International Journal of Greenhouse Gas Control最新文献

A smart injection optimization for CO₂ sequestration: ensuring storage integrity through adaptive control and real-time monitoring 针对CO₂封存的智能注入优化：通过自适应控制和实时监控确保存储完整性

IF 5.2 3区工程技术 Q2 ENERGY & FUELS

International Journal of Greenhouse Gas Control

Pub Date : 2025-12-11 DOI: 10.1016/j.ijggc.2025.104542

Ahmed Ali Shanshool Alsubaih, Kamy Sepehrnoori, Mojdeh Delshad

The oil and gas industry is undergoing a transformative shift towards digital and smart fields, driven by the integration of artificial intelligence (AI), machine learning (ML), and real-time data analytics. Within this context, the novelty of this study lies in the development of an adaptive smart injection system for CO₂ sequestration that integrates real-time monitoring with advanced control strategies. Unlike conventional injection schemes that rely on pre-defined injection plans, the proposed framework dynamically adjusts injection parameters to optimize storage efficiency while mitigating leakage risks. A fully three-dimensional reservoir model with three injection wells and one legacy well is simulated over 5 years of injection followed by 50 years of storage, using a commercial reservoir simulator coupled to Python-based supervisory control. Three control strategies Proportional Integral Derivative (PID) control, Reinforcement Learning (RL), and Genetic Algorithm (GA) based optimization are compared under a conservative bottom-hole pressure limit tied to the fracture gradient. In an uncontrolled case, 10.2 % of the injected CO₂ leaks through the legacy well. The smart injection framework reduces this leakage to 2.8 % with PID, 2.0 % with GA, and 1.6 % with RL, corresponding to an 84 % reduction for RL relative to the baseline. RL provides the greatest average leakage reduction and most adaptive response to changing reservoir conditions, whereas GA offers slightly higher leakage but the most consistent performance across realizations; PID serves as a simple benchmark with limited adaptability. These results demonstrate that AI- and optimization-driven control can substantially enhance CO₂ storage security and operational efficiency, with direct transferability to waterflooding, enhanced oil recovery, and underground gas storage operations.

在人工智能（AI）、机器学习（ML）和实时数据分析的整合推动下，油气行业正在经历向数字化和智能领域的转型。在此背景下，本研究的新颖之处在于开发了一种用于二氧化碳封存的自适应智能注入系统，该系统将实时监测与先进的控制策略相结合。与依赖预定义注入计划的传统注入方案不同，该框架动态调整注入参数，以优化储存效率，同时降低泄漏风险。利用商业油藏模拟器和基于python的监控系统，模拟了一个全三维油藏模型，包括3口注水井和1口旧井，注入时间为5年，储存时间为50年。在与裂缝梯度相关的保守井底压力限制下，比较了比例积分导数（PID）控制、强化学习（RL）和基于遗传算法（GA）的优化三种控制策略。在不受控制的情况下，10.2%的注入二氧化碳通过旧井泄漏。智能注入框架将PID、GA和RL的泄漏量分别减少到2.8%、2.0%和1.6%，与基线相比，RL减少了84%。RL提供了最大的平均泄漏减少和对不断变化的油藏条件的最适应性响应，而GA提供了略高的泄漏，但在各个实现中性能最一致；PID作为一种简单的基准，适应性有限。这些结果表明，人工智能和优化驱动的控制可以大大提高CO₂储存的安全性和作业效率，并可直接应用于水驱、提高采收率和地下储气作业。

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引用次数: 0

Interoperability and energy optimization in low pressure ship to medium pressure terminal interfacing 低压船舶与中压终端接口的互操作性与能量优化

IF 5.2 3区工程技术 Q2 ENERGY & FUELS

International Journal of Greenhouse Gas Control

Pub Date : 2025-12-11 DOI: 10.1016/j.ijggc.2025.104544

Panos Deligiannis , Vangelis Karageorgos , Paraskevi Bardavillia , Chara Georgopoulou

Large-scale deployment of Carbon Capture and Storage (CCS) is essential to meet global climate change mitigation goals, with CO₂ shipping playing an important role in enabling cost-effective transport from dispersed sources to storage sites. However, transporting CO₂ is facing interoperability challenges due to the absence of standardized specifications for transport conditions, including state (gas, liquid, or dense phase), pressure and temperature levels.

To address this, the authors propose a compatibility framework between Low Pressure (LP, 7–10 bara) ships and Medium Pressure (MP, 12–20 bara) terminals, serving liquefied CO₂ (LCO₂) shipping. The aim is to identify machinery systems and operating strategies that ensure cost-effective LCO₂ transfer. A thermodynamic model is used to simulate and optimize performance during loading and discharging operations, by quantifying energy and equipment needs and proposing ship-terminal interface solutions. The model is applied in a case study featuring a ship with three 7300 m³ tanks (simulated range: 5840–8760 m³) and evaluated across varying pressures, temperatures, and flow rates. The study concludes that:

•
During LP discharging, the LCO₂ is pressurized and heated to MP saturation conditions. To reduce vapor displacement from the terminal tank, subcooled inlet conditions are applied. Vapor returned to the ship is cooled via heat integration before being depressurized to LP.
•
During MP loading, the fluid stream is depressurized to LP, requiring subcooling to avoid two-phase flow and excessive vapor return. A sub-cooler reduces vapor displacement but demands more energy than a high-capacity vapor return compressor.

碳捕集与封存（CCS）的大规模部署对于实现全球气候变化减缓目标至关重要，二氧化碳运输在实现从分散的碳源到储存地点的成本效益运输方面发挥着重要作用。然而，由于缺乏运输条件（包括状态（气体、液体或致密相）、压力和温度水平）的标准化规范，二氧化碳运输面临互操作性挑战。为了解决这个问题，作者提出了低压（LP, 7-10 bara）船舶和中压（MP, 12-20 bara）码头之间的兼容性框架，用于液化CO₂（LCO₂）运输。目的是确定机械系统和操作策略，确保具有成本效益的LCO₂转移。通过量化能源和设备需求，并提出船舶码头接口解决方案，使用热力学模型来模拟和优化装卸作业过程中的性能。该模型应用于一个具有三个7300 m³储罐（模拟范围：5840-8760 m³）的船舶的案例研究中，并在不同的压力、温度和流量下进行了评估。研究得出结论：•在LP放电过程中，LCO₂被加压并加热到MP饱和状态。为了减少末端储罐的蒸汽位移，采用过冷进口条件。返回到船上的蒸汽在降压到低压之前通过热集成冷却。•在MP加载过程中，流体流被降压至低压，需要过冷以避免两相流动和过多的蒸汽回流。亚冷却器减少蒸汽排量，但比高容量蒸汽回流压缩机需要更多的能量。

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引用次数: 0

CO2 storage evaluation combined with oil recovery in depleted gulf of America reservoirs 美国枯竭海湾油藏CO2储量评价与采收率的结合

IF 5.2 3区工程技术 Q2 ENERGY & FUELS

International Journal of Greenhouse Gas Control

Pub Date : 2025-12-11 DOI: 10.1016/j.ijggc.2025.104553

Manohar Gaddipati, Elif Agartan, Can Yetkin, Bill Savage, Chet Ozgen

Enhanced Oil Recovery techniques using carbon dioxide (CO₂-EOR) focus primarily on oil production with CO₂ storage being an incidental benefit. In contrast, EOR with Carbon Capture and Storage (CCS-EOR) combines oil recovery with the explicit objective of capturing and storing anthropogenic CO₂ to reduce emissions. As part of a DOE-funded project, 461 depleted oil and gas reservoirs in the Gulf of America were analyzed and CO₂ storage correlations were developed and published in 2018. This study extends that foundational work in two phases: quantifying and comparing the storage benefits of CCS-EOR operations with those achieved through conventional CO₂ injection in selected fields, and refining storage capacity estimates by incorporating practical operational constraints through staging analysis, which involves strategic completion of injection wells while eliminating unsuitable sands based on operational considerations.

Ten reservoir sands across nine depleted federal offshore fields were selected for detailed evaluation based on storage capacity, oil recovery potential, available data, and reservoir properties. Simulation models were developed using data from the Bureau of Ocean Energy Management (BOEM). CCS-EOR operations consistently achieve higher storage volumes than conventional CO₂ storage, with total storage capacities ranging from 10.4 Bscf (0.54 MM tons) to 137.9 Bscf (7.19 MM tons). The incremental storage benefit ranges from 5.24 Bscf (0.27 MM tons) to 71.56 Bscf (3.73 MM tons). This enhanced performance results from two primary mechanisms: maintaining lower reservoir pressures through continuous production and improving CO₂ sweep efficiency compared to conventional storage. Primary oil recovery ranges from 0.2 % to 30.2 %, while incremental recovery factors from CCS-EOR operations vary from 46.3 % to 87.8 %. The wide range in recovery performance reflects low primary recovery creating greater recovery potential, homogeneous reservoir modeling assumptions that may overestimate sweep efficiency, and uncertainties in critical parameters such as minimum miscibility pressure.

Sensitivity analysis of well configurations, residual oil saturation at CO₂ miscibility, CO₂ availability, and reservoir heterogeneity shows that CCS-EOR provides greater storage capacity but introduces higher operational uncertainty. Stochastic analysis demonstrates that geological heterogeneity reduces oil recovery by 28–50 % compared to homogeneous models. Staging analysis applied to 3514 depleted formations reduces prospective storage resources from 79,811 Bscf (4162 MM tons) to 46,362 Bscf (2418 MM tons), representing a 58 % reduction, with gas sands experiencing the highest losses particularly in low permeability-thickness formations.

使用二氧化碳（CO₂-EOR）的提高石油采收率技术主要关注石油生产，CO₂储存是附带的好处。相比之下，碳捕集与封存技术（CCS-EOR）将采油与捕获和储存人为二氧化碳的明确目标结合起来，以减少排放。作为美国能源部资助项目的一部分，研究人员分析了美国湾461个枯竭的油气储层，并于2018年开发并发布了二氧化碳储存相关性。本研究将基础工作扩展为两个阶段：量化和比较CCS-EOR操作与选定油田常规CO 2注入所获得的存储效益，并通过分级分析结合实际操作约束，改进存储容量估算，包括根据操作考虑，战略性完井注水井，同时消除不合适的砂粒。根据储层容量、采收率潜力、现有数据和储层性质，选择了9个枯竭的联邦海上油田的10个储层砂进行详细评估。利用海洋能源管理局（BOEM）的数据建立了模拟模型。CCS-EOR作业始终比传统的CO₂存储获得更高的存储容量，总存储容量从10.4 Bscf （0.54 MM吨）到137.9 Bscf （7.19 MM吨）不等。增加的储存效益从5.24立方英尺（0.27毫米吨）到71.56立方英尺（3.73毫米吨）不等。这种性能的提高源于两个主要机制：通过连续生产保持较低的油藏压力，与传统储存相比，提高了CO 2清除效率。一次采收率为0.2% ~ 30.2%，而CCS-EOR作业的增量采收率为46.3% ~ 87.8%。采收率的大范围反映了初级采收率低而采收率潜力大，均质油藏建模假设可能高估波及效率，以及最小混相压力等关键参数的不确定性。对油井配置、CO₂混相残余油饱和度、CO₂有效性和储层非均质性的敏感性分析表明，CCS-EOR提供了更大的存储容量，但也带来了更高的操作不确定性。随机分析表明，与均质模型相比，地质非均质模型的采收率降低了28 - 50%。对3514个枯竭地层进行了分级分析，预期储量从79811立方英尺（4162毫米吨）减少到46362立方英尺（2418毫米吨），减少了58%，其中含气砂的损失最大，特别是在低渗透厚度地层。

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引用次数: 0

A workflow for estimating injection pressure limits for CO2 storage: A reservoir-geomechanical analysis of a candidate site in the German North Sea sector 估算CO2储层注入压力极限的工作流程：对德国北海某候选区块进行储层地质力学分析

IF 5.2 3区工程技术 Q2 ENERGY & FUELS

International Journal of Greenhouse Gas Control

Pub Date : 2025-12-10 DOI: 10.1016/j.ijggc.2025.104534

Firdovsi Gasanzade , Hendrawan Diandaru Bayu Aji , Frank Wuttke , Sebastian Bauer

Geological carbon capture and storage (CCS) in saline formations is seen as a plausible short-term solution to reduce atmospheric carbon dioxide (CO₂) concentrations and mitigate climate change. Besides storage capacity, largely determined by pore space within a geological trap, the maximum allowable pressure in the storage formation represents a major limitation for geological CO₂ storage. This study, therefore, addresses the hydromechanical aspects of geological CO₂ storage by developing an integrated workflow to determine site-specific injection pressure limits and applying it to a potential storage site in the German North Sea sector. The workflow ensures consistency between reservoir flow and geomechanical models by automatically extracting near-wellbore geomechanical domains from the large-scale model. For a vertical well, the site-specific injection pressure limit is estimated at 17.9 MPa/km, governed by tensile failure in the storage formation. Within the cap rock, the limit increases to 28.6 MPa/km, providing a large margin of safety and enabling higher injection rates. A horizontal well configuration yields a slightly higher limit of 19.7 MPa/km, due to the larger well-reservoir contact area and improved pressure dissipation. The derived pressure limits are subsequently implemented in a large-scale dynamic simulation to verify workflow performance and assess formation integrity. Results indicate that injection rates of approximately 1.7 Mt CO₂ per year per vertical well can be sustained over 30 years, with reservoir overpressure and the corresponding stress states strongly dependent on the hydraulic setting of the reservoir. Importantly, injection-induced stresses and thus the probability of fracture formation decreases rapidly after CO₂ injection ends.

地质碳捕集与封存（CCS）技术被认为是降低大气二氧化碳（CO 2）浓度和减缓气候变化的一种可行的短期解决方案。除了储存能力（主要由地质圈闭内的孔隙空间决定）之外，储存地层中的最大允许压力是地质CO₂储存的主要限制因素。因此，该研究通过开发一个集成的工作流程来确定特定地点的注入压力限制，并将其应用于德国北海地区的潜在储存地点，从而解决了地质CO₂储存的流体力学方面的问题。该工作流程通过自动从大尺度模型中提取近井地质力学域，确保了油藏流动和地质力学模型之间的一致性。对于直井来说，受储层拉伸破坏的影响，现场特定的注入压力极限估计为17.9 MPa/km。在盖层中，极限增加到28.6 MPa/km，提供了很大的安全裕度，并实现了更高的注入速率。水平井的极限略高，为19.7 MPa/km，因为井-储层接触面积更大，压力消散效果更好。随后，将导出的压力极限应用于大规模动态模拟，以验证工作流程的性能并评估地层完整性。结果表明，每口直井每年约1.7 Mt CO₂的注入速度可以持续30年以上，而储层超压和相应的应力状态强烈依赖于储层的水力环境。重要的是，在CO 2注入结束后，注入引起的应力和裂缝形成的可能性迅速降低。

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引用次数: 0

Physics-coupled machine learning toolset for geological carbon storage evaluation and performance analysis 用于地质碳储量评估和性能分析的物理耦合机器学习工具集

IF 5.2 3区工程技术 Q2 ENERGY & FUELS

International Journal of Greenhouse Gas Control

Pub Date : 2025-12-09 DOI: 10.1016/j.ijggc.2025.104538

Guoxiang Liu , Xiongjun Wu , Chung-Yan Shih , Veronika Vasylkivska , Hema Siriwandane , Grant Bromhal

A comprehensive toolset that can provide fast and accurate design, survey, planning, monitoring, and evaluation of behaviors and responses in the reservoir field is essential to achieve successful geological carbon capture and storage (CCS) development and operations, with or without enhanced hydrocarbon recovery. Based on the physics of material balance between injection and extraction, the Capacitance Resistance Model (CRM) method can perform rapid history matching (HM), forecasting, and optimizations in operational scale. Such capabilities provide key operational guidance to users with insights of an individual well regarding its injection/extraction and bottom hole pressure (BHP), as well as inter-well connectivity of multiple wells in the field along with its flexible time-window capability for operation planning and development. Moreover, advanced artificial intelligence (AI)/machine learning (ML) models developed for the virtual learning environment (VLE) are also coupled with the workflow to provide detailed three-dimensional reservoir field responses that are essential to the geological CCS monitoring and evaluation of the optimal reservoir management and risk reduction. The proposed approach with physics-informed ML demonstrates the value for emerging “SMART” field operations and reservoir management with three to four orders of magnitude speed-up in computational time in a real-time and near real-time fashion. Innovatively coupling CRM and virtual learning together brings a dual benefit for both rapid operational focus in field applications and drilling down to the detailed three-dimensional of reservoir evolutions. Such provides insights and comprehensive understanding for CO₂ storage and other application potentials such as oil & gas, geothermal, and hydrogen applications.

无论是否提高油气采收率，能够提供快速、准确的设计、调查、规划、监测和评估储层行为和响应的综合工具集对于实现地质碳捕集与封存（CCS）开发和操作的成功至关重要。基于注入和萃取之间物质平衡的物理特性，电容电阻模型（CRM）方法可以在操作规模上进行快速历史匹配（HM）、预测和优化。这种能力为用户提供了关键的操作指导，可以了解单口井的注入/提取和井底压力（BHP），以及油田中多口井的井间连通性，并具有灵活的时间窗口能力，可以进行作业规划和开发。此外，为虚拟学习环境（VLE）开发的先进人工智能(AI)/机器学习（ML）模型也与工作流程相结合，提供详细的三维油藏现场响应，这对于地质CCS监测和评估最佳油藏管理和降低风险至关重要。基于物理信息的机器学习方法展示了新兴的“SMART”现场作业和油藏管理的价值，实时和接近实时的计算时间加快了3到4个数量级。创新地将CRM和虚拟学习结合在一起，为现场应用的快速操作重点和深入到油藏演化的详细三维钻井带来双重好处。这为二氧化碳储存和其他应用潜力（如石油和天然气、地热和氢应用）提供了见解和全面的理解。

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引用次数: 0

Enhanced hydrogeochemical baseline of a CO2 injection facility in southern Alberta, Canada 加拿大阿尔伯塔省南部二氧化碳注入设施的水文地球化学基线增强

IF 5.2 3区工程技术 Q2 ENERGY & FUELS

International Journal of Greenhouse Gas Control

Pub Date : 2025-12-05 DOI: 10.1016/j.ijggc.2025.104545

Nicholas Utting , Kirk G. Osadetz , Bernhard Mayer , Tiago Morais , Stuart M.V. Gilfillan , Michael Nightingale , Thomas Darrah , Emma Martin-Roberts , Don Lawton

Geological storage of CO₂ is anticipated to play a significant role in the management and reduction of greenhouse gas emissions. Monitoring of CO₂ injection facilities is essential to provide reassurance of the containment of the injected CO₂. Here, we report results over six years (2018–2023) for a hydrogeological and geochemical (gas compositions, δ¹³C_CH4, δ¹³C_CO2, δ²H_CH4 and noble gas concentration and isotopes) monitoring program at a small-scale CO₂ injection facility located near Brooks, Alberta, Canada with injection ∼300 m below ground. The results provide a comprehensive record of the subsurface hydrological and geochemical conditions over the six-year period. Injected CO₂ was not detected in samples from the injection zone. There was also no indication of injected CO₂ in samples collected from surface casing vents of the three ∼300 m deep wells, nor was injected CO₂ observed in samples from the six shallow groundwater wells (<105 m deep). Various compositional and isotopic changes have been observed over time which are interpreted to either be indirectly related to CO₂ injection or completely unrelated indicating non-CO₂ injection related variability in the baseline conditions of the site. Additionally, a progressive reduction in hydraulic head has been observed in some shallow aquifers consistent with drought conditions in the region. Our study implies that complex subsurface changes may occur at CO₂ storage sites which may be unrelated to human activity, complicating the monitoring of CO₂ injection.

预计二氧化碳的地质储存将在管理和减少温室气体排放方面发挥重要作用。对二氧化碳注入设施的监测对于确保注入的二氧化碳的密封至关重要。在这里，我们报告了在加拿大阿尔伯塔省布鲁克斯附近的一个小型二氧化碳注入设施进行的六年（2018-2023）水文地质和地球化学（气体成分，δ13CCH4, δ13CCO2， δ2HCH4和惰性气体浓度和同位素）监测计划的结果，该设施位于地下约300 m处。研究结果提供了六年来地下水文和地球化学条件的综合记录。注入区样品中未检测到注入的二氧化碳。从3 ~ 300米深井的地表套管喷口采集的样品中也没有发现注入的二氧化碳，从6口浅层地下水井（105米深）采集的样品中也没有观察到注入的二氧化碳。随着时间的推移，已经观察到各种成分和同位素的变化，这些变化被解释为与二氧化碳注入间接相关或完全无关，表明该地点基线条件下与二氧化碳注入无关的变化。此外，在一些浅层含水层观察到水力水头逐渐减少，这与该地区的干旱条件相一致。我们的研究表明，二氧化碳储存地点可能发生复杂的地下变化，这些变化可能与人类活动无关，从而使二氧化碳注入的监测复杂化。

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引用次数: 0

Feasibility of subsurface storage of hydrochar in the Netherlands as carbon dioxide removal technique 荷兰地下储存碳氢化合物作为二氧化碳去除技术的可行性

IF 5.2 3区工程技术 Q2 ENERGY & FUELS

International Journal of Greenhouse Gas Control

Pub Date : 2025-12-05 DOI: 10.1016/j.ijggc.2025.104539

Timothy F. Baars , Hemmo A. Abels , Anne-Catherine A.M. Dieudonné , Joachim B. Hanssler , Sebastian Geiger

Hydrothermal carbonisation enables the conversion of wet biomass into hydrochar, a carbon-rich solid with potential for durable carbon dioxide removal (CDR). While hydrochar has been studied extensively for topics as soil application or wastewater treatment, its role in subsurface storage remains underexplored. This study examines the feasibility of hydrochar-based biomass carbon removal and storage (BiCRS) in the Netherlands, where abundant wet biomass and well-developed subsurface infrastructure offer a promising deployment context. We characterise the chemical and mechanical properties of manure-derived hydrochar and evaluate seven potential storage configurations, from abandoned coal mines to quarry lakes and lightweight fill applications, based on technical feasibility, environmental risk, and long-term containment. Our findings identify two priority pathways: storage in salt caverns and use as lightweight filling material for land elevation. A third pathway, storage in sand quarry lakes, also holds potential, though additional safeguards and site-specific assessments are needed to ensure environmental integrity and carbon retention. Hydrochar’s compatibility with wet, low-value feedstocks and potential for decentralised implementation position it as a flexible addition to the CDR portfolio. However, realising this potential will depend on further field validation, material optimisation, and regulatory alignment. Key uncertainties remain regarding long-term degradation, leachate behaviour, and performance under representative subsurface conditions. This study highlights hydrochar as a scalable, technically viable CDR approach. If supported by robust containment, monitoring, and governance frameworks, it could play a meaningful role in national and regional climate mitigation strategies.

水热碳化可以将湿生物质转化为碳氢化合物，这是一种富含碳的固体，具有持久去除二氧化碳（CDR）的潜力。虽然碳氢化合物在土壤应用或废水处理等方面已被广泛研究，但其在地下储存中的作用仍未得到充分探索。本研究探讨了在荷兰采用基于碳氢化合物的生物质碳去除和储存（BiCRS）的可行性，荷兰丰富的湿生物质和发达的地下基础设施提供了一个有前景的部署环境。我们描述了粪便衍生碳氢化合物的化学和机械特性，并基于技术可行性、环境风险和长期控制，评估了七种潜在的储存配置，从废弃的煤矿到采石场湖泊和轻质填料应用。我们的研究结果确定了两种优先途径：在盐洞中储存和作为陆地高程的轻质填充材料使用。第三种途径，即储存在采石场湖泊中，也有潜力，尽管需要额外的保障措施和特定地点的评估，以确保环境的完整性和碳保留。碳氢化合物与湿的、低价值的原料的兼容性以及分散实施的潜力使其成为CDR组合中灵活的补充。然而，实现这一潜力将取决于进一步的现场验证、材料优化和法规一致性。主要的不确定性仍然存在于长期降解、渗滤液行为和代表性地下条件下的性能。这项研究强调了碳氢化合物是一种可扩展的、技术上可行的CDR方法。如果得到强有力的遏制、监测和治理框架的支持，它可以在国家和区域减缓气候变化战略中发挥有意义的作用。

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引用次数: 0

Integrated CO2-EOR and post-EOR dedicated CO2 storage: Demonstrating the value of coupled system and optimal incentive structures 集成二氧化碳- eor和eor后专用二氧化碳储存：展示耦合系统和最佳激励结构的价值

IF 5.2 3区工程技术 Q2 ENERGY & FUELS

International Journal of Greenhouse Gas Control

Pub Date : 2025-12-03 DOI: 10.1016/j.ijggc.2025.104543

Abouzar Mirzaei-Paiaman , Larry W. Lake , Lorena G. Moscardelli

<div><div>Injecting anthropogenic CO<sub>2</sub> into oil reservoirs provides the dual benefits of enhanced oil recovery (EOR) and reduced atmospheric CO<sub>2</sub> levels. After a CO<sub>2</sub>-EOR project ends, operations can transition into dedicated CO<sub>2</sub> storage, wherein CO<sub>2</sub> injection continues without further oil production. However, most prior studies have treated CO<sub>2</sub>-EOR and dedicated storage as separate processes, potentially overlooking important interdependencies. This separation may limit the optimization of both economic and environmental outcomes. In this study, we adopt an integrated approach that jointly considers the EOR and post-EOR phases, with the objective of maximizing benefits across the entire project timeline. We demonstrate the value of the integrated system using a case study from a San Andres reservoir in the Permian Basin, West Texas, and also use it to provide first-order estimates of optimal carbon storage incentives for both phases. Optimality is defined as the level of incentive that aligns economic returns with environmental gains. Using a compositional simulation model, we compared two integrated strategies under identical conditions: (1) continuous CO<sub>2</sub> injection and (2) CO<sub>2</sub>-WAG (Water-Alternating-Gas), each followed by a post-EOR CO<sub>2</sub> storage phase. The CO<sub>2</sub>-WAG approach yielded higher oil production but resulted in lower CO<sub>2</sub> storage compared to continuous injection, with the reduction in CO<sub>2</sub> storage observed during both the EOR and post-EOR phases. A similar trend was observed in terms of net CO<sub>2</sub> emissions, further reinforcing that CO<sub>2</sub>-WAG is less favorable from climate perspective. Economically, the relative attractiveness of each strategy was highly dependent on the level of incentives. At lower incentive levels, the CO<sub>2</sub>-WAG strategy was more profitable, both during the EOR phase and over the entire integrated system. However, as incentives increased, certain scenarios emerged where CO<sub>2</sub>-WAG remained more profitable only during the EOR phase, while the strategy involving continuous CO<sub>2</sub> injection became economically superior over the full integrated system. In some cases, continuous injection was consistently more profitable in both the EOR phase and the integrated context. These findings underscore the importance of evaluating CO<sub>2</sub>-EOR and post-EOR storage as a single, integrated system. Economic superiority during the EOR phase alone does not guarantee optimal outcomes across the full project period. Moreover, compromising CO<sub>2</sub> storage during the EOR phase can make it implausible to achieve maximum storage potential in the integrated system. These results also highlight the critical role of well-designed incentive structures in aligning economic and environmental goals, ensuring that the most economically beneficial strategy also delivers

向油藏中注入人为二氧化碳具有提高采收率（EOR）和降低大气二氧化碳水平的双重好处。在CO2- eor项目结束后，作业可以过渡到专用的CO2储存，其中CO2注入继续进行，而无需进一步生产石油。然而，大多数先前的研究都将CO2-EOR和专用存储视为独立的过程，可能忽略了重要的相互依赖性。这种分离可能会限制经济和环境结果的优化。在这项研究中，我们采用了一种综合方法，共同考虑了EOR和EOR后阶段，目标是在整个项目时间内实现效益最大化。我们通过德克萨斯州西部二叠纪盆地San Andres油藏的案例研究证明了集成系统的价值，并使用它来提供两个阶段的最佳碳储存激励的一阶估计。最优性被定义为使经济回报与环境收益相一致的激励水平。利用成分模拟模型，我们在相同的条件下比较了两种综合策略：(1)连续注入二氧化碳和(2)CO2- wag（水-气交替），每一种策略都有一个提高采收率后的二氧化碳储存阶段。与连续注入相比，CO2- wag方法的产油量更高，但二氧化碳储存量更低，在EOR和EOR后阶段都观察到二氧化碳储存量的降低。在CO2净排放量方面也观察到类似的趋势，进一步强化了CO2- wag从气候角度来看不太有利的观点。在经济上，每项战略的相对吸引力高度依赖于激励的水平。在较低的激励水平下，无论是在提高采收率阶段还是在整个集成系统中，CO2-WAG策略都更有利可图。然而，随着激励措施的增加，出现了某些情况，即CO2- wag仅在EOR阶段更有利可图，而持续注入CO2的策略在经济上优于完整的集成系统。在某些情况下，连续注入在EOR阶段和综合环境中都具有更高的利润。这些发现强调了将CO2-EOR和eor后存储作为一个单一的综合系统进行评估的重要性。仅在提高采收率阶段的经济优势并不能保证整个项目期间的最佳结果。此外，在提高采收率阶段降低二氧化碳的储存可能会使集成系统难以实现最大的储存潜力。这些结果还强调了设计良好的激励结构在协调经济和环境目标方面的关键作用，确保最具经济效益的战略也能带来最大的气候效益。

{"title":"Integrated CO2-EOR and post-EOR dedicated CO2 storage: Demonstrating the value of coupled system and optimal incentive structures","authors":"Abouzar Mirzaei-Paiaman , Larry W. Lake , Lorena G. Moscardelli","doi":"10.1016/j.ijggc.2025.104543","DOIUrl":"10.1016/j.ijggc.2025.104543","url":null,"abstract":"<div><div>Injecting anthropogenic CO<sub>2</sub> into oil reservoirs provides the dual benefits of enhanced oil recovery (EOR) and reduced atmospheric CO<sub>2</sub> levels. After a CO<sub>2</sub>-EOR project ends, operations can transition into dedicated CO<sub>2</sub> storage, wherein CO<sub>2</sub> injection continues without further oil production. However, most prior studies have treated CO<sub>2</sub>-EOR and dedicated storage as separate processes, potentially overlooking important interdependencies. This separation may limit the optimization of both economic and environmental outcomes. In this study, we adopt an integrated approach that jointly considers the EOR and post-EOR phases, with the objective of maximizing benefits across the entire project timeline. We demonstrate the value of the integrated system using a case study from a San Andres reservoir in the Permian Basin, West Texas, and also use it to provide first-order estimates of optimal carbon storage incentives for both phases. Optimality is defined as the level of incentive that aligns economic returns with environmental gains. Using a compositional simulation model, we compared two integrated strategies under identical conditions: (1) continuous CO<sub>2</sub> injection and (2) CO<sub>2</sub>-WAG (Water-Alternating-Gas), each followed by a post-EOR CO<sub>2</sub> storage phase. The CO<sub>2</sub>-WAG approach yielded higher oil production but resulted in lower CO<sub>2</sub> storage compared to continuous injection, with the reduction in CO<sub>2</sub> storage observed during both the EOR and post-EOR phases. A similar trend was observed in terms of net CO<sub>2</sub> emissions, further reinforcing that CO<sub>2</sub>-WAG is less favorable from climate perspective. Economically, the relative attractiveness of each strategy was highly dependent on the level of incentives. At lower incentive levels, the CO<sub>2</sub>-WAG strategy was more profitable, both during the EOR phase and over the entire integrated system. However, as incentives increased, certain scenarios emerged where CO<sub>2</sub>-WAG remained more profitable only during the EOR phase, while the strategy involving continuous CO<sub>2</sub> injection became economically superior over the full integrated system. In some cases, continuous injection was consistently more profitable in both the EOR phase and the integrated context. These findings underscore the importance of evaluating CO<sub>2</sub>-EOR and post-EOR storage as a single, integrated system. Economic superiority during the EOR phase alone does not guarantee optimal outcomes across the full project period. Moreover, compromising CO<sub>2</sub> storage during the EOR phase can make it implausible to achieve maximum storage potential in the integrated system. These results also highlight the critical role of well-designed incentive structures in aligning economic and environmental goals, ensuring that the most economically beneficial strategy also delivers ","PeriodicalId":334,"journal":{"name":"International Journal of Greenhouse Gas Control","volume":"149 ","pages":"Article 104543"},"PeriodicalIF":5.2,"publicationDate":"2025-12-03","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"145692543","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}

引用次数: 0

Does the release of toxic metals due to subsurface CO2 storage in basalts pose an environmental hazard? 由于玄武岩地下二氧化碳储存而释放的有毒金属是否会对环境造成危害？

IF 5.2 3区工程技术 Q2 ENERGY & FUELS

International Journal of Greenhouse Gas Control

Pub Date : 2025-12-02 DOI: 10.1016/j.ijggc.2025.104526

Deirdre E. Clark , Iwona M. Galeczka , Sigurður R. Gíslason , Sandra Ó. Snæbjörnsdóttir , Ingvi Gunnarsson , Eric H. Oelkers

Carbon dioxide storage through the carbonation of subsurface basaltic rocks is currently being explored to limit carbon emissions to the atmosphere. Basaltic rocks, however, contain trace and toxic metals that could potentially be mobilized by the carbonation process. This study reports the degree to which selected trace and toxic metals were mobilized during CarbFix1 and CarbFix2 projects. CarbFix1 injected 175 tons of CO₂-charged water followed by 73 tons of CO₂/H₂S-charged water into basalts at 35 °C, whereas CarbFix2 continuously injected CO₂/H₂S-charged water into basalts at >250 °C. In most cases dissolved concentrations of Ba, Sr, Mo, Cu, Cr, Ni, Cd, and Pb in monitoring well fluids remained low. Although these fluids are not intended for human consumption, the aqueous trace element concentrations were generally below the WHO, EU, and Iceland drinking water standards, except for Fe and Mn in CarbFix1. Aluminum and As concentrations exceeded these standards during CarbFix2, but were elevated before injection. The low concentrations of most trace and toxic metals are consistent with their removal by secondary processes, particularly co-precipitation into carbonate and sulfide minerals formed during gas-water-basalt interaction. Solid precipitates recovered from CarbFix1 show strong enrichment of transition metals in calcite, consistent with natural and engineered analogues. As the two CarbFix injections bound the lower and upper temperature ranges of likely mineral carbon storage efforts, these results suggest limited risk of water contamination due to toxic and trace element release from subsurface basalts due to the injection of dissolved CO₂ and H₂S.

目前正在探索通过地下玄武岩的碳酸化来储存二氧化碳，以限制碳排放到大气中。然而，玄武岩中含有微量和有毒的金属，这些金属可能会通过碳化过程被动员起来。本研究报告了在CarbFix1和CarbFix2项目中选定的痕量和有毒金属的动员程度。CarbFix1先向玄武岩注入175吨含二氧化碳的水，然后在35℃下注入73吨含二氧化碳/硫化氢的水，而CarbFix2则在250℃下连续向玄武岩注入含二氧化碳/硫化氢的水。在大多数情况下，监测井流体中Ba、Sr、Mo、Cu、Cr、Ni、Cd和Pb的溶解浓度仍然很低。虽然这些液体不是供人类饮用的，但水中微量元素的浓度普遍低于世界卫生组织、欧盟和冰岛的饮用水标准，除了CarbFix1中的铁和锰。在CarbFix2期间，铝和砷的浓度超过了这些标准，但在注射前升高。大多数微量和有毒金属的低浓度与它们通过二次过程去除一致，特别是在气-水-玄武岩相互作用过程中形成的碳酸盐和硫化物矿物中共沉淀。从CarbFix1中回收的固体沉淀物显示方解石中过渡金属的富集，与天然和工程类似物一致。由于两次CarbFix注入限制了可能的矿物碳储存工作的上下温度范围，因此这些结果表明，由于注入溶解的CO2和H2S，地下玄武岩释放出有毒和微量元素，因此水污染的风险有限。

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引用次数: 0

Scaling carbon capture and storage (CCS) to gigaton capacity: A multi-dimensional and critical review 将碳捕集与封存（CCS）规模扩大到千兆吨容量：多维度和批判性回顾

IF 5.2 3区工程技术 Q2 ENERGY & FUELS

International Journal of Greenhouse Gas Control

Pub Date : 2025-12-02 DOI: 10.1016/j.ijggc.2025.104531

Benjamin Mitterrutzner , Benjamin K. Sovacool , Brage Rugstad Knudsen , Morgan D. Bazilian , Jinsoo Kim , Simon Roussanaly , Asgeir Tomasgard , Steven Griffiths

This Review examines the role of carbon capture and storage (CCS) in achieving net-zero emissions by 2050, focusing on its scale-up and integration across energy systems and hard-to-abate industries. Its interdisciplinary approach provides a comprehensive review of the state-of-the-art in CCS research, evaluating its potential role in achieving net-zero emissions. It assesses not only technological advancements and characteristics but also the critical costs and energy requirements of various CCS technologies. Based on modelling insights from the International Energy Agency Net Zero Emissions pathway, it highlights the need to scale CCS deployment to 1 Gt CO₂ annually by 2030 to stay on track for climate goals. This review piece underscores the urgency of rapid CCS scale-up this decade, complementing other measures across energy and industry. Furthermore, it assesses the recent advancements in CO₂ capture, transport, and storage technologies, along with their techno-economic characteristics and results in energy system models. The study concludes by identifying key challenges and providing a strategy roadmap for decision-makers for accelerating CCS deployment.

本综述探讨了碳捕集与封存（CCS）在到2050年实现净零排放方面的作用，重点关注其在能源系统和难以减排的行业中的扩大和整合。它的跨学科方法对CCS研究的最新进展进行了全面回顾，评估了其在实现净零排放方面的潜在作用。它不仅评估了技术的进步和特点，而且还评估了各种CCS技术的关键成本和能源需求。基于国际能源机构净零排放路径的建模见解，该报告强调了到2030年将CCS部署规模扩大到每年1亿吨二氧化碳的必要性，以保持气候目标的正轨。这篇综述文章强调了在这十年内迅速扩大CCS规模的紧迫性，并补充了能源和工业领域的其他措施。此外，它还评估了CO₂捕获、运输和储存技术的最新进展，以及它们的技术经济特征和能源系统模型的结果。该研究通过确定关键挑战并为决策者提供加速CCS部署的战略路线图来结束。

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引用次数: 0