Pub Date : 2025-12-01Epub Date: 2025-11-05DOI: 10.1016/j.ijggc.2025.104521
Doguhan Barlas Sevindik , Oluwafemi Precious Oyenowo , Ryosuke Okuno , Muhammad Farooq Zia , Bo Zhang
Carbon dioxide (CO2) leakage presents a significant risk to carbon storage in saline aquifers. Buoyant forces can cause CO2 in resident brine to migrate into overlying formations through faults, fractures, or existing wells. Wells are especially prone to leakage because CO2 produces an acidic environment, as recently observed in the Illinois Basin Decatur Project (IBDP). This study was motivated by the question of how to mitigate the risk of leakage caused by corrosion in well tubulars.
This research, for the first time, explores the use of sodium formate solution as a corrosion control method based on an IBDP geological model. To evaluate its effectiveness, reactive transport simulations of CO₂ and sodium formate solution injection were performed using the IBDP model. The simulation cases tested different injection rates (80 and 640 m³/d) and concentrations (5 and 15 wt.%), which resulted in varying amounts of sodium formate being injected. Both pre-flush and post-flush injection strategies were considered.
Results indicated that in the pre-flush scenarios, formate can effectively be dispersed by the subsequently injected CO2 (e.g., 150 to 350 meters from the well), while raising the pH above 4.5. However, to mitigate pH reduction near the injector, formate does not need to disperse widely; the scenario involving approximately 2.5 × 103 tonnes of sodium formate resulted in an average pH of 4.45 with a standard deviation of 0.27 along the injection well for 25 years, remaining safely above 4.0, which is the recommended pH range for corrosion control of 13 chrome steel pipe.
{"title":"Corrosion control in carbon storage by injection of sodium formate solution","authors":"Doguhan Barlas Sevindik , Oluwafemi Precious Oyenowo , Ryosuke Okuno , Muhammad Farooq Zia , Bo Zhang","doi":"10.1016/j.ijggc.2025.104521","DOIUrl":"10.1016/j.ijggc.2025.104521","url":null,"abstract":"<div><div>Carbon dioxide (CO<sub>2</sub>) leakage presents a significant risk to carbon storage in saline aquifers. Buoyant forces can cause CO<sub>2</sub> in resident brine to migrate into overlying formations through faults, fractures, or existing wells. Wells are especially prone to leakage because CO<sub>2</sub> produces an acidic environment, as recently observed in the Illinois Basin Decatur Project (IBDP). This study was motivated by the question of how to mitigate the risk of leakage caused by corrosion in well tubulars.</div><div>This research, for the first time, explores the use of sodium formate solution as a corrosion control method based on an IBDP geological model. To evaluate its effectiveness, reactive transport simulations of CO₂ and sodium formate solution injection were performed using the IBDP model. The simulation cases tested different injection rates (80 and 640 m³/d) and concentrations (5 and 15 wt.%), which resulted in varying amounts of sodium formate being injected. Both pre-flush and post-flush injection strategies were considered.</div><div>Results indicated that in the pre-flush scenarios, formate can effectively be dispersed by the subsequently injected CO<sub>2</sub> (e.g., 150 to 350 meters from the well), while raising the pH above 4.5. However, to mitigate pH reduction near the injector, formate does not need to disperse widely; the scenario involving approximately 2.5 × 10<sup>3</sup> tonnes of sodium formate resulted in an average pH of 4.45 with a standard deviation of 0.27 along the injection well for 25 years, remaining safely above 4.0, which is the recommended pH range for corrosion control of 13 chrome steel pipe.</div></div>","PeriodicalId":334,"journal":{"name":"International Journal of Greenhouse Gas Control","volume":"148 ","pages":"Article 104521"},"PeriodicalIF":5.2,"publicationDate":"2025-12-01","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"145475080","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}
Gas injection in CCS is an unstable displacement process due to the viscosity contrast between injected gas and in-situ brine, a fact often overlooked in CO₂ storage modelling. Most studies estimating relative permeability (Relperms) for CCS rely on conventional methods. This paper applies a novel approach that explicitly considers viscous instability from injecting low-viscosity gas into more viscous brine. Based on our earlier studies (A. Beteta et al., 2024; Sorbie et al., 2020). viscous fingering is expected under viscous-dominated conditions. While strong capillary forces may suppress fingering at lab scale, the balance of viscous and capillary forces can shift at field scale, leading to pronounced gas fingering.
To model CO₂ injection, we used published CO₂/water Relperms from CCS experiments. Two approaches were compared: conventional Relperms estimation and an alternative viscous fingering-based method. Simulations using conventional CO₂/water Relperms showed no fingering patterns, whereas our earlier study indicated that core flood experiments with a water–CO₂ viscosity ratio of ∼55 may generate gas fingers. The second approach, based on maximum mobility, produced gas fingers and matched production and differential pressure equally well.
This apparent absence of fingering may suggest limitations in the conventional representation of flow dynamics under such conditions. Possible reasons why experimental relative permeabilities do not capture the expected “fingering behaviour” are discussed in this paper. The main difference between our proposed Relperms and lab derived Relperms is in the total mobility, with our Relperms having a higher total mobility at the shock front gas saturations (Sgf) of CO2.
由于注入气体和原位盐水之间的粘度差异，CCS中的注气是一个不稳定的驱油过程，这一事实在CO₂储存建模中经常被忽视。大多数估算CCS相对渗透率（Relperms）的研究都依赖于传统方法。本文采用了一种新颖的方法，明确考虑了将低粘度气体注入黏度更高的盐水所产生的黏性不稳定性。基于我们早期的研究（A. beta et al., 2024; Sorbie et al., 2020）。粘性指法是预期在粘性主导的条件下。虽然在实验室尺度上，强大的毛细力可能会抑制指动，但在现场尺度上，粘性和毛细力的平衡可能会发生变化，导致明显的气指动。为了模拟二氧化碳的注入，我们使用了CCS实验中公布的二氧化碳/水浓度。比较了两种方法：常规的Relperms估计方法和基于粘性指法的替代方法。使用常规CO 2 /water Relperms进行的模拟没有显示出指状模式，而我们早期的研究表明，水- CO 2粘度比为~ 55的岩心注水实验可能会产生气指状模式。第二种方法基于最大的流动性，产生了气指，同时也很好地匹配了产量和压差。这种明显的指法缺失可能表明在这种条件下流动动力学的传统表示存在局限性。可能的原因，为什么实验相对渗透率不捕获预期的“指法行为”在本文中进行了讨论。我们提出的Relperms和实验室衍生的Relperms之间的主要区别在于总迁移率，我们的Relperms在CO2的激波前气体饱和度（Sgf）下具有更高的总迁移率。
{"title":"Numerical simulation of viscous fingering in CO₂ storage: Addressing the limitations of laboratory-derived relative permeabilities","authors":"S.A. Larki , A. Skauge , K.S. Sorbie , E.J. Mackay","doi":"10.1016/j.ijggc.2025.104523","DOIUrl":"10.1016/j.ijggc.2025.104523","url":null,"abstract":"<div><div>Gas injection in CCS is an unstable displacement process due to the viscosity contrast between injected gas and in-situ brine, a fact often overlooked in CO₂ storage modelling. Most studies estimating relative permeability (Relperms) for CCS rely on conventional methods. This paper applies a novel approach that explicitly considers viscous instability from injecting low-viscosity gas into more viscous brine. Based on our earlier studies (A. Beteta et al., 2024; Sorbie et al., 2020). viscous fingering is expected under viscous-dominated conditions. While strong capillary forces may suppress fingering at lab scale, the balance of viscous and capillary forces can shift at field scale, leading to pronounced gas fingering.</div><div>To model CO₂ injection, we used published CO₂/water Relperms from CCS experiments. Two approaches were compared: conventional Relperms estimation and an alternative viscous fingering-based method. Simulations using conventional CO₂/water Relperms showed no fingering patterns, whereas our earlier study indicated that core flood experiments with a water–CO₂ viscosity ratio of ∼55 may generate gas fingers. The second approach, based on maximum mobility, produced gas fingers and matched production and differential pressure equally well.</div><div>This apparent absence of fingering may suggest limitations in the conventional representation of flow dynamics under such conditions. Possible reasons why experimental relative permeabilities do not capture the expected “fingering behaviour” are discussed in this paper. The main difference between our proposed Relperms and lab derived Relperms is in the total mobility, with our Relperms having a higher total mobility at the shock front gas saturations (S<sub>gf</sub>) of CO<sub>2</sub>.</div></div>","PeriodicalId":334,"journal":{"name":"International Journal of Greenhouse Gas Control","volume":"148 ","pages":"Article 104523"},"PeriodicalIF":5.2,"publicationDate":"2025-12-01","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"145475082","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 : 2025-12-01Epub Date: 2025-11-08DOI: 10.1016/j.ijggc.2025.104524
Mohammad Nooraiepour , Karol M. Dąbrowski , Mohammad Masoudi , Szymon Kuczyński , Zezhang Song , Ane Elisabet Lothe , Helge Hellevang
Emerging carbon capture and storage (CCS) markets face critical challenges in developing systematic methodologies to assess geological CO2 storage potential under conditions of limited data availability, evolving regulatory frameworks, and nascent infrastructure development. This study establishes an integrated assessment framework for lower-maturity CCS regions that combines geological characterization, storage capacity assessment, regulatory analysis, and socio-economic evaluation through a structured approach adaptable to diverse global contexts. Poland serves as a representative case study, with its coal-reliant economy exemplifying the decarbonization challenges facing emerging regions while meeting European Union climate mandates, and its geological setting offering substantial sequestration opportunities across three major sedimentary regions. Through multidisciplinary analysis synthesizing scattered geological data, policy developments, CCUS value chain dynamics, and stakeholder perspectives, we systematically evaluate CO2 storage potential and demonstrate framework application. Analysis reveals that onshore saline aquifers and depleted hydrocarbon fields provide significant storage capacity, while offshore Baltic Basin sites face logistical and environmental regulatory constraints. Current assessments encounter limitations including sparse data, restricted research access, and inadequate industry-academia collaboration, preventing basin-scale analyses from advancing to higher storage readiness levels and undermining business decision-making reliability. This study contributes a replicable methodology extending beyond Poland to lower-maturity CCS regions worldwide, providing decision-makers with tools for storage assessment, policy development, and stakeholder engagement that support evidence-based deployment strategies. Success in emerging markets requires coordinated advancement across technical characterization, regulatory clarity, infrastructure development, and public engagement, with transparent governance and inclusive community participation as critical enablers for sustainable CCS implementation.
{"title":"Geological CO2 storage assessment in emerging CCS regions: Review of sequestration potential, policy development, and socio-economic factors in Poland","authors":"Mohammad Nooraiepour , Karol M. Dąbrowski , Mohammad Masoudi , Szymon Kuczyński , Zezhang Song , Ane Elisabet Lothe , Helge Hellevang","doi":"10.1016/j.ijggc.2025.104524","DOIUrl":"10.1016/j.ijggc.2025.104524","url":null,"abstract":"<div><div>Emerging carbon capture and storage (CCS) markets face critical challenges in developing systematic methodologies to assess geological CO<sub>2</sub> storage potential under conditions of limited data availability, evolving regulatory frameworks, and nascent infrastructure development. This study establishes an integrated assessment framework for lower-maturity CCS regions that combines geological characterization, storage capacity assessment, regulatory analysis, and socio-economic evaluation through a structured approach adaptable to diverse global contexts. Poland serves as a representative case study, with its coal-reliant economy exemplifying the decarbonization challenges facing emerging regions while meeting European Union climate mandates, and its geological setting offering substantial sequestration opportunities across three major sedimentary regions. Through multidisciplinary analysis synthesizing scattered geological data, policy developments, CCUS value chain dynamics, and stakeholder perspectives, we systematically evaluate CO<sub>2</sub> storage potential and demonstrate framework application. Analysis reveals that onshore saline aquifers and depleted hydrocarbon fields provide significant storage capacity, while offshore Baltic Basin sites face logistical and environmental regulatory constraints. Current assessments encounter limitations including sparse data, restricted research access, and inadequate industry-academia collaboration, preventing basin-scale analyses from advancing to higher storage readiness levels and undermining business decision-making reliability. This study contributes a replicable methodology extending beyond Poland to lower-maturity CCS regions worldwide, providing decision-makers with tools for storage assessment, policy development, and stakeholder engagement that support evidence-based deployment strategies. Success in emerging markets requires coordinated advancement across technical characterization, regulatory clarity, infrastructure development, and public engagement, with transparent governance and inclusive community participation as critical enablers for sustainable CCS implementation.</div></div>","PeriodicalId":334,"journal":{"name":"International Journal of Greenhouse Gas Control","volume":"148 ","pages":"Article 104524"},"PeriodicalIF":5.2,"publicationDate":"2025-12-01","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"145475083","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 : 2025-12-01Epub 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":"2025-12-01","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}
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":"2025-12-01","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 : 2025-12-01Epub Date: 2025-11-28DOI: 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 : 2025-12-01Epub Date: 2025-11-01DOI: 10.1016/j.ijggc.2025.104506
Fred Closmann, Yuying Wu, Chih-I Chen, Ariel Z. Plantz, Gary T. Rochelle
The University of Texas at Austin ran a carbon capture pilot campaign at the Separations Research Program 0.1-MWe facility to test oxidation mitigation strategies in 5 m piperazine (PZ) using the Piperazine with the Advanced Stripper (PZAS) process. A synthetic natural gas combined cycle (NGCC) flue gas with 4 % CO2 and 20 % O2 was used in the campaign. Mitigation methods tested included N2 gas sparging in the absorber sump for dissolved oxygen (DO) stripping and carbon treating of solvent for dissolved metal ion removal. NO2 was blended into the flue gas and absorbed by the solvent at a rate of 42 %. 2-oxopiperazine (OPZ) formed at the greatest concentration of the degradation products through a catalytic process at up to 10:1 molar ratio with NO2 absorbed. Mononitrosopiperazine (MNPZ) was formed at a 1:1 molar ratio with NO2 absorbed, demonstrating stoichiometric reaction behaviour. The data support the hypothesis that NO2 reacts with PZ in the absorber to form nitrite and PZ radicals (PZ•). Nitrite reacts with PZ to form MNPZ, while the PZ radicals will participate in radical propagation reactions. At a gas rate of 1 % of total gas traffic in the absorber, N2 gas sparging into the absorber sump removed 85 % of DO.
德克萨斯大学奥斯汀分校（University of Texas at Austin）在分离研究项目（separation Research Program）的0.1 mwe设施中进行了一项碳捕集试验，使用piperazine与高级脱提器（PZAS）工艺，测试5米哌嗪（PZ）的氧化减缓策略。该活动使用了含4% CO2和20% O2的合成天然气联合循环（NGCC）烟气。测试的缓解方法包括在吸收池中喷射氮气以溶出溶解氧（DO）和对溶剂进行碳处理以去除溶解金属离子。将NO2混入烟气中，并以42%的速率被溶剂吸收。2-氧哌嗪（OPZ）在吸收NO2的条件下，以10∶1的摩尔比催化生成。在吸收NO2的条件下，以1:1的摩尔比生成单硝基哌嗪（MNPZ），表现出化学计量反应行为。这些数据支持了NO2在吸收剂中与PZ反应生成亚硝酸盐和PZ自由基（PZ•）的假设。亚硝酸盐与PZ反应生成MNPZ，而PZ自由基则参与自由基增殖反应。当气体流量为吸收塔总气体流量的1%时，喷入吸收塔底壳的N2气体去除了85%的DO。
{"title":"Pilot testing of mitigation methods for piperazine oxidation","authors":"Fred Closmann, Yuying Wu, Chih-I Chen, Ariel Z. Plantz, Gary T. Rochelle","doi":"10.1016/j.ijggc.2025.104506","DOIUrl":"10.1016/j.ijggc.2025.104506","url":null,"abstract":"<div><div>The University of Texas at Austin ran a carbon capture pilot campaign at the Separations Research Program 0.1-MW<sub>e</sub> facility to test oxidation mitigation strategies in 5 m piperazine (PZ) using the Piperazine with the Advanced Stripper (PZAS) process. A synthetic natural gas combined cycle (NGCC) flue gas with 4 % CO<sub>2</sub> and 20 % O<sub>2</sub> was used in the campaign. Mitigation methods tested included N<sub>2</sub> gas sparging in the absorber sump for dissolved oxygen (DO) stripping and carbon treating of solvent for dissolved metal ion removal. NO<sub>2</sub> was blended into the flue gas and absorbed by the solvent at a rate of 42 %. 2-oxopiperazine (OPZ) formed at the greatest concentration of the degradation products through a catalytic process at up to 10:1 molar ratio with NO<sub>2</sub> absorbed. Mononitrosopiperazine (MNPZ) was formed at a 1:1 molar ratio with NO<sub>2</sub> absorbed, demonstrating stoichiometric reaction behaviour. The data support the hypothesis that NO<sub>2</sub> reacts with PZ in the absorber to form nitrite and PZ radicals (PZ•). Nitrite reacts with PZ to form MNPZ, while the PZ radicals will participate in radical propagation reactions. At a gas rate of 1 % of total gas traffic in the absorber, N<sub>2</sub> gas sparging into the absorber sump removed 85 % of DO.</div></div>","PeriodicalId":334,"journal":{"name":"International Journal of Greenhouse Gas Control","volume":"148 ","pages":"Article 104506"},"PeriodicalIF":5.2,"publicationDate":"2025-12-01","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"145414648","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 : 2025-12-01Epub Date: 2025-11-05DOI: 10.1016/j.ijggc.2025.104522
Rasesh Pokharel , Guangnan Wu , Peter Kraal , Jasper Griffioen , Joris Dijkstra , Gert-Jan Reichart , Helen E. King
Enhanced silicate weathering (ESW) shows promise in converting atmospheric CO2 into inorganic carbonates via mineral weathering. This study investigates the potential of utilizing olivine containing mineral mixtures from waste rock and tailings (olivine purity ∼ 55% and mean particle size ∼ 39 µm) for ESW in seawater. A decrease in olivine weathering rate over time was observed in the form of diminishing Mg release rates due to the formation of passivating layers at the mineral surface. Quantitative mineralogical analysis revealed a reduction in the olivine percentage (up to 8.6%) in the reacted mineral mixture indicating a reaction that results in CO2 sequestration. However, there was also simultaneous precipitation of 2:1 layer silicates and a possible amorphous clay mineral (a CO2-releasing process known as reverse weathering). The highest deployed material dosages released significant amounts of nickel (Ni) and cobalt (Co) into the solution, emphasizing the need for careful consideration in large-scale ESW deployment. The CO2 sequestration rate measured at 90 days of the olivine-mineral mixture was calculated to be 3.80 × 10−12 mol CO2 m−2 s−1, equating to 14.43 kg of CO2 sequestered per ton of olivine-mineral mixture per year. As rates decline non-linearly, this value reflects short-term kinetics, highlighting the need for Monitoring Reporting and Verification (MRV) based on windowed rates and cumulative uptake. These findings suggest that olivine containing mineral mixtures from mine waste and tailings represent a durable carbon storage, characterized by high early fluxes that decline over time, with material dosage critical for efficiency and metal risks.
增强硅酸盐风化（ESW）有望通过矿物风化将大气中的二氧化碳转化为无机碳酸盐。本研究探讨了利用废岩石和尾矿中含有橄榄石的矿物混合物（橄榄石纯度~ 55%，平均粒径~ 39µm）在海水中制备ESW的潜力。随着时间的推移，由于矿物表面钝化层的形成，观察到橄榄石风化速率的降低，表现为Mg释放速率的减少。定量矿物学分析显示，在反应的矿物混合物中，橄榄石的百分比减少了（高达8.6%），表明反应导致了二氧化碳的封存。然而，同时也有2:1的硅酸盐层和一种可能的无定形粘土矿物（一种被称为反向风化的二氧化碳释放过程）的沉淀。最高的材料用量释放了大量的镍（Ni）和钴（Co）到溶液中，这强调了在大规模ESW部署时需要仔细考虑的问题。计算得出，橄榄石-矿物混合物90天的CO2固存率为3.80 × 10−12 mol CO2 m−2 s−1，相当于每年每吨橄榄石-矿物混合物固存了14.43 kg CO2。由于速率呈非线性下降，该值反映了短期动力学，强调了基于窗口速率和累积吸收的监测报告和验证（MRV）的必要性。这些发现表明，来自矿山废物和尾矿的含有矿物混合物的橄榄石是一种持久的碳储存方式，其特点是早期通量高，随着时间的推移而下降，材料剂量对效率和金属风险至关重要。
{"title":"Viability of commercial olivine mixtures for enhanced weathering in seawater: Dissolution kinetics, CO2 sequestration, and metal release assessment","authors":"Rasesh Pokharel , Guangnan Wu , Peter Kraal , Jasper Griffioen , Joris Dijkstra , Gert-Jan Reichart , Helen E. King","doi":"10.1016/j.ijggc.2025.104522","DOIUrl":"10.1016/j.ijggc.2025.104522","url":null,"abstract":"<div><div>Enhanced silicate weathering (ESW) shows promise in converting atmospheric CO<sub>2</sub> into inorganic carbonates via mineral weathering. This study investigates the potential of utilizing olivine containing mineral mixtures from waste rock and tailings (olivine purity ∼ 55% and mean particle size ∼ 39 µm) for ESW in seawater. A decrease in olivine weathering rate over time was observed in the form of diminishing Mg release rates due to the formation of passivating layers at the mineral surface. Quantitative mineralogical analysis revealed a reduction in the olivine percentage (up to 8.6%) in the reacted mineral mixture indicating a reaction that results in CO<sub>2</sub> sequestration. However, there was also simultaneous precipitation of 2:1 layer silicates and a possible amorphous clay mineral (a CO<sub>2</sub>-releasing process known as reverse weathering). The highest deployed material dosages released significant amounts of nickel (Ni) and cobalt (Co) into the solution, emphasizing the need for careful consideration in large-scale ESW deployment. The CO<sub>2</sub> sequestration rate measured at 90 days of the olivine-mineral mixture was calculated to be 3.80 × 10<sup>−12</sup> mol CO<sub>2</sub> m<sup>−2</sup> s<sup>−1</sup>, equating to 14.43 kg of CO<sub>2</sub> sequestered per ton of olivine-mineral mixture per year. As rates decline non-linearly, this value reflects short-term kinetics, highlighting the need for Monitoring Reporting and Verification (MRV) based on windowed rates and cumulative uptake. These findings suggest that olivine containing mineral mixtures from mine waste and tailings represent a durable carbon storage, characterized by high early fluxes that decline over time, with material dosage critical for efficiency and metal risks.</div></div>","PeriodicalId":334,"journal":{"name":"International Journal of Greenhouse Gas Control","volume":"148 ","pages":"Article 104522"},"PeriodicalIF":5.2,"publicationDate":"2025-12-01","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"145475029","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 : 2025-12-01Epub Date: 2025-11-10DOI: 10.1016/j.ijggc.2025.104520
Frederick Pessu , Alice Macente , Olujide Sanni , Sandra Piazolo
As global emissions fail to reduce rapidly, Carbon Capture and Storage (CCS) is attracting ever-growing attention. CCS involves capturing, treating, transporting and storing CO2 to ensure its long-term removal from the atmosphere. To design a viable CCS system, the different interactions and impacts of injected CO2 (either as sub-critical or supercritical fluid) across the whole CCS system need to be considered. However, it is unclear how changes in fluid chemistry and the pre-existing reservoir rock chemistry influence the evolution of the two key storage properties, porosity and permeability.
This study investigates how upstream corrosion-induced fluid chemistry changes and realistic rock composition could affect the injectivity and storage capacity of reservoirs. The condition and material chosen for this project fall into the possible envelope of conditions of interest during CO2 injection and storage. Corrosion occurring during CO2 injection through saline aquifers was simulated at 40 bar, 60°C for two weeks, using X65 carbon and 13Cr steel. The fluid resulting from the experimental fluid-metal interaction was then reacted at ∼40 bar, 60°C for another two weeks with two fine-grained arkoses, with and without lithic clast, representative of siliciclastic reservoir rocks.
Results show that upstream corrosion caused a change in fluid chemistry and decreased fluid acidity. The corrosion-induced chemical changes had a marked effect on the evolution of porosity and permeability within the reservoir rocks. The storage capacity of reservoir rocks with diverse mineralogy is highly dynamic, and directly affected by rock chemical composition and, importantly, the chemical evolution of the incoming fluid.
{"title":"The importance of whole system considerations for sustainable, long-term CO2 injection and storage: Interplay between infrastructure-related corrosion and reservoir rock chemistry effects on the evolution of the CO2 storage capacity","authors":"Frederick Pessu , Alice Macente , Olujide Sanni , Sandra Piazolo","doi":"10.1016/j.ijggc.2025.104520","DOIUrl":"10.1016/j.ijggc.2025.104520","url":null,"abstract":"<div><div>As global emissions fail to reduce rapidly, Carbon Capture and Storage (CCS) is attracting ever-growing attention. CCS involves capturing, treating, transporting and storing CO<sub>2</sub> to ensure its long-term removal from the atmosphere. To design a viable CCS system, the different interactions and impacts of injected CO<sub>2</sub> (either as sub-critical or supercritical fluid) across the whole CCS system need to be considered. However, it is unclear how changes in fluid chemistry and the pre-existing reservoir rock chemistry influence the evolution of the two key storage properties, porosity and permeability.</div><div>This study investigates how upstream corrosion-induced fluid chemistry changes and realistic rock composition could affect the injectivity and storage capacity of reservoirs. The condition and material chosen for this project fall into the possible envelope of conditions of interest during CO<sub>2</sub> injection and storage. Corrosion occurring during CO<sub>2</sub> injection through saline aquifers was simulated at 40 bar, 60°C for two weeks, using X65 carbon and <sup>13</sup>Cr steel. The fluid resulting from the experimental fluid-metal interaction was then reacted at ∼40 bar, 60°C for another two weeks with two fine-grained arkoses, with and without lithic clast, representative of siliciclastic reservoir rocks.</div><div>Results show that upstream corrosion caused a change in fluid chemistry and decreased fluid acidity. The corrosion-induced chemical changes had a marked effect on the evolution of porosity and permeability within the reservoir rocks. The storage capacity of reservoir rocks with diverse mineralogy is highly dynamic, and directly affected by rock chemical composition and, importantly, the chemical evolution of the incoming fluid.</div></div>","PeriodicalId":334,"journal":{"name":"International Journal of Greenhouse Gas Control","volume":"148 ","pages":"Article 104520"},"PeriodicalIF":5.2,"publicationDate":"2025-12-01","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"145526748","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 : 2025-12-01Epub Date: 2025-11-29DOI: 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}
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