩和净化装置(CO2CPU)是从富氧燃烧烟气中捕获二氧化碳的有效工艺。然而,为了实现高附加值利用,需要提高二氧化碳产品的质量。在本研究中,Aspen Plus 和 Matlab 利用遗传算法对高浓度杂质(SOX、NOX、H2O)的 CO2CPU 进行了优化。该模型与参考文献中的类似实验进行了验证。结果表明,在压缩机压力为 30 巴、冷凝温度为 -36 °C 的条件下,可以获得纯度为 99.9991 % 的液态 CO2 产品,总成本为 26.98 美元/tCO2。利用敏感性分析研究了关键参数对系统性能的影响,包括塔板数、压力、回流比和气化分数。压缩机所需的冷却能力和性能与环境温度密切相关。为了进一步提高工艺性能,使用了一个带侧线提取的杂质去除塔。能耗和总成本分别降低了 140.55 千瓦和 0.23 美元/吨 CO2。甲醇作为水合物抑制剂用于结冰保护。尽管增加了三个塔,但通过热耦合,总成本降低了 1.86%。
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引用次数: 0
Synergizing shale enhanced oil recovery and carbon sequestration: A novel approach with dual lateral horizontal wells 页岩强化采油与碳封存的协同作用:采用双横向水平井的新方法
IF 3.9 3区 工程技术 Q2 ENERGY & FUELS Pub Date : 2024-05-16 DOI: 10.1016/j.ijggc.2024.104155
Khaled Enab, Ian Lopez, Youssef Elmasry

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.

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.

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.

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.

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.

既要提高石油采收率,又要在油藏中封存二氧化碳(CO2),这是能源行业面临的双重挑战。注入二氧化碳能够降低石油密度和粘度,从而提高石油流动性和采收率,这一点已得到公认。传统上,人们一直致力于提高石油采收率(EOR)或碳封存,但将 EOR 与二氧化碳封存结合起来的努力并不多。因此,采用新技术优化工程设计,使采油与二氧化碳封存协同增效,是最大限度地利用封存排放气体的机会,为实现全球去碳化目标做出贡献的最佳方法。本研究介绍了一种创新的双侧向水平井设计,旨在同时提高页岩油藏的石油采收率和二氧化碳封存能力。通过将对采油机制的概念性理解与现场经验数据相结合,本研究将所提出的双侧向设计与页岩油层中常用的传统 Huff-n-Puff 注气技术进行了对比。经过优化,双侧向注气设计在二氧化碳封存、石油采收率和净现值(NPV)方面继续超越 Huff-n-Puff 方法。这项研究不仅提出了页岩油藏中的创新注气策略,还为优化注气方法提供了见解,以提高生产效率,并通过提高碳捕集与封存能力来减缓气候变化。通过全面的数值模拟和经验数据分析,该研究探讨了井距的优化问题,结果表明,优化井距在 20 至 30 英尺之间的双侧向井在石油采收率、二氧化碳保留率和净现值(NPV)方面取得了最佳成果。这项研究将经济效益和环境效益独特地结合在一起,并得到了包括二氧化碳税收抵免潜在影响在内的经济分析的支持。这项研究的新颖之处在于它采用了二氧化碳-EOR 的综合方法,开发了双侧向井设计,并优化了井距,以实现效率最大化。通过提供经济上可行、环境上可持续的可扩展解决方案,这项研究为 EOR 和二氧化碳封存领域的范式转变做出了重大贡献,并对能源领域的政策和投资战略产生了影响。研究结果为页岩储层开采提出了一个新方向,有望在提高生产效率的同时,为全球减少温室气体排放做出贡献。
{"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 (CO<sub>2</sub>) in oil reservoirs is a pivotal concern in the energy sector. CO<sub>2</sub> 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 CO<sub>2</sub> sequestration. Hence, novel techniques to optimize engineering designs to synergize EOR with CO<sub>2</sub> 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 CO<sub>2</sub> 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 CO<sub>2</sub> storage. Upon optimization, the dual lateral injection design continues to surpass the Huff-n-Puff method in terms of CO<sub>2</sub> 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, CO<sub>2</sub> 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 CO<sub>2</sub> tax credits.</p><p>The novelty of this research is underscored by its integrated approach to CO<sub>2</sub>-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 CO<sub>2</sub> 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}
引用次数: 0
Relative permeability evolution with thermo-poromechanical process during N2 and scCO2 injection in brine saturated Deadwood sandstone from Aquistore Aquistore 的盐水饱和 Deadwood 砂岩在注入 N2 和 scCO2 过程中的相对渗透率随热-孔-机械过程而变化
IF 3.9 3区 工程技术 Q2 ENERGY & FUELS Pub Date : 2024-05-14 DOI: 10.1016/j.ijggc.2024.104159
A. Haghi, R. Chalaturnyk

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.

本研究深入探讨了加拿大 Aquistore 二氧化碳封存场地下 Deadwood 砂岩的固有和多相流特性,特别是稳态排水相对渗透率。我们利用 N2-和 scCO2-盐水对在广泛的温度(20-70 °C)和各向同性有效应力(0-30 兆帕)范围内进行了连续的岩心充水实验。此外,我们还采用了一种将 microCT 扫描与原位加热/加载试验相结合的综合方法,对砂岩在高温单轴加载过程中的裂纹萌发和扩展进行了监测。我们的研究结果表明,通过等温压实和热膨胀过程,砂岩的绝对渗透率分别降低了 54% 和提高了 3%。温度从 20 °C 升至 70 °C 会导致不可还原盐水饱和度系统性地增加 24%,终点 N2 移动性几乎增加一倍,这表明随着温度的升高,岩石表面更倾向于盐水相。用 scCO2 替代 N2 后,相对渗透率左移,不可还原盐水饱和度降低(从 0.36 降至 0.31),这与低界面张力和循环注入 scCO2 盐水时的去湿效应是一致的。显微 CT 图像分析表明,在 10 兆帕应力和 70 °C 温度条件下会出现微裂缝,这表明诱导裂缝、动态润湿性和热机械变形的混合影响是 Aquistore 油井注入率随时间大幅提高的原因。这项新颖的实验计划为深入了解加拿大 Aquistore 注水井多相流的热孔隙力学和润湿性控制提供了不可或缺的信息,并有可能适用于全球类似情况。
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引用次数: 0
Impacts of irregularly-distributed acidified brine flow on geo-chemo-mechanical alteration in an artificial shale fracture under differential stress 差异应力下不规则分布的酸化盐水流对人工页岩断裂中地质-化学-力学变化的影响
IF 3.9 3区 工程技术 Q2 ENERGY & FUELS Pub Date : 2024-05-14 DOI: 10.1016/j.ijggc.2024.104127
Samantha J. Fuchs , Dustin Crandall , Johnathan E. Moore , Mayandi Sivaguru , Bruce W. Fouke , D. Nicolas Espinoza , Ange-Therese Akono , Charles J. Werth

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.

地质固碳的有效性取决于盖岩的完整性及其对物理和化学变化的抵抗力。含有大量方解石等活性碳酸盐的盖岩容易受到酸性物质的溶解作用,从而导致结构减弱。这项研究探讨了在压应力差作用下,酸化盐水流经人工断裂的高碳酸盐(XRD 为 30%)页岩的影响。将圆柱形样品垂直切成两半,然后进行铣削,以制造出具有交错突起和开放通道的人工断裂。样品在工业 CT 扫描仪内的定制流动池中以单一外加应力进行剪切。在储层压力和室温条件下,酸性(pH 值为 4)或储层模拟(pH 值为 9.5)盐水流经人工裂缝 7-8 天。模型模拟结果表明,盐水主要在开放通道中流动,重叠表面之间的流动有限。通过光学显微镜和扫描电子显微镜对断裂表面进行的分析表明,在 pH 值为 4 的盐水与 pH 值为 9.5 的盐水作用下,断裂表面的变化和粗糙度增加,表明矿物质溶解/流失,而且在盐水流量最大的区域,这种影响更大。同样,通过划痕测试进行的表面分析表明,接触酸性盐水与接触储层模拟盐水后,断裂韧性的下降幅度更大,在酸性盐水流量最大的区域,断裂韧性的变化最大。尽管有所减弱,但没有发生剪切滑移。总之,研究结果表明,酸化盐水会对页岩毛岩中的不规则断裂表面造成显著的物理和地质力学改变,在优先流动区域的影响最大。
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引用次数: 0
Investigation of chemical processes in cement exposed to wet ScCO2 and CO2-saturated brine in geological CO2 storage conditions 调查在二氧化碳地质封存条件下水泥暴露于湿ScCO2和二氧化碳饱和盐水中的化学过程
IF 3.9 3区 工程技术 Q2 ENERGY & FUELS Pub Date : 2024-05-13 DOI: 10.1016/j.ijggc.2024.104143
Kaiyuan Mei , Liwei Zhang , Yuna Cai , Ting Xiao , Quan Xue , Yan Wang , Qiang Sun , Brian McPherson

In geological CO2 storage conditions, wellbore cement can be exposed to both supercritical CO2 (ScCO2) with water vapor, and CO2 dissolved in water. There is a lack of studies that investigate the effects of reaction environments on the extent of CO2-induced cement carbonation and leaching. In this study, four CO2 exposure experiments were designed with wellbore cement samples exposed to both ScCO2 and CO2 dissolved in water to investigate the impacts of evaporation, capillarity, diffusion, and salt deposition on cement carbonation. Severe cement carbonation after 14 and 28 days of CO2 exposure was observed in a wet ScCO2 phase. When water evaporation into ScCO2 phase was minimized by a steel plate between the brine phase and the ScCO2 phase, a strong cement carbonation in ScCO2 phase was still visible. The reason was that imbibition and diffusion drove water to migrate from the lower section to the upper section of the cement sample to participate in the carbonation reaction. The level of cement carbonation in different CO2 exposure environments was ranked as: wet ScCO2 > CO2 dissolved in water > Pure-ScCO2. The corresponding maximum carbonation area ratios were 90 % and 38 % for the wet ScCO2 scenario and the brine scenario, respectively, compared with a maximum carbonation area ratio of 20 % for the Pure-ScCO2 scenario. This study implies that the most altered region in wellbore cement is at the ScCO2—water interface, and the expansion rate of the altered region is the key to evaluate the potential for CO2 leakage through wellbore cement.

在二氧化碳地质封存条件下,井筒水泥可能会接触到含有水蒸气的超临界二氧化碳(ScCO2)和溶于水的二氧化碳。目前还没有研究调查反应环境对二氧化碳诱导的水泥碳化和沥滤程度的影响。本研究设计了四次二氧化碳暴露实验,将井筒水泥样品暴露在 ScCO2 和溶于水的二氧化碳中,以研究蒸发、毛细管、扩散和盐沉积对水泥碳化的影响。在潮湿的 ScCO2 阶段,二氧化碳暴露 14 天和 28 天后观察到严重的水泥碳化现象。在盐水相和 ScCO2 相之间用钢板隔开,以尽量减少水分蒸发到 ScCO2 相中,但在 ScCO2 相中仍能看到强烈的水泥碳化现象。原因是浸润和扩散促使水从水泥样品的下部迁移到上部参与碳化反应。在不同的二氧化碳暴露环境中,水泥碳化程度依次为:湿ScCO2 >;溶于水的二氧化碳 >;纯ScCO2。湿ScCO2情景和盐水情景的相应最大碳化面积比分别为90%和38%,而纯ScCO2情景的最大碳化面积比为20%。这项研究表明,井筒水泥中变化最大的区域位于 ScCO2-水界面,而变化区域的膨胀率是评估二氧化碳通过井筒水泥泄漏的可能性的关键。
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引用次数: 0
Post-combustion carbon capture process modeling, simulation, and assessment of synergistic effect of solvents 燃烧后碳捕获过程建模、模拟和溶剂协同效应评估
IF 3.9 3区 工程技术 Q2 ENERGY & FUELS Pub Date : 2024-05-12 DOI: 10.1016/j.ijggc.2024.104145
Dalal Alalaiwat , Ezzat Khan

Post-combustion carbon capture appears to be a promising solution to reduce the emission of carbon dioxide (CO2) from power plants that generate electricity using either coal or natural gas. In addition, carbon capture process efficiency, capacity, and energy consumption have become challenging against the performance of the capture process. However, synergistic effect due to solvents blend has gained attention to reduce the process energy consumption and enhance process efficiency. In this study, blends of methyldiethanolamine (MDEA) and piperazine (PZ) at different concentrations were investigated using a validated post-combustion capture process model using Aspen HYSYS. Results were compared with 30 wt% monoethanolamine (MEA) as reference case. The effective process variables are concentration of solvents, the amount of water and solvent in the makeup section, viscosity of solvent, energy consumed in different process stages, and the amount of lean solvent flow rate. These variables were studied against fixed process variables using rate-based model. The study shows that using (43 wt% MDEA/7 wt% PZ) for post-combustion carbon capture needs 2.53 MJ/kgCO2 regeneration energy for 88.5% process efficiency compared to 4.003 MJ/kgco2 for 30 wt% MEA without the need for any process modifications. In addition, it was found that solvents synergistic effect contributes to resolving the drawbacks of post-combustion capture that will enable the high utilization of the process and contribution to reduce the consequences effect of climate change. Therefore, the study will help policymakers, industries and encourage researchers towards the large-scale commissioning of blended solvent -based post-combustion capture process.

燃烧后碳捕集似乎是减少使用煤炭或天然气发电的发电厂二氧化碳(CO2)排放的一个很有前景的解决方案。此外,碳捕集过程的效率、产能和能耗也对捕集过程的性能提出了挑战。然而,混合溶剂所产生的协同效应在降低工艺能耗和提高工艺效率方面受到了关注。在本研究中,使用 Aspen HYSYS 验证了燃烧后捕集工艺模型,对不同浓度的甲基二乙醇胺(MDEA)和哌嗪(PZ)混合物进行了研究。研究结果与 30 wt% 的一乙醇胺 (MEA) 作为参考案例进行了比较。有效工艺变量包括溶剂浓度、补给段的水量和溶剂量、溶剂粘度、不同工艺阶段消耗的能量以及贫溶剂流量。利用基于速率的模型,针对固定工艺变量对这些变量进行了研究。研究表明,使用(43 wt% MDEA/7 wt% PZ)进行燃烧后碳捕集需要 2.53 MJ/kgCO2 的再生能量,工艺效率为 88.5%,而使用 30 wt% MEA 则需要 4.003 MJ/kgco2,无需对工艺进行任何修改。此外,研究还发现,溶剂的协同效应有助于解决燃烧后捕集的弊端,从而提高工艺的利用率,并有助于减少气候变化的后果。因此,这项研究将有助于政策制定者、工业界和鼓励研究人员大规模投入使用基于混合溶剂的燃烧后捕集工艺。
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引用次数: 0
Energy optimization of a non-aqueous solvent CO2 absorption system with pressure swing regeneration 具有变压再生功能的非水溶剂二氧化碳吸收系统的能量优化
IF 3.9 3区 工程技术 Q2 ENERGY & FUELS Pub Date : 2024-05-09 DOI: 10.1016/j.ijggc.2024.104154
Chairunnisa , Yingxin Zhou , Yitong Wu , Cheng You , Kyaw Thu , Takahiko Miyazaki , Yusuke Uehara , Hiroshi Machida , Koyo Norinaga

This study focuses on optimizing the energy requirement in the post-combustion CO2 capture system using pressure swing regeneration through a model-based design (MBD). The simulation results highlight the significant impact of CO2 recovery, inlet gas and liquid flow rate, and CO2 concentration in the flue gas on the overall energy demand of the system. Moreover, an investigation into the de-sublimation chamber was undertaken, revealing a relationship between dry ice formation and the heat transfer between the LNG stream and CO2 in the heat exchanger. The parametric analysis study reveals that the sensible heat of the lean solvent is significantly influenced by the CO2 concentration in the liquid, consequently affecting the overall system energy. According to the results, the utilization of cold energy from LNG could save 80 % of the total energy requirement. The optimization results found the best working condition, which consumes energy of 0.190 GJ/ton CO2, 31 % lower than the basic scenario.

本研究的重点是通过基于模型的设计(MBD),优化使用变压再生技术的燃烧后二氧化碳捕集系统的能源需求。模拟结果表明,二氧化碳回收率、入口气体和液体流速以及烟气中的二氧化碳浓度对系统的总体能源需求有重大影响。此外,还对脱升华室进行了调查,发现干冰的形成与热交换器中液化天然气流和二氧化碳之间的热传递之间存在关系。参数分析研究表明,贫溶剂的显热受液体中二氧化碳浓度的显著影响,从而影响整个系统的能量。结果表明,利用液化天然气的冷能可节省 80% 的总能源需求。优化结果发现了最佳工作条件,其能耗为 0.190 GJ/吨二氧化碳,比基本方案低 31%。
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引用次数: 0
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International Journal of Greenhouse Gas Control
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