Pub Date : 2025-12-27DOI: 10.1016/j.ijggc.2025.104564
Maryam Eslami , Xi Wang , Yoon-Seok Choi
Four different corrosion-resistant alloys (13Cr, super 13Cr, 25Cr duplex stainless, 25Cr super duplex stainless steel) were studied under two different CO2 partial pressures (0 and 13.8 MPa) at high temperature (150 °C) in a 3 wt.% NaCl solution. Electrochemical and exposure experiments were conducted at a consistent initial pH for comparison. The results indicate that 13Cr exhibits active corrosion behavior, whereas super 13Cr demonstrates typical passive behavior without re-passivation under the testing conditions. Both 25Cr duplex and 25Cr super duplex steels show exceptional corrosion resistance and passive behavior, with re-passivation potentials higher than corrosion potential in nearly all testing conditions. Passive films show similar composition and forward-scan responses under both experimental conditions; however, in the CO2 environment, the alloys repassivated only at more negative potentials than in the CO₂-free condition.
{"title":"Influence of CO2 partial pressure on electrochemical behavior of corrosion-resistant alloys for CO2 injection tubing of carbon capture and storage system","authors":"Maryam Eslami , Xi Wang , Yoon-Seok Choi","doi":"10.1016/j.ijggc.2025.104564","DOIUrl":"10.1016/j.ijggc.2025.104564","url":null,"abstract":"<div><div>Four different corrosion-resistant alloys (13Cr, super 13Cr, 25Cr duplex stainless, 25Cr super duplex stainless steel) were studied under two different CO<sub>2</sub> partial pressures (0 and 13.8 MPa) at high temperature (150 °C) in a 3 wt.% NaCl solution. Electrochemical and exposure experiments were conducted at a consistent initial pH for comparison. The results indicate that 13Cr exhibits active corrosion behavior, whereas super 13Cr demonstrates typical passive behavior without re-passivation under the testing conditions. Both 25Cr duplex and 25Cr super duplex steels show exceptional corrosion resistance and passive behavior, with re-passivation potentials higher than corrosion potential in nearly all testing conditions. Passive films show similar composition and forward-scan responses under both experimental conditions; however, in the CO<sub>2</sub> environment, the alloys repassivated only at more negative potentials than in the CO₂-free condition.</div></div>","PeriodicalId":334,"journal":{"name":"International Journal of Greenhouse Gas Control","volume":"149 ","pages":"Article 104564"},"PeriodicalIF":5.2,"publicationDate":"2025-12-27","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"145837180","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}
This study presents a techno-economic comparison of three amine technologies for CO2 capture from three major CO2-rich flue gases in integrated iron and steelmaking processes. The amine technologies were based on aqueous solutions of 30 wt% MEA, a 13 wt% PZ and 27 wt% AMP blend (PZ/AMP), and CSIRO’s proprietary CAL008 absorbent. The flue gases considered, in order of decreasing CO2 intensity, were blast furnace gas (BFG), sintering gas (SG), and basic oxygen furnace gas (BOFG). Carbon capture systems utilised amine solutions in standard absorber-stripper and modified cold rich-split process configurations. The processes were simulated using ProTreat®, employing a rate-based approach to design and simulate absorber and stripper columns, targeting 90 % capture. Using the standard design, CAL008 achieved minimum regeneration duties of 2.82–2.97 MJ/kg CO2, comparable to PZ/AMP (2.56–2.76 MJ/kg CO2) and significantly lower than MEA (3.20–3.30 MJ/kg CO2). The cold rich-split modification further reduced the minimum regeneration duty, particulalry for BFG, with reductions of 14.3 % for CAL008, 12 % for PZ/AMP, and 6.2 % for MEA. The levelised cost of carbon capture (LCCC) was lowest for PZ/AMP among the amine technologies when applied to BFG, primarily due to its lower regeneration energy requirement. However, when considering absorbent management costs—including those associated with thermal and oxidative degradation, thermal reclaiming, and waste disposal—CAL008 had a lower LCCC than PZ/AMP and MEA for SG and BOFG. This advantage primarily stemmed from CAL008’s ability to be recovered from a degradation product, in contrast to MEA and PZ/AMP, which required replacement with fresh absorbent.
{"title":"Energy and economic performance of three amine technologies for carbon capture in integrated iron and steel production plants","authors":"Ehsan Soroodan , Graeme Puxty , Sanger Huang , Paul Feron","doi":"10.1016/j.ijggc.2025.104561","DOIUrl":"10.1016/j.ijggc.2025.104561","url":null,"abstract":"<div><div>This study presents a techno-economic comparison of three amine technologies for CO<sub>2</sub> capture from three major CO<sub>2</sub>-rich flue gases in integrated iron and steelmaking processes. The amine technologies were based on aqueous solutions of 30 wt% MEA, a 13 wt% PZ and 27 wt% AMP blend (PZ/AMP), and CSIRO’s proprietary CAL008 absorbent. The flue gases considered, in order of decreasing CO<sub>2</sub> intensity, were blast furnace gas (BFG), sintering gas (SG), and basic oxygen furnace gas (BOFG). Carbon capture systems utilised amine solutions in standard absorber-stripper and modified cold rich-split process configurations. The processes were simulated using ProTreat®, employing a rate-based approach to design and simulate absorber and stripper columns, targeting 90 % capture. Using the standard design, CAL008 achieved minimum regeneration duties of 2.82–2.97 MJ/kg CO<sub>2</sub>, comparable to PZ/AMP (2.56–2.76 MJ/kg CO<sub>2</sub>) and significantly lower than MEA (3.20–3.30 MJ/kg CO<sub>2</sub>). The cold rich-split modification further reduced the minimum regeneration duty, particulalry for BFG, with reductions of 14.3 % for CAL008, 12 % for PZ/AMP, and 6.2 % for MEA. The levelised cost of carbon capture (LCCC) was lowest for PZ/AMP among the amine technologies when applied to BFG, primarily due to its lower regeneration energy requirement. However, when considering absorbent management costs—including those associated with thermal and oxidative degradation, thermal reclaiming, and waste disposal—CAL008 had a lower LCCC than PZ/AMP and MEA for SG and BOFG. This advantage primarily stemmed from CAL008’s ability to be recovered from a degradation product, in contrast to MEA and PZ/AMP, which required replacement with fresh absorbent.</div></div>","PeriodicalId":334,"journal":{"name":"International Journal of Greenhouse Gas Control","volume":"149 ","pages":"Article 104561"},"PeriodicalIF":5.2,"publicationDate":"2025-12-27","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"145837178","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 : 2025-12-27DOI: 10.1016/j.ijggc.2025.104562
Marcopolo Alcantara Fuentes , Taehyung Park , Min-Kyung Jeon , Joo Yong Lee , Tae-Hyuk Kwon
This study tests the hypothesis that sodium dodecyl sulfate, a commercially available anionic surfactant, can enhance CO2 injection efficiency in geological carbon storage systems by simultaneously reducing interfacial tension and altering rock wettability. High-pressure and high-temperature experiments covered a wide range of pressure and temperature (1–12 MPa, 25–80 °C), covering from gaseous, sub-critical, to supercritical CO2 phases, and measured interfacial tensions and contact angles on quartz, Berea sandstone, and Mancos shale substrates in the absence and presence of sodium dodecyl sulfate. Results show that sodium dodecyl sulfate reduces the interfacial tension between CO2 and brine by up to 61% at 40 °C, with reduced effectiveness at 80 °C due to increased critical micelle concentration and thermal effects on surfactant packing. Static and dynamic contact angle measurements reveal that sodium dodecyl sulfate consistently shifts wettability toward more water-wet conditions, with quartz exhibiting the greatest sensitivity and shale showing moderate change. The pore network modelling analysis demonstrates that reductions in capillary factor caused by this anionic surfactant increase CO2 sweep efficiency. These findings highlight that sodium dodecyl sulfate can improve injectivity via interfacial tension reduction and can also enhance structural trapping by shalely caprock through wettability alteration. This study provides the first systematic experimental evidence of such effects on reservoir-relevant lithologies, sandstone as porous media and shale as caprock.
{"title":"Effect of anionic surfactant on interfacial tension and wettability of rock/water/CO2 system under geological carbon storage conditions","authors":"Marcopolo Alcantara Fuentes , Taehyung Park , Min-Kyung Jeon , Joo Yong Lee , Tae-Hyuk Kwon","doi":"10.1016/j.ijggc.2025.104562","DOIUrl":"10.1016/j.ijggc.2025.104562","url":null,"abstract":"<div><div>This study tests the hypothesis that sodium dodecyl sulfate, a commercially available anionic surfactant, can enhance CO<sub>2</sub> injection efficiency in geological carbon storage systems by simultaneously reducing interfacial tension and altering rock wettability. High-pressure and high-temperature experiments covered a wide range of pressure and temperature (1–12 MPa, 25–80 °C), covering from gaseous, sub-critical, to supercritical CO2 phases, and measured interfacial tensions and contact angles on quartz, Berea sandstone, and Mancos shale substrates in the absence and presence of sodium dodecyl sulfate. Results show that sodium dodecyl sulfate reduces the interfacial tension between CO<sub>2</sub> and brine by up to 61% at 40 °C, with reduced effectiveness at 80 °C due to increased critical micelle concentration and thermal effects on surfactant packing. Static and dynamic contact angle measurements reveal that sodium dodecyl sulfate consistently shifts wettability toward more water-wet conditions, with quartz exhibiting the greatest sensitivity and shale showing moderate change. The pore network modelling analysis demonstrates that reductions in capillary factor caused by this anionic surfactant increase CO<sub>2</sub> sweep efficiency. These findings highlight that sodium dodecyl sulfate can improve injectivity via interfacial tension reduction and can also enhance structural trapping by shalely caprock through wettability alteration. This study provides the first systematic experimental evidence of such effects on reservoir-relevant lithologies, sandstone as porous media and shale as caprock.</div></div>","PeriodicalId":334,"journal":{"name":"International Journal of Greenhouse Gas Control","volume":"149 ","pages":"Article 104562"},"PeriodicalIF":5.2,"publicationDate":"2025-12-27","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"145837179","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 : 2025-12-24DOI: 10.1016/j.ijggc.2025.104554
Seyi Philemon Akanji , Rossen Sedev , Lionel Esteban , Ausama Giwelli , Trevor Beardsmore , Heather Howard , Joel Sarout , Alireza Keshavarz , Stefan Iglauer
Geosequestration of carbon dioxide in basaltic rock formations is considered to have the potential to safely and permanently store significant quantities of this greenhouse gas and thereby mitigate its potential global warming effect. The success of this storage method is primarily dependent on the wettability behaviour of the rock-water-CO2 system, which significantly affects fluid distribution, fluid transport, storage capacity and containment security. This study investigates the wettability performance of several Western Australian altered basaltic rocks, of similar geochemistry, porosity and inter-connection. The wettability behaviour of the basaltic materials is assessed using water containing ions that have been leached from the rock samples used in this investigation (Synthetic Formational Water). Under realistic geo-storage conditions, most samples exhibited intermediate -wet behaviour at pressures of 10 to 80 bar and a temperature of 50 °C. Further increase in pressure from 80 to 100 bar at 50 °C changed the wettability of the altered basaltic rock samples with most samples changing from an intermediate-wet state to weakly CO2-wet state, while the other sample maintained this intermediate-wet at 100 bar and 50 °C temperature. This study highlights the potential of Western Australian altered basaltic rocks to be used for the mineral storage of CO2.
{"title":"Towards carbon geosequestration: comparing the wettability performance of Western Australian altered basaltic rock/CO2/water systems","authors":"Seyi Philemon Akanji , Rossen Sedev , Lionel Esteban , Ausama Giwelli , Trevor Beardsmore , Heather Howard , Joel Sarout , Alireza Keshavarz , Stefan Iglauer","doi":"10.1016/j.ijggc.2025.104554","DOIUrl":"10.1016/j.ijggc.2025.104554","url":null,"abstract":"<div><div>Geosequestration of carbon dioxide in basaltic rock formations is considered to have the potential to safely and permanently store significant quantities of this greenhouse gas and thereby mitigate its potential global warming effect. The success of this storage method is primarily dependent on the wettability behaviour of the rock-water-CO<sub>2</sub> system, which significantly affects fluid distribution, fluid transport, storage capacity and containment security. This study investigates the wettability performance of several Western Australian altered basaltic rocks, of similar geochemistry, porosity and inter-connection. The wettability behaviour of the basaltic materials is assessed using water containing ions that have been leached from the rock samples used in this investigation (Synthetic Formational Water). Under realistic geo-storage conditions, most samples exhibited intermediate -wet behaviour at pressures of 10 to 80 bar and a temperature of 50 °C. Further increase in pressure from 80 to 100 bar at 50 °C changed the wettability of the altered basaltic rock samples with most samples changing from an intermediate-wet state to weakly CO<sub>2</sub>-wet state, while the other sample maintained this intermediate-wet at 100 bar and 50 °C temperature. This study highlights the potential of Western Australian altered basaltic rocks to be used for the mineral storage of CO<sub>2</sub>.</div></div>","PeriodicalId":334,"journal":{"name":"International Journal of Greenhouse Gas Control","volume":"149 ","pages":"Article 104554"},"PeriodicalIF":5.2,"publicationDate":"2025-12-24","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"145837176","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 : 2025-12-24DOI: 10.1016/j.ijggc.2025.104559
Cyril Bajamundi , Timo Leino , Juho Kauppinen , Oona Louhola , Mikko Lappalainen
Operating electrically heated kilns under high-CO2 atmospheres can increase CO2 capture efficiency but creates reducing conditions that drive CO formation. In this work, CO generation during limestone calcination in a 280 kW electrically heated rotary kiln at 75 vol-% CO2 and low O2 concentration is investigated. Equilibrium calculations indicate that sulphide and sulphite phases in limestone decompose, releasing SO2 and promoting CO formation. Complementary packed-bed experiments confirm that sulphur species are a major CO promoter and reveal a synergistic interaction between sulphur compounds and elevated CO2 levels. Using low-sulphur limestone could suppress CO emissions. Where low-sulphur feedstocks are unavailable, targeted electrolytic O2 or air injection coupled with indirect limestone preheating is proposed to strip sulphur and preserve the high-purity CO2 stream which will improve the efficiency of electrified kilns integrated with a carbon capture process.
{"title":"Production of high-concentration CO2 from electrified limestone calcination for carbon capture applications","authors":"Cyril Bajamundi , Timo Leino , Juho Kauppinen , Oona Louhola , Mikko Lappalainen","doi":"10.1016/j.ijggc.2025.104559","DOIUrl":"10.1016/j.ijggc.2025.104559","url":null,"abstract":"<div><div>Operating electrically heated kilns under high-CO<sub>2</sub> atmospheres can increase CO<sub>2</sub> capture efficiency but creates reducing conditions that drive CO formation. In this work, CO generation during limestone calcination in a 280 kW electrically heated rotary kiln at 75<!--> <!-->vol-% CO<sub>2</sub> and low O<sub>2</sub> concentration is investigated. Equilibrium calculations indicate that sulphide and sulphite phases in limestone decompose, releasing SO<sub>2</sub> and promoting CO formation. Complementary packed-bed experiments confirm that sulphur species are a major CO promoter and reveal a synergistic interaction between sulphur compounds and elevated CO<sub>2</sub> levels. Using low-sulphur limestone could suppress CO emissions. Where low-sulphur feedstocks are unavailable, targeted electrolytic O<sub>2</sub> or air injection coupled with indirect limestone preheating is proposed to strip sulphur and preserve the high-purity CO<sub>2</sub> stream which will improve the efficiency of electrified kilns integrated with a carbon capture process.</div></div>","PeriodicalId":334,"journal":{"name":"International Journal of Greenhouse Gas Control","volume":"149 ","pages":"Article 104559"},"PeriodicalIF":5.2,"publicationDate":"2025-12-24","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"145837175","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 : 2025-12-20DOI: 10.1016/j.ijggc.2025.104563
Rikke C. Pedersen , Simon Roussanaly , Lars O. Nord , Jonas K. Jensen
Biogas plants are expected to play an important role in the future global energy system and hold a large potential for achieving negative CO2 emissions. In Denmark, CO2 separation is implemented in the majority of biogas plants. Therefore, their CO2 is readily available, only requiring the subsequent process steps conditioning, transportation, and storage to exploit the biogenic CO2 for net-negative emissions. However, biogas plants are relatively small point sources, which may result in high CCS deployment costs. Therefore, this study investigates how two biogas plants could economically benefit from sharing a common conditioning system. The technical performance of the processes are evaluated through process modelling and simulation, and a detailed economic analysis is used to evaluate the costs of the system. Four different options with different degrees of centralisation were considered. It was investigated for which emission levels and transport distances a centralised system shared between at least two biogas plants could be relevant. A shared conditioning system was found to yield economic benefits when two plants were located within 5 km to 10 km and when only the liquefaction and purification subprocesses were centralised. The results show that permanent storage of CO2 from biogas plants can be cost-competitive with other negative emission technologies. Furthermore, an average cost saving of 13 % can be achieved by relevant existing Danish plants when the CO2 conditioning process is shared between at least two biogas plants.
{"title":"When is a central CO2 conditioning system beneficial for CCS from biogas?: A techno-economic analysis of capacities and distances","authors":"Rikke C. Pedersen , Simon Roussanaly , Lars O. Nord , Jonas K. Jensen","doi":"10.1016/j.ijggc.2025.104563","DOIUrl":"10.1016/j.ijggc.2025.104563","url":null,"abstract":"<div><div>Biogas plants are expected to play an important role in the future global energy system and hold a large potential for achieving negative CO<sub>2</sub> emissions. In Denmark, CO<sub>2</sub> separation is implemented in the majority of biogas plants. Therefore, their CO<sub>2</sub> is readily available, only requiring the subsequent process steps conditioning, transportation, and storage to exploit the biogenic CO<sub>2</sub> for net-negative emissions. However, biogas plants are relatively small point sources, which may result in high CCS deployment costs. Therefore, this study investigates how two biogas plants could economically benefit from sharing a common conditioning system. The technical performance of the processes are evaluated through process modelling and simulation, and a detailed economic analysis is used to evaluate the costs of the system. Four different options with different degrees of centralisation were considered. It was investigated for which emission levels and transport distances a centralised system shared between at least two biogas plants could be relevant. A shared conditioning system was found to yield economic benefits when two plants were located within 5<!--> <!-->km to 10<!--> <!-->km and when only the liquefaction and purification subprocesses were centralised. The results show that permanent storage of CO<sub>2</sub> from biogas plants can be cost-competitive with other negative emission technologies. Furthermore, an average cost saving of 13<!--> <!-->% can be achieved by relevant existing Danish plants when the CO<sub>2</sub> conditioning process is shared between at least two biogas plants.</div></div>","PeriodicalId":334,"journal":{"name":"International Journal of Greenhouse Gas Control","volume":"149 ","pages":"Article 104563"},"PeriodicalIF":5.2,"publicationDate":"2025-12-20","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"145837174","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 : 2025-12-18DOI: 10.1016/j.ijggc.2025.104558
Martin Greco-Coppi , Nelly Eisenbach , Manuel-Daniel Kurkunc , Markus Sattler , Nils Roloff , Jochen Ströhle , Bernd Epple
Waste incineration and waste-to-energy (WtE) plants play a key role in waste management worldwide. To avoid the high amounts of CO2 emissions associated with waste incineration, cost-effective capture solutions are required. Nevertheless, most capture processes entail high economic penalties, making them unprofitable under current carbon taxes. In this work, we compare two concepts for capturing CO2 emissions using carbonate looping (also known as calcium looping, CaL) technology. One concept involves retrofitting the capture facility at the back end. The other is a novel integration concept that uses pretreated waste to fire the calciner, replacing one incineration line. The CaL concepts are analyzed for retrofitting a German WtE plant, which treats 200 kt of waste per year. We performed a techno-economic assessment that includes process modeling using the software Aspen Plus. The process simulations were supported using reactor models validated with pilot plant data. The calculated mass and energy balances were used to dimension components and calculate economic indicators, including a sensitivity analysis. We obtained CO2 avoidance costs (CAC) of ca. 140 €/tCO2,av for the tail-end concept, in agreement with previous studies. On the other hand, the integrated concept has CAC of 27 €/tCO2,av, including compression but excluding transport and storage, making it competitive with the current price of CO2 certificates in the European Union. To the best of our knowledge, this is the lowest value reported in the scientific literature for CO2 capture from waste incineration plants to date.
{"title":"Techno-economic assessment of carbonate looping for cost-effective CO2 capture in waste incineration","authors":"Martin Greco-Coppi , Nelly Eisenbach , Manuel-Daniel Kurkunc , Markus Sattler , Nils Roloff , Jochen Ströhle , Bernd Epple","doi":"10.1016/j.ijggc.2025.104558","DOIUrl":"10.1016/j.ijggc.2025.104558","url":null,"abstract":"<div><div>Waste incineration and waste-to-energy (WtE) plants play a key role in waste management worldwide. To avoid the high amounts of CO<sub>2</sub> emissions associated with waste incineration, cost-effective capture solutions are required. Nevertheless, most capture processes entail high economic penalties, making them unprofitable under current carbon taxes. In this work, we compare two concepts for capturing CO<sub>2</sub> emissions using carbonate looping (also known as <em>calcium looping</em>, CaL) technology. One concept involves retrofitting the capture facility at the back end. The other is a novel integration concept that uses pretreated waste to fire the calciner, replacing one incineration line. The CaL concepts are analyzed for retrofitting a German WtE plant, which treats 200 kt of waste per year. We performed a techno-economic assessment that includes process modeling using the software Aspen Plus. The process simulations were supported using reactor models validated with pilot plant data. The calculated mass and energy balances were used to dimension components and calculate economic indicators, including a sensitivity analysis. We obtained CO<sub>2</sub> avoidance costs (<em>CAC</em>) of ca. 140 €/t<sub>CO2,av</sub> for the tail-end concept, in agreement with previous studies. On the other hand, the integrated concept has <em>CAC</em> of 27 €/t<sub>CO2,av</sub>, including compression but excluding transport and storage, making it competitive with the current price of CO<sub>2</sub> certificates in the European Union. To the best of our knowledge, this is the lowest value reported in the scientific literature for CO<sub>2</sub> capture from waste incineration plants to date.</div></div>","PeriodicalId":334,"journal":{"name":"International Journal of Greenhouse Gas Control","volume":"149 ","pages":"Article 104558"},"PeriodicalIF":5.2,"publicationDate":"2025-12-18","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"145797794","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 : 2025-12-16DOI: 10.1016/j.ijggc.2025.104555
Wanting Hou , Olivia Collet , Li-Yun Fu , Roman Isaenkov , Roman Pevzner , Pavel Shashkin , Boris Gurevich
Permanent downhole seismic receivers such as Distributed Acoustic Sensors (DAS) offer a useful means for long-term seismic monitoring. Indeed, amplitudes of seismic waves recorded using downhole DAS are sensitive to changes of formation properties and can be used to monitor these changes. A recent analysis of downhole DAS data acquired during a CO2 injection into a 1500 m deep shows that DAS amplitudes and traveltimes of direct waves emitted by permanent seismic sources are controlled by temporal variations of formation properties caused by injected CO2. Comparison of the observed traveltimes and amplitudes against 1.5D simulations over the entire length of the well shows a reasonably good agreement for source offsets of up to 600 m. The time-lapse effects in the vicinity of the reservoir interval are also reproduced by the 1.5 modelling reasonably well, but this modelling cannot explain strong depth variations of traveltime shifts and amplitudes below the injection interval. The decrease in time shifts below the plume is reproduced in 2D finite-difference simulations, which shows that this decrease is caused by a finite lateral size of the plume. Matching the modelled traveltimes and amplitudes for a range of plume thicknesses to field observations gives an estimate of the plume thickness. Modelling the effect of injected supercritical CO2 close to the well for uniform and patchy saturation models confirms that the CO2 saturation is likely closer to uniform, and is above 10 %. Above this value, the sensitivity of both traveltimes and amplitudes is insufficient to obtain a more definitive estimate.
{"title":"Modelling temporal variations of direct-wave DAS traveltimes and amplitudes caused by CO2 injection","authors":"Wanting Hou , Olivia Collet , Li-Yun Fu , Roman Isaenkov , Roman Pevzner , Pavel Shashkin , Boris Gurevich","doi":"10.1016/j.ijggc.2025.104555","DOIUrl":"10.1016/j.ijggc.2025.104555","url":null,"abstract":"<div><div>Permanent downhole seismic receivers such as Distributed Acoustic Sensors (DAS) offer a useful means for long-term seismic monitoring. Indeed, amplitudes of seismic waves recorded using downhole DAS are sensitive to changes of formation properties and can be used to monitor these changes. A recent analysis of downhole DAS data acquired during a CO<sub>2</sub> injection into a 1500 m deep shows that DAS amplitudes and traveltimes of direct waves emitted by permanent seismic sources are controlled by temporal variations of formation properties caused by injected CO<sub>2</sub>. Comparison of the observed traveltimes and amplitudes against 1.5D simulations over the entire length of the well shows a reasonably good agreement for source offsets of up to 600 m. The time-lapse effects in the vicinity of the reservoir interval are also reproduced by the 1.5 modelling reasonably well, but this modelling cannot explain strong depth variations of traveltime shifts and amplitudes below the injection interval. The decrease in time shifts below the plume is reproduced in 2D finite-difference simulations, which shows that this decrease is caused by a finite lateral size of the plume. Matching the modelled traveltimes and amplitudes for a range of plume thicknesses to field observations gives an estimate of the plume thickness. Modelling the effect of injected supercritical CO<sub>2</sub> close to the well for uniform and patchy saturation models confirms that the CO<sub>2</sub> saturation is likely closer to uniform, and is above 10 %. Above this value, the sensitivity of both traveltimes and amplitudes is insufficient to obtain a more definitive estimate.</div></div>","PeriodicalId":334,"journal":{"name":"International Journal of Greenhouse Gas Control","volume":"149 ","pages":"Article 104555"},"PeriodicalIF":5.2,"publicationDate":"2025-12-16","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"145797861","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 : 2025-12-13DOI: 10.1016/j.ijggc.2025.104556
Maurizio Milano, Luigi Bianco, Maurizio Fedi
This study explores the use of 4D surface gravity data to monitor CO₂ stored in geological formations. We show that gravity method can provide useful and independent information for tracking CO₂ plume development and estimating stored mass, thereby supporting the safety assessment of carbon storage. Our objective is to delineate the plume spatial extent, evaluate its depth, and estimate net CO₂ mass changes over time. We focus on the Sleipner storage site, where 4D gravity surveys have been used to monitor CO₂ migration. We computed the time-lapse gravity field from multi-physics simulations based on the Utsira benchmark model and defined a workflow to process the data. We first performed the boundary analysis of the gravity field to evaluate its capability to resolve the plume shape within the limits in spatial resolution. Then we showed that, despite the plume complex geometry, the field behaves as a homogeneous field at large altitudes. This allowed the DEXP transformation of the field to yield an accurate depth and mass estimation of the stored CO2 also confirmed by constrained inverse modeling.
This workflow was then applied to the gravity dataset collected as part of the Sleipner monitoring program. Despite limitations in spatial coverage and data sampling, the inferred CO₂ mass and plume extent from the Sleipner gravity data are consistent with injected volumes and the seismic plume boundaries, supporting the robustness of gravity-based monitoring.
{"title":"What gravity monitoring may reveal about CO₂ storage: Insights from the Sleipner site (Norway)","authors":"Maurizio Milano, Luigi Bianco, Maurizio Fedi","doi":"10.1016/j.ijggc.2025.104556","DOIUrl":"10.1016/j.ijggc.2025.104556","url":null,"abstract":"<div><div>This study explores the use of 4D surface gravity data to monitor CO₂ stored in geological formations. We show that gravity method can provide useful and independent information for tracking CO₂ plume development and estimating stored mass, thereby supporting the safety assessment of carbon storage. Our objective is to delineate the plume spatial extent, evaluate its depth, and estimate net CO₂ mass changes over time. We focus on the Sleipner storage site, where 4D gravity surveys have been used to monitor CO₂ migration. We computed the time-lapse gravity field from multi-physics simulations based on the Utsira benchmark model and defined a workflow to process the data. We first performed the boundary analysis of the gravity field to evaluate its capability to resolve the plume shape within the limits in spatial resolution. Then we showed that, despite the plume complex geometry, the field behaves as a homogeneous field at large altitudes. This allowed the DEXP transformation of the field to yield an accurate depth and mass estimation of the stored CO<sub>2</sub> also confirmed by constrained inverse modeling.</div><div>This workflow was then applied to the gravity dataset collected as part of the Sleipner monitoring program. Despite limitations in spatial coverage and data sampling, the inferred CO₂ mass and plume extent from the Sleipner gravity data are consistent with injected volumes and the seismic plume boundaries, supporting the robustness of gravity-based monitoring.</div></div>","PeriodicalId":334,"journal":{"name":"International Journal of Greenhouse Gas Control","volume":"149 ","pages":"Article 104556"},"PeriodicalIF":5.2,"publicationDate":"2025-12-13","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"145797860","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 : 2025-12-11DOI: 10.1016/j.ijggc.2025.104542
Ahmed Ali Shanshool Alsubaih, Kamy Sepehrnoori, Mojdeh Delshad
The oil and gas industry is undergoing a transformative shift towards digital and smart fields, driven by the integration of artificial intelligence (AI), machine learning (ML), and real-time data analytics. Within this context, the novelty of this study lies in the development of an adaptive smart injection system for CO₂ sequestration that integrates real-time monitoring with advanced control strategies. Unlike conventional injection schemes that rely on pre-defined injection plans, the proposed framework dynamically adjusts injection parameters to optimize storage efficiency while mitigating leakage risks. A fully three-dimensional reservoir model with three injection wells and one legacy well is simulated over 5 years of injection followed by 50 years of storage, using a commercial reservoir simulator coupled to Python-based supervisory control. Three control strategies Proportional Integral Derivative (PID) control, Reinforcement Learning (RL), and Genetic Algorithm (GA) based optimization are compared under a conservative bottom-hole pressure limit tied to the fracture gradient. In an uncontrolled case, 10.2 % of the injected CO₂ leaks through the legacy well. The smart injection framework reduces this leakage to 2.8 % with PID, 2.0 % with GA, and 1.6 % with RL, corresponding to an 84 % reduction for RL relative to the baseline. RL provides the greatest average leakage reduction and most adaptive response to changing reservoir conditions, whereas GA offers slightly higher leakage but the most consistent performance across realizations; PID serves as a simple benchmark with limited adaptability. These results demonstrate that AI- and optimization-driven control can substantially enhance CO₂ storage security and operational efficiency, with direct transferability to waterflooding, enhanced oil recovery, and underground gas storage operations.
{"title":"A smart injection optimization for CO₂ sequestration: ensuring storage integrity through adaptive control and real-time monitoring","authors":"Ahmed Ali Shanshool Alsubaih, Kamy Sepehrnoori, Mojdeh Delshad","doi":"10.1016/j.ijggc.2025.104542","DOIUrl":"10.1016/j.ijggc.2025.104542","url":null,"abstract":"<div><div>The oil and gas industry is undergoing a transformative shift towards digital and smart fields, driven by the integration of artificial intelligence (AI), machine learning (ML), and real-time data analytics. Within this context, the novelty of this study lies in the development of an adaptive smart injection system for CO₂ sequestration that integrates real-time monitoring with advanced control strategies. Unlike conventional injection schemes that rely on pre-defined injection plans, the proposed framework dynamically adjusts injection parameters to optimize storage efficiency while mitigating leakage risks. A fully three-dimensional reservoir model with three injection wells and one legacy well is simulated over 5 years of injection followed by 50 years of storage, using a commercial reservoir simulator coupled to Python-based supervisory control. Three control strategies Proportional Integral Derivative (PID) control, Reinforcement Learning (RL), and Genetic Algorithm (GA) based optimization are compared under a conservative bottom-hole pressure limit tied to the fracture gradient. In an uncontrolled case, 10.2 % of the injected CO₂ leaks through the legacy well. The smart injection framework reduces this leakage to 2.8 % with PID, 2.0 % with GA, and 1.6 % with RL, corresponding to an 84 % reduction for RL relative to the baseline. RL provides the greatest average leakage reduction and most adaptive response to changing reservoir conditions, whereas GA offers slightly higher leakage but the most consistent performance across realizations; PID serves as a simple benchmark with limited adaptability. These results demonstrate that AI- and optimization-driven control can substantially enhance CO₂ storage security and operational efficiency, with direct transferability to waterflooding, enhanced oil recovery, and underground gas storage operations.</div></div>","PeriodicalId":334,"journal":{"name":"International Journal of Greenhouse Gas Control","volume":"149 ","pages":"Article 104542"},"PeriodicalIF":5.2,"publicationDate":"2025-12-11","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"145748579","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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