Pub Date : 2025-12-01DOI: 10.1016/j.ijggc.2025.104529
Shi Yuan Toh, Colin MacBeth, Jorge Landa, Hamed Heidari
Carbon capture and storage (CCS) is crucial for meeting global CO2 emissions reduction targets. Monitoring, measurement, and verification (MMV) plans are essential for the effective management of CO2 storage sites, with 4D seismic data playing a key role. To aid this understanding, this study presents simulation to seismic modelling (Sim2Seis) case studies for CO2 injection into depleted gas fields, focusing on the Goldeneye, Hamilton, and Viking fields in the North Sea. Using compositional reservoir flow simulation models, we conduct a forward modelling process to generate synthetic seismic at key time steps such as baseline (pre-CO2 injection) and at the end of CO2 injection (post-CO2 injection). We demonstrate that 4D seismic signals, related to saturation changes, are strong and most visible at fluid contacts, particularly where CO2-hydrocarbon gas mixture displaces the aquifer. By contrast, intra-reservoir signals arise primarily from fluid compositional changes with only limited contrast in acoustic properties from density and velocity variations. These findings suggest that 4D seismic is better suited for containment monitoring and leakage detection than conformance monitoring. They also highlight the need for tailored strategies based on compositional reservoir flow simulation models. Continued research into fluid flow physics and seismic interpretation is critical to optimizing monitoring strategies for CO2 storage in depleted gas fields.
{"title":"Exploring 4D seismic potential for monitoring CO2 injection in depleted North Sea gas fields","authors":"Shi Yuan Toh, Colin MacBeth, Jorge Landa, Hamed Heidari","doi":"10.1016/j.ijggc.2025.104529","DOIUrl":"10.1016/j.ijggc.2025.104529","url":null,"abstract":"<div><div>Carbon capture and storage (CCS) is crucial for meeting global CO<sub>2</sub> emissions reduction targets. Monitoring, measurement, and verification (MMV) plans are essential for the effective management of CO<sub>2</sub> storage sites, with 4D seismic data playing a key role. To aid this understanding, this study presents simulation to seismic modelling (Sim2Seis) case studies for CO<sub>2</sub> injection into depleted gas fields, focusing on the Goldeneye, Hamilton, and Viking fields in the North Sea. Using compositional reservoir flow simulation models, we conduct a forward modelling process to generate synthetic seismic at key time steps such as baseline (pre-CO<sub>2</sub> injection) and at the end of CO<sub>2</sub> injection (post-CO<sub>2</sub> injection). We demonstrate that 4D seismic signals, related to saturation changes, are strong and most visible at fluid contacts, particularly where CO<sub>2</sub>-hydrocarbon gas mixture displaces the aquifer. By contrast, intra-reservoir signals arise primarily from fluid compositional changes with only limited contrast in acoustic properties from density and velocity variations. These findings suggest that 4D seismic is better suited for containment monitoring and leakage detection than conformance monitoring. They also highlight the need for tailored strategies based on compositional reservoir flow simulation models. Continued research into fluid flow physics and seismic interpretation is critical to optimizing monitoring strategies for CO<sub>2</sub> storage in depleted gas fields.</div></div>","PeriodicalId":334,"journal":{"name":"International Journal of Greenhouse Gas Control","volume":"148 ","pages":"Article 104529"},"PeriodicalIF":5.2,"publicationDate":"2025-12-01","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"145621153","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}
Pub Date : 2025-12-01DOI: 10.1016/j.ijggc.2025.104541
Ferdinand Uilhoorn, Maciej Chaczykowski, Andrzej J. Osiadacz, Tomasz Bleschke, Łukasz Kotyński
Carbon capture and storage is crucial for reducing emissions from fossil fuel power plants and industries with significant CO production. To ensure safe pipeline design, integrated emergency shutdown systems are implemented, which can induce rapid changes in flow conditions, potentially causing critical pressure spikes and phase transitions, accelerating cavitation and material fatigue. In this work, we used a homogeneous two-phase flow model to evaluate the risk of two-phase flow during a hydraulic shock. The heat transfer between the CO-rich stream and its surroundings is modeled using a heat transfer model with steady-periodic thermal boundary conditions. We considered pure CO and CO mixtures containing impurities obtained from pre-combustion and post-combustion carbon capture technologies. We investigated the influence of impurities, the choice of equation of state, pipeline inclination, and flow closure characteristics. The flow model is approximated using a weighted essentially non-oscillatory scheme coupled with the Harten–Lax–van Leer Contact flux. The model was benchmarked against a Riemann problem, a depressurization scenario, and decompression wave speed measurements, and further validated using pressure pulse data from cavity collapse experiments caused by rapid valve closure in water. The model’s applicability is demonstrated through a case study of an offshore pipeline, utilizing parameters from the Porthos project. Results indicated that CO-rich streams initially in the liquid phase and near the saturation line can trigger vapor formation, but it depends on the impurity content. The results showed to be sensitive for the selected equation of state.
{"title":"Modeling two-phase multicomponent CO2 mixtures in offshore pipelines under hydraulic shock","authors":"Ferdinand Uilhoorn, Maciej Chaczykowski, Andrzej J. Osiadacz, Tomasz Bleschke, Łukasz Kotyński","doi":"10.1016/j.ijggc.2025.104541","DOIUrl":"10.1016/j.ijggc.2025.104541","url":null,"abstract":"<div><div>Carbon capture and storage is crucial for reducing emissions from fossil fuel power plants and industries with significant CO<span><math><msub><mrow></mrow><mrow><mn>2</mn></mrow></msub></math></span> production. To ensure safe pipeline design, integrated emergency shutdown systems are implemented, which can induce rapid changes in flow conditions, potentially causing critical pressure spikes and phase transitions, accelerating cavitation and material fatigue. In this work, we used a homogeneous two-phase flow model to evaluate the risk of two-phase flow during a hydraulic shock. The heat transfer between the CO<span><math><msub><mrow></mrow><mrow><mn>2</mn></mrow></msub></math></span>-rich stream and its surroundings is modeled using a heat transfer model with steady-periodic thermal boundary conditions. We considered pure CO<span><math><msub><mrow></mrow><mrow><mn>2</mn></mrow></msub></math></span> and CO<span><math><msub><mrow></mrow><mrow><mn>2</mn></mrow></msub></math></span> mixtures containing impurities obtained from pre-combustion and post-combustion carbon capture technologies. We investigated the influence of impurities, the choice of equation of state, pipeline inclination, and flow closure characteristics. The flow model is approximated using a weighted essentially non-oscillatory scheme coupled with the Harten–Lax–van Leer Contact flux. The model was benchmarked against a Riemann problem, a depressurization scenario, and decompression wave speed measurements, and further validated using pressure pulse data from cavity collapse experiments caused by rapid valve closure in water. The model’s applicability is demonstrated through a case study of an offshore pipeline, utilizing parameters from the Porthos project. Results indicated that CO<span><math><msub><mrow></mrow><mrow><mn>2</mn></mrow></msub></math></span>-rich streams initially in the liquid phase and near the saturation line can trigger vapor formation, but it depends on the impurity content. The results showed to be sensitive for the selected equation of state.</div></div>","PeriodicalId":334,"journal":{"name":"International Journal of Greenhouse Gas Control","volume":"148 ","pages":"Article 104541"},"PeriodicalIF":5.2,"publicationDate":"2025-12-01","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"145690720","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}
Pub Date : 2025-12-01DOI: 10.1016/j.ijggc.2025.104533
Jong Heon Ha , Hyun‑Kwon Do , Soyeon Lim , Hakyung Cho , Sung-Wook Jeen
Leakage of CO2 from carbon capture and storage (CCS) sites into shallow aquifers can alter groundwater chemistry, affecting parameters such as pH, electrical conductivity (EC), alkalinity, and cation concentrations. Monitoring these parameters is essential for early detection of CO2 leakage. This study employed multicomponent reactive transport modeling to analyze geochemical changes observed in laboratory column experiments (push-and-pull and natural gradient tests) using soil and groundwater from the Environmental Impact Test (EIT) facility in Korea. The site mainly consists of a granitic/gneissic aquifer system. The model incorporated primary alumino-silicate minerals (quartz, microcline, anorthite, albite, and biotite) identified through X-ray diffraction (XRD) analysis and accounted for the precipitation of secondary minerals (gibbsite, calcite, and dolomite). Simulations successfully reproduced observed trends in pH, alkalinity, and major cations (Ca, Mg, Na, and K) and Fe, indicating that mineral dissolution, particularly of anorthite and biotite, was the primary buffering mechanism under acidic conditions. Gibbsite precipitation effectively limited Al mobility. Predictive simulations showed that geochemical responses were largely confined within 2.5 meters of the CO2 source during the 30 days following injection, with delayed breakthrough at greater distances. These findings underscore the utility of reactive transport modeling for quantifying spatiotemporal geochemical evolution following CO2 leakage. The approach supports improved monitoring well placement, sampling strategies, and site-specific risk assessments, and can be broadly applied to geochemical investigations in CCS and other groundwater systems.
{"title":"Integrated column experiments and reactive transport modeling for identifying chemical indicators of CO2 leakage in a shallow granitic/gneissic aquifer","authors":"Jong Heon Ha , Hyun‑Kwon Do , Soyeon Lim , Hakyung Cho , Sung-Wook Jeen","doi":"10.1016/j.ijggc.2025.104533","DOIUrl":"10.1016/j.ijggc.2025.104533","url":null,"abstract":"<div><div>Leakage of CO<sub>2</sub> from carbon capture and storage (CCS) sites into shallow aquifers can alter groundwater chemistry, affecting parameters such as pH, electrical conductivity (EC), alkalinity, and cation concentrations. Monitoring these parameters is essential for early detection of CO<sub>2</sub> leakage. This study employed multicomponent reactive transport modeling to analyze geochemical changes observed in laboratory column experiments (push-and-pull and natural gradient tests) using soil and groundwater from the Environmental Impact Test (EIT) facility in Korea. The site mainly consists of a granitic/gneissic aquifer system. The model incorporated primary alumino-silicate minerals (quartz, microcline, anorthite, albite, and biotite) identified through X-ray diffraction (XRD) analysis and accounted for the precipitation of secondary minerals (gibbsite, calcite, and dolomite). Simulations successfully reproduced observed trends in pH, alkalinity, and major cations (Ca, Mg, Na, and K) and Fe, indicating that mineral dissolution, particularly of anorthite and biotite, was the primary buffering mechanism under acidic conditions. Gibbsite precipitation effectively limited Al mobility. Predictive simulations showed that geochemical responses were largely confined within 2.5 meters of the CO<sub>2</sub> source during the 30 days following injection, with delayed breakthrough at greater distances. These findings underscore the utility of reactive transport modeling for quantifying spatiotemporal geochemical evolution following CO<sub>2</sub> leakage. The approach supports improved monitoring well placement, sampling strategies, and site-specific risk assessments, and can be broadly applied to geochemical investigations in CCS and other groundwater systems.</div></div>","PeriodicalId":334,"journal":{"name":"International Journal of Greenhouse Gas Control","volume":"148 ","pages":"Article 104533"},"PeriodicalIF":5.2,"publicationDate":"2025-12-01","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"145690816","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}
Pub Date : 2025-12-01DOI: 10.1016/j.ijggc.2025.104540
Susanne Hochmeister, Stefan Wallner, Josef Steinegger, Thomas Kienberger
The successful implementation of Carbon Capture and Utilization (CCU) and Carbon Capture and Storage (CCS) requires the development of a CO2 infrastructure connecting CO2 sources and sinks. From an economic standpoint, pipelines are the only way to transport large quantities of CO2 over land. In this work a techno-economic optimization approach for the design of CO2 networks, incorporating detailed physical constraints, is evaluated. The proposed Optimal Power Flow (OPF) model integrates detailed Power Flow calculations, to analyze pressure drops during gaseous, supercritical, and dense phase CO2 transport. The methodology is applied to various sample networks to assess its applicability across different topologies, including branched and meshed configurations, as well as networks with long transmission lines. Also, the computational performance of the proposed approach is evaluated. The results show that the model can determine cost-optimal pipeline routes as well as pipe diameters, strategically place booster stations with respect to balancing investment costs and operational feasibility, and eliminate redundant connections in meshed systems. Network topology has been found to have a significant impact on optimal design. The model allows for varying network complexities and scales, making it applicable to both small-scale projects and large-scale CO₂ infrastructure initiatives. The study provides a scalable framework for designing CO2 infrastructure to support large-scale decarbonization efforts, offering valuable insights for policymakers and engineers.
{"title":"A novel Optimal Power Flow model for the design of CO2 networks","authors":"Susanne Hochmeister, Stefan Wallner, Josef Steinegger, Thomas Kienberger","doi":"10.1016/j.ijggc.2025.104540","DOIUrl":"10.1016/j.ijggc.2025.104540","url":null,"abstract":"<div><div>The successful implementation of Carbon Capture and Utilization (CCU) and Carbon Capture and Storage (CCS) requires the development of a CO<sub>2</sub> infrastructure connecting CO<sub>2</sub> sources and sinks. From an economic standpoint, pipelines are the only way to transport large quantities of CO<sub>2</sub> over land. In this work a techno-economic optimization approach for the design of CO<sub>2</sub> networks, incorporating detailed physical constraints, is evaluated. The proposed Optimal Power Flow (OPF) model integrates detailed Power Flow calculations, to analyze pressure drops during gaseous, supercritical, and dense phase CO<sub>2</sub> transport. The methodology is applied to various sample networks to assess its applicability across different topologies, including branched and meshed configurations, as well as networks with long transmission lines. Also, the computational performance of the proposed approach is evaluated. The results show that the model can determine cost-optimal pipeline routes as well as pipe diameters, strategically place booster stations with respect to balancing investment costs and operational feasibility, and eliminate redundant connections in meshed systems. Network topology has been found to have a significant impact on optimal design. The model allows for varying network complexities and scales, making it applicable to both small-scale projects and large-scale CO₂ infrastructure initiatives. The study provides a scalable framework for designing CO<sub>2</sub> infrastructure to support large-scale decarbonization efforts, offering valuable insights for policymakers and engineers.</div></div>","PeriodicalId":334,"journal":{"name":"International Journal of Greenhouse Gas Control","volume":"148 ","pages":"Article 104540"},"PeriodicalIF":5.2,"publicationDate":"2025-12-01","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"145690818","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}
Pub Date : 2025-12-01DOI: 10.1016/j.ijggc.2025.104536
Dominik Strutz, Andrew Curtis
Effective seismic monitoring of subsurface carbon dioxide storage (SCS) sites is essential for managing risks posed by induced seismicity. This is particularly challenging in offshore environments, such as the Endurance licence area in the North Sea, where the UK’s permanent land-based seismometer network offers limited monitoring capability due to its distance from the expected locations of seismic events. A Bayesian experimental design framework is used to assess enhancements of the network with a low-noise onshore station located at around 1 km depth in Boulby mine, the onshore North York Moors Seismic Array, an optimally-located additional onshore monitoring site, and ocean bottom seismometers (OBS). We quantify the expected information gain about seismic source locations and introduce a practical method to incorporate signal-to-noise dependent detectability and velocity model uncertainty. We show that the Boulby station or an onshore array primarily lower the detection threshold for small-magnitude events (M=0-2), but offer limited improvement in location accuracy. An optimally-located additional land-based seismometer or local array provides little additional benefit. OBS deployments yield significant improvements in location accuracy due to their proximity to potential seismicity. Optimised networks of two to three OBS stations are effective for Endurance, while three to five OBS stations offer robust monitoring across North Sea carbon storage licence areas off England’s east coast. Velocity model uncertainty remains a key limiting factor for location precision across all configurations. We conclude that deploying OBS networks is the most promising strategy for enhancing microseismic monitoring capabilities at offshore SCS sites, though potentially more expensive.
对地下二氧化碳储存（SCS）地点进行有效的地震监测对于管理诱发地震活动带来的风险至关重要。这在海上环境中尤其具有挑战性，例如北海的Endurance许可证区域，由于距离地震事件的预期位置较远，英国的永久性陆地地震仪网络的监测能力有限。贝叶斯实验设计框架用于评估网络的增强，包括位于Boulby矿约1公里深度的低噪声陆上站、陆上North York Moors地震阵列、最佳位置的额外陆上监测点和海底地震仪（OBS）。我们量化了震源位置的预期信息增益，并介绍了一种实用的方法来结合依赖于信噪比的可探测性和速度模型的不确定性。我们发现，Boulby台站或陆上阵列主要降低了小震级事件（M=0-2）的检测阈值，但在定位精度方面提供了有限的改进。最佳位置的额外陆基地震仪或本地阵列几乎没有额外的好处。由于OBS靠近潜在的地震活动，因此其定位精度显著提高。两到三个OBS站的优化网络对Endurance来说是有效的，而三到五个OBS站可以在英格兰东海岸的北海碳储存许可区域提供强大的监测。速度模型的不确定性仍然是所有配置中定位精度的关键限制因素。我们的结论是，部署OBS网络是增强海上SCS站点微地震监测能力的最有前途的策略，尽管可能更昂贵。
{"title":"The roles of low-noise stations, arrays and ocean-bottom seismometers in monitoring UK offshore seismicity associated with subsurface storage of carbon dioxide","authors":"Dominik Strutz, Andrew Curtis","doi":"10.1016/j.ijggc.2025.104536","DOIUrl":"10.1016/j.ijggc.2025.104536","url":null,"abstract":"<div><div>Effective seismic monitoring of subsurface carbon dioxide storage (SCS) sites is essential for managing risks posed by induced seismicity. This is particularly challenging in offshore environments, such as the Endurance licence area in the North Sea, where the UK’s permanent land-based seismometer network offers limited monitoring capability due to its distance from the expected locations of seismic events. A Bayesian experimental design framework is used to assess enhancements of the network with a low-noise onshore station located at around 1 km depth in Boulby mine, the onshore North York Moors Seismic Array, an optimally-located additional onshore monitoring site, and ocean bottom seismometers (OBS). We quantify the expected information gain about seismic source locations and introduce a practical method to incorporate signal-to-noise dependent detectability and velocity model uncertainty. We show that the Boulby station or an onshore array primarily lower the detection threshold for small-magnitude events (M=0-2), but offer limited improvement in location accuracy. An optimally-located additional land-based seismometer or local array provides little additional benefit. OBS deployments yield significant improvements in location accuracy due to their proximity to potential seismicity. Optimised networks of two to three OBS stations are effective for Endurance, while three to five OBS stations offer robust monitoring across North Sea carbon storage licence areas off England’s east coast. Velocity model uncertainty remains a key limiting factor for location precision across all configurations. We conclude that deploying OBS networks is the most promising strategy for enhancing microseismic monitoring capabilities at offshore SCS sites, though potentially more expensive.</div></div>","PeriodicalId":334,"journal":{"name":"International Journal of Greenhouse Gas Control","volume":"148 ","pages":"Article 104536"},"PeriodicalIF":5.2,"publicationDate":"2025-12-01","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"145621154","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}
Pub Date : 2025-12-01DOI: 10.1016/j.ijggc.2025.104519
Jan M. Nordbotten , Martin A. Fernø , Bernd Flemisch , Anthony R. Kovscek , Knut-Andreas Lie , Jakub W. Both , Olav Møyner , Tor Harald Sandve , Etienne Ahusborde , Sebastian Bauer , Zhangxing Chen , Holger Class , Chaojie Di , Didier Ding , David Element , Eric Flauraud , Jacques Franc , Firdovsi Gasanzade , Yousef Ghomian , Marie Ann Giddins , AbdAllah A. Youssef
The 11th Society of Petroleum Engineers Comparative Solution Project (shortened SPE11 herein) benchmarked simulation tools for geological carbon dioxide (CO2) storage. A total of 45 groups from leading research institutions and industry across the globe signed up to participate, with 18 ultimately contributing valid results that were included in the comparative study reported here.
This paper summarizes the SPE11 results. A comprehensive introduction and qualitative discussion of the submitted data are provided, together with an overview of online resources for accessing the full depth of data. A global metric for analyzing the relative distance between submissions is proposed and used to conduct a quantitative analysis of the submissions. This analysis attempts to statistically resolve the key aspects influencing the variability between submissions.
The study shows that the major qualitative variation between the submitted results is related to thermal effects, dissolution-driven convective mixing, and resolution of facies discontinuities. Moreover, a strong dependence on grid resolution is observed across all three versions of the SPE11. However, our quantitative analysis suggests that the observed variations are predominantly influenced by factors not documented in the technical responses provided by the participants. We therefore identify that unreported variations due to human choices within the process of setting up, conducting, and reporting on the simulations underlying each SPE11 submission are at least as impactful as the computational choices reported.
{"title":"Benchmarking CO₂ storage simulations: Results from the 11th Society of Petroleum Engineers Comparative Solution Project","authors":"Jan M. Nordbotten , Martin A. Fernø , Bernd Flemisch , Anthony R. Kovscek , Knut-Andreas Lie , Jakub W. Both , Olav Møyner , Tor Harald Sandve , Etienne Ahusborde , Sebastian Bauer , Zhangxing Chen , Holger Class , Chaojie Di , Didier Ding , David Element , Eric Flauraud , Jacques Franc , Firdovsi Gasanzade , Yousef Ghomian , Marie Ann Giddins , AbdAllah A. Youssef","doi":"10.1016/j.ijggc.2025.104519","DOIUrl":"10.1016/j.ijggc.2025.104519","url":null,"abstract":"<div><div>The 11<sup>th</sup> Society of Petroleum Engineers Comparative Solution Project (shortened SPE11 herein) benchmarked simulation tools for geological carbon dioxide (CO<sub>2</sub>) storage. A total of 45 groups from leading research institutions and industry across the globe signed up to participate, with 18 ultimately contributing valid results that were included in the comparative study reported here.</div><div>This paper summarizes the SPE11 results. A comprehensive introduction and qualitative discussion of the submitted data are provided, together with an overview of online resources for accessing the full depth of data. A global metric for analyzing the relative distance between submissions is proposed and used to conduct a quantitative analysis of the submissions. This analysis attempts to statistically resolve the key aspects influencing the variability between submissions.</div><div>The study shows that the major qualitative variation between the submitted results is related to thermal effects, dissolution-driven convective mixing, and resolution of facies discontinuities. Moreover, a strong dependence on grid resolution is observed across all three versions of the SPE11. However, our quantitative analysis suggests that the observed variations are predominantly influenced by factors not documented in the technical responses provided by the participants. We therefore identify that unreported variations due to human choices within the process of setting up, conducting, and reporting on the simulations underlying each SPE11 submission are at least as impactful as the computational choices reported.</div></div>","PeriodicalId":334,"journal":{"name":"International Journal of Greenhouse Gas Control","volume":"148 ","pages":"Article 104519"},"PeriodicalIF":5.2,"publicationDate":"2025-12-01","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"145690817","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}
Pub Date : 2025-12-01DOI: 10.1016/j.ijggc.2025.104528
Paweł Bielka, Szymon Kuczyński, Stanisław Nagy
This study introduces a conceptual Digital Twin framework for real-time modeling of CO2 dispersion following accidental pipeline leaks or ruptures. Forecasts cloud pathways and concentration gradients both in real-time operations and within a simulated training environment. The system offers simulations on demand for operator training, strengthening preparedness, situational awareness, and rapid decision-making during critical incidents. By integrating high-frequency nondispersive infrared (NDIR) sensor data with a physics-informed long-short-term memory (LSTM) model, validated against synthetic data from DNV Phast software, the developed system generates accurate spatial forecasts of the 5 000 ppm CO2 dispersion contour. Experimental validation in more than 300 000 simulated scenarios showed a mean squared error just below 5 %, indicating high reliability and operational effectiveness. The proposed Hybrid Gaussian Digital Twin (HyG-CO2DT) offers scalability, maintains robustness under varying sensor densities without requiring model retraining, and provides a practical framework for enhancing safety, regulatory compliance, and effective risk management in industrial carbon capture and storage (CCS) applications.
{"title":"Development of a hybrid Digital Twin for the dispersion of transient CO2 clouds accompanying accidental pipeline leaks","authors":"Paweł Bielka, Szymon Kuczyński, Stanisław Nagy","doi":"10.1016/j.ijggc.2025.104528","DOIUrl":"10.1016/j.ijggc.2025.104528","url":null,"abstract":"<div><div>This study introduces a conceptual Digital Twin framework for real-time modeling of CO<sub>2</sub> dispersion following accidental pipeline leaks or ruptures. Forecasts cloud pathways and concentration gradients both in real-time operations and within a simulated training environment. The system offers simulations on demand for operator training, strengthening preparedness, situational awareness, and rapid decision-making during critical incidents. By integrating high-frequency nondispersive infrared (NDIR) sensor data with a physics-informed long-short-term memory (LSTM) model, validated against synthetic data from DNV Phast software, the developed system generates accurate spatial forecasts of the 5<!--> <!-->000 ppm CO<sub>2</sub> dispersion contour. Experimental validation in more than 300<!--> <!-->000 simulated scenarios showed a mean squared error just below 5 %, indicating high reliability and operational effectiveness. The proposed Hybrid Gaussian Digital Twin (HyG-CO2DT) offers scalability, maintains robustness under varying sensor densities without requiring model retraining, and provides a practical framework for enhancing safety, regulatory compliance, and effective risk management in industrial carbon capture and storage (CCS) applications.</div></div>","PeriodicalId":334,"journal":{"name":"International Journal of Greenhouse Gas Control","volume":"148 ","pages":"Article 104528"},"PeriodicalIF":5.2,"publicationDate":"2025-12-01","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"145621218","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}
Pub Date : 2025-12-01DOI: 10.1016/j.ijggc.2025.104537
Ahmad Azadivash , Ahmad Reza Rabbani , Sahar Bakhshian , Vali Mehdipour
The feasibility of geological CO2 storage in the Asmari naturally fractured carbonate reservoir was assessed using an integrated workflow that combined high-resolution 3D geological modeling with reactive-transport simulation. The reservoir model incorporated seismic data, well log information, and discrete fracture networks. This model was upscaled for multiphase flow simulations to evaluate injection and storage dynamics under realistic reservoir conditions. To assess the effects on CO2 trapping mechanisms, ten sensitivity scenarios were performed. These scenarios varied the injection rate, injection duration, maximum residual gas saturation, capillary pressure, fracture spacing, and storage. Results demonstrated that higher injection rates led to rapid plume migration and increased structural trapping. In contrast, lower injection rates and extended injection periods enhanced CO2-brine interactions, resulting in greater solubility and residual trapping during the post-injection phase. The inclusion of capillary pressure limited buoyancy-driven ascent, promoted lateral plume dispersion, and improved overall trapping efficiency. Denser fracture networks increased near-well retention and matrix exchange, thereby enhancing residual trapping, while wider fracture spacing facilitated broader structural storage. Mineral trapping was negligible over extended timescales due to acidic and saline brine conditions, as well as limited matrix interaction. These findings inform the optimization of injection strategies and well placement in fractured carbonate reservoirs. The results underscore the significant roles of capillary, viscous, and fracture controls in CO2 storage, indicating the need for pH-buffering strategies or long-term field validation to enhance mineralization potential.
{"title":"Assessing CO2 storage capacity in fractured carbonate reservoirs: A case study of the Asmari Reservoir, Iran","authors":"Ahmad Azadivash , Ahmad Reza Rabbani , Sahar Bakhshian , Vali Mehdipour","doi":"10.1016/j.ijggc.2025.104537","DOIUrl":"10.1016/j.ijggc.2025.104537","url":null,"abstract":"<div><div>The feasibility of geological CO<sub>2</sub> storage in the Asmari naturally fractured carbonate reservoir was assessed using an integrated workflow that combined high-resolution 3D geological modeling with reactive-transport simulation. The reservoir model incorporated seismic data, well log information, and discrete fracture networks. This model was upscaled for multiphase flow simulations to evaluate injection and storage dynamics under realistic reservoir conditions. To assess the effects on CO<sub>2</sub> trapping mechanisms, ten sensitivity scenarios were performed. These scenarios varied the injection rate, injection duration, maximum residual gas saturation, capillary pressure, fracture spacing, and storage. Results demonstrated that higher injection rates led to rapid plume migration and increased structural trapping. In contrast, lower injection rates and extended injection periods enhanced CO<sub>2</sub>-brine interactions, resulting in greater solubility and residual trapping during the post-injection phase. The inclusion of capillary pressure limited buoyancy-driven ascent, promoted lateral plume dispersion, and improved overall trapping efficiency. Denser fracture networks increased near-well retention and matrix exchange, thereby enhancing residual trapping, while wider fracture spacing facilitated broader structural storage. Mineral trapping was negligible over extended timescales due to acidic and saline brine conditions, as well as limited matrix interaction. These findings inform the optimization of injection strategies and well placement in fractured carbonate reservoirs. The results underscore the significant roles of capillary, viscous, and fracture controls in CO<sub>2</sub> storage, indicating the need for pH-buffering strategies or long-term field validation to enhance mineralization potential.</div></div>","PeriodicalId":334,"journal":{"name":"International Journal of Greenhouse Gas Control","volume":"148 ","pages":"Article 104537"},"PeriodicalIF":5.2,"publicationDate":"2025-12-01","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"145621219","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}
Carbon dioxide (CO2) is increasingly viewed not only as a climate liability but also as a potential feedstock in circular carbon strategies. However, its practical utilization critically depends on both its chemical composition – including application-specific impurity tolerances – and its origin, whether fossil-based or biogenic. This study presents a comprehensive compositional assessment of CO2-rich streams from twelve industrial point sources in Finland, with a special focus on biogas upgrading facilities employing diverse purification technologies (membrane separation, water/amine scrubbing, pressure swing absorption (PSA)). Using Fourier Transform Infrared (FTIR), gas chromatograph (GC), adsorption tubes and biogenicity analysis, key impurities affecting downstream suitability for five major applications –food, medical, fuel synthesis, greenhouse use, and permanent storage – were identified, along with the assessment of biogenicity of streams.
The results indicate that measured membrane-based upgrading plants provided the most suitable CO2 quality (95.9–97.3 vol-%) for high-purity applications, including the food and beverage industry, medicinal use, and chemical production. This stream requires only limited removal of residual moisture, nitrogen, and oxygen, although elevated concentrations of methane and hydrogen remain a challenge. In contrast, amine scrubbing and PSA processes exhibited higher impurity levels, particularly hydrogen sulfide and volatile organic compounds. Nevertheless, CO2-rich off-gas streams from biogas upgrading plants can be directly applied to greenhouse enrichment and concrete curing when appropriate dilutions are performed. Biogenicity values of almost 100 % modern 14C for biogas plants confirm that these CO2 streams originate fully from renewable sources, which is critical for regulatory compliance and carbon accounting.
{"title":"Assessment of carbon dioxide quality from industrial point sources for carbon utilization","authors":"Tuula Kajolinna , Siarhei Balshakou , Joonas Mustonen","doi":"10.1016/j.ijggc.2025.104527","DOIUrl":"10.1016/j.ijggc.2025.104527","url":null,"abstract":"<div><div>Carbon dioxide (CO<sub>2</sub>) is increasingly viewed not only as a climate liability but also as a potential feedstock in circular carbon strategies. However, its practical utilization critically depends on both its chemical composition – including application-specific impurity tolerances – and its origin, whether fossil-based or biogenic. This study presents a comprehensive compositional assessment of CO<sub>2</sub>-rich streams from twelve industrial point sources in Finland, with a special focus on biogas upgrading facilities employing diverse purification technologies (membrane separation, water/amine scrubbing, pressure swing absorption (PSA)). Using Fourier Transform Infrared (FTIR), gas chromatograph (GC), adsorption tubes and biogenicity analysis, key impurities affecting downstream suitability for five major applications –food, medical, fuel synthesis, greenhouse use, and permanent storage – were identified, along with the assessment of biogenicity of streams.</div><div>The results indicate that measured membrane-based upgrading plants provided the most suitable CO<sub>2</sub> quality (95.9–97.3 vol-%) for high-purity applications, including the food and beverage industry, medicinal use, and chemical production. This stream requires only limited removal of residual moisture, nitrogen, and oxygen, although elevated concentrations of methane and hydrogen remain a challenge. In contrast, amine scrubbing and PSA processes exhibited higher impurity levels, particularly hydrogen sulfide and volatile organic compounds. Nevertheless, CO<sub>2</sub>-rich off-gas streams from biogas upgrading plants can be directly applied to greenhouse enrichment and concrete curing when appropriate dilutions are performed. Biogenicity values of almost 100 % modern <sup>14</sup>C for biogas plants confirm that these CO<sub>2</sub> streams originate fully from renewable sources, which is critical for regulatory compliance and carbon accounting.</div></div>","PeriodicalId":334,"journal":{"name":"International Journal of Greenhouse Gas Control","volume":"148 ","pages":"Article 104527"},"PeriodicalIF":5.2,"publicationDate":"2025-11-21","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"145577062","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}
Pub Date : 2025-11-15DOI: 10.1016/j.ijggc.2025.104525
Lee J. Hosking , Yazeed A. Al-Noaimat , Xiangming Zhou , Renato Zagorscak , Steven Benbow , Richard Metcalfe
This paper presents a numerical analysis of CO₂ injection well integrity, focusing on degradation of cement sheath bonds with the casing and caprock. The cement sheath and caprock are modelled as thermo-poroelastic materials subject to coupled thermal, hydraulic, and mechanical behaviour. Debonding at the cement-casing and cement-formation interfaces is explicitly modelled in the finite element formulation using a cohesive zone model. A mixed-mode traction-separation failure criterion is employed to capture progressive failure under tension and shear. 144 simulation scenarios are considered for practical ranges of CO₂ injection pressure (15–23 MPa) and temperature (0–15 °C) sustained for 30 days in a well system at 1.5 km depth. Predictions are compared based on the timeframe of damage development and the apertures of any resulting microannuli. For the system studied, CO₂ injection conditions align with the ‘window’ of damage initiation and development at the cement-casing interface, whilst no damage is predicted at the cement-formation interface. Thermal loading has a greater influence on damage development than pressure loading, with lower injection pressures and temperatures producing earlier damage onset and larger microannulus apertures. Higher injection pressures somewhat mitigate damage by counteracting thermal contraction of the system, although this pressure effect would be less pronounced for a real well completion considering the injection tubing and A-annulus fluid. Once initiated, damage develops rapidly and has typically fully evolved within one day. These findings contribute to robust CO₂ storage risk assessments and support planning of corrective measures to ensure long-term wellbore integrity during geological CO₂ storage.
{"title":"Numerical sensitivity analysis of cement sheath bond integrity for CO2 injection wells under pressure and thermal loading","authors":"Lee J. Hosking , Yazeed A. Al-Noaimat , Xiangming Zhou , Renato Zagorscak , Steven Benbow , Richard Metcalfe","doi":"10.1016/j.ijggc.2025.104525","DOIUrl":"10.1016/j.ijggc.2025.104525","url":null,"abstract":"<div><div>This paper presents a numerical analysis of CO₂ injection well integrity, focusing on degradation of cement sheath bonds with the casing and caprock. The cement sheath and caprock are modelled as thermo-poroelastic materials subject to coupled thermal, hydraulic, and mechanical behaviour. Debonding at the cement-casing and cement-formation interfaces is explicitly modelled in the finite element formulation using a cohesive zone model. A mixed-mode traction-separation failure criterion is employed to capture progressive failure under tension and shear. 144 simulation scenarios are considered for practical ranges of CO₂ injection pressure (15–23 MPa) and temperature (0–15 °C) sustained for 30 days in a well system at 1.5 km depth. Predictions are compared based on the timeframe of damage development and the apertures of any resulting microannuli. For the system studied, CO₂ injection conditions align with the ‘window’ of damage initiation and development at the cement-casing interface, whilst no damage is predicted at the cement-formation interface. Thermal loading has a greater influence on damage development than pressure loading, with lower injection pressures and temperatures producing earlier damage onset and larger microannulus apertures. Higher injection pressures somewhat mitigate damage by counteracting thermal contraction of the system, although this pressure effect would be less pronounced for a real well completion considering the injection tubing and A-annulus fluid. Once initiated, damage develops rapidly and has typically fully evolved within one day. These findings contribute to robust CO₂ storage risk assessments and support planning of corrective measures to ensure long-term wellbore integrity during geological CO₂ storage.</div></div>","PeriodicalId":334,"journal":{"name":"International Journal of Greenhouse Gas Control","volume":"148 ","pages":"Article 104525"},"PeriodicalIF":5.2,"publicationDate":"2025-11-15","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"145526747","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}
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