International Journal of Greenhouse Gas Control最新文献

{"title":"Differentiating legacy wellbores in the scottish north sea using multi-criteria decision analysis with a view to minimising containment risk for carbon capture and storage","authors":"Benjamin Pullen ,&nbsp;Aaron Cahill ,&nbsp;Daniel Arnold","doi":"10.1016/j.ijggc.2025.104336","DOIUrl":"10.1016/j.ijggc.2025.104336","url":null,"abstract":"<div><div>Carbon Capture and Storage (CCS) is a critical technology for mitigating climate change by securely storing CO₂ emissions underground. Former oil and gas fields are prime candidates for CCS due to their proven storage capacity, existing infrastructure, and favourable geology. However, legacy wells in these fields pose significant containment risks. Assessing these risks typically requires site-specific evaluations, which are time-intensive and impractical at scale, hindering systematic regional assessments, particularly in areas where CCS is expected to expand.</div><div>We developed a weight sum model (WSM) multi-criteria decision analysis (MCDA) approach to evaluate the containment risks of 12,264 legacy oil and gas wells in the North Sea. The model was informed by expert elicitation involving 54 global subject matter experts, 70 % of whom are industry professionals with over a decade of CCS experience. Wellbores were assigned consideration scores reflecting their containment risks based on geospatial, temporal, and engineering factors, weighted by expert consensus. The mean consideration score was 0.55 (range: 0–1), with outlier thresholds at 0.74 and 0.36, identifying 506 wells with significantly higher or lower risks to containment.</div><div>Among Scotland's nine most promising CO₂ storage sites, the Miller Oil Field and Captain Sandstone Fairway represent the highest and lowest cases of consideration score, respectively. By integrating expert knowledge into an MCDA framework, this approach provides a systematic method to prioritise wellbores for further evaluation based on risk profiles, supplementing traditional case-by-case assessments. It offers a scalable solution for managing containment risks across domains with multiple planned CCS projects.</div></div>","PeriodicalId":334,"journal":{"name":"International Journal of Greenhouse Gas Control","volume":"142 ","pages":"Article 104336"},"PeriodicalIF":4.6,"publicationDate":"2025-02-15","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"143420837","PeriodicalName":null,"FirstCategoryId":null,"ListUrlMain":null,"RegionNum":3,"RegionCategory":"工程技术","ArticlePicture":[],"TitleCN":null,"AbstractTextCN":null,"PMCID":"OA","EPubDate":null,"PubModel":null,"JCR":null,"JCRName":null,"Score":null,"Total":0}

{"title":"Experimental investigation of the interfacial debonding strength of class G cement and the implications to well integrity","authors":"Khizar Abid ,&nbsp;Felipe Baena ,&nbsp;Catalin Teodoriu ,&nbsp;Junghun Leem ,&nbsp;Latief Riyanto ,&nbsp;Yon Azwa Sazali ,&nbsp;Muhammad Syafeeq","doi":"10.1016/j.ijggc.2025.104334","DOIUrl":"10.1016/j.ijggc.2025.104334","url":null,"abstract":"<div><div>For the repurposing of plug and abandoned (P&amp;A) wells for the Carbon Capture and Sequestration (CCS) project, it is essential to know the condition of the well plugs. These plugs serve as a barrier that restricts the movement of unwanted fluids to the surface. Therefore, the integrity of the cement plug becomes essential. Thus, this study focuses on the interfacial debonding strength of the cement, which is a crucial parameter that must be quantified to find the integrity of the plug. The methodology used for this testing consisted of the novel apparatus established at the University of Oklahoma to find the debonding strength of the cement. The cement used for these experiments consisted of neat Class G mixed according to the API standard. The samples were cured for seven days in the pipe, which had a diameter of 2″ and a height of 6″. Different test variations were conducted, including thermal cyclic loading, transient, elevated, and room temperature tests. The samples were heated with the help of a thermal jacket, whereas the water for the hydraulic debonding test consisted of room and elevated temperature (95 °C). The experiments found that before the complete debonding of the cement plug, the leakage of water (wetting phase) on the sample surface was observed, which happened at a lower pressure than the interfacial debonding pressure. This wetting phase starts at a low pressure, i.e., around 500 psi, compared to debonding pressure, which mainly was above 1,000 psi. It was also noted that samples exposed to temperature testing (elevated temperature, transient, and cyclic loading) had lower interfacial debonding strength than those tested at room temperature. The final failure mode of these samples was due to the shear debonding, which was facilitated by the development of the microannuli in the testing samples, especially when the cement was exposed to temperature testing. Therefore, care should be taken, and proper calculations should be performed when using the P&amp;A wells that are exposed to high-temperature conditions for the CCS project.</div></div>","PeriodicalId":334,"journal":{"name":"International Journal of Greenhouse Gas Control","volume":"142 ","pages":"Article 104334"},"PeriodicalIF":4.6,"publicationDate":"2025-02-08","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"143369781","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}

{"title":"Geophysical characterization of the in-situ CO2 mineral storage pilot site in Helguvik, Iceland","authors":"Jonas Simon Junker ,&nbsp;Anne Obermann ,&nbsp;Martin Voigt ,&nbsp;Hansruedi Maurer ,&nbsp;Ovie Emmanuel Eruteya ,&nbsp;Andrea Moscariello ,&nbsp;Stefan Wiemer ,&nbsp;Alba Zappone","doi":"10.1016/j.ijggc.2025.104320","DOIUrl":"10.1016/j.ijggc.2025.104320","url":null,"abstract":"<div><div>In-situ CO₂ mineral storage is moving into focus as a technology for storing substantial amounts of CO₂ that would otherwise be released into the atmosphere. However, one of the main drawbacks of this technology is that it requires large amounts of freshwater for injection. To overcome this obstacle, a pilot project in Helguvik, Iceland is testing the effectiveness of carbon mineralization using saline water, similar to seawater. Here, we describe the project and the geophysical characterization of the pilot site using crosshole seismic- and single-hole electrical resistivity measurements. The data show that the subsurface strata are dominated by decameter-thick horizontal layers of basaltic strata, with varying seismic velocities and electrical resistivities. Variations in both seismic velocity and electrical resistivity are in excellent agreement and delineate high and low porosity zones in the subsurface. The results are compared to well logging results and the mineralogical composition of drill cuttings to build a comprehensive subsurface model of the future CO₂ mineral storage reservoir, highlighting potential pathways for the injected CO₂-charged waters.</div></div>","PeriodicalId":334,"journal":{"name":"International Journal of Greenhouse Gas Control","volume":"141 ","pages":"Article 104320"},"PeriodicalIF":4.6,"publicationDate":"2025-02-01","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"143095746","PeriodicalName":null,"FirstCategoryId":null,"ListUrlMain":null,"RegionNum":3,"RegionCategory":"工程技术","ArticlePicture":[],"TitleCN":null,"AbstractTextCN":null,"PMCID":"OA","EPubDate":null,"PubModel":null,"JCR":null,"JCRName":null,"Score":null,"Total":0}

{"title":"Microwave assisted in-situ gasification chemical looping combustion of coal using different oxygen carrier integrated with chemical production unit","authors":"Gaurav Sharma ,&nbsp;Roni Mallick ,&nbsp;Prabu Vairakannu","doi":"10.1016/j.ijggc.2025.104325","DOIUrl":"10.1016/j.ijggc.2025.104325","url":null,"abstract":"<div><div>Chemical looping combustion (CLC) is a promising technology for the clean and efficient production of energy without carbon emissions in the atmosphere. CLC uses two reactors, a fuel reactor and an air reactor, to combust fuel with the help of oxygen carriers (OC) such as NiO, Fe₂O₃, etc. <em>In-situ</em> gasification based CLC needs to be integrated with microwave for fast and energy efficient process. In the current study, the microwave assisted chemical looping combustion (MW-CLC) of coal is investigated using NiO, CuO and Fe₂O₃. Further, the MW-CLC process is simulated using Aspen Plus for dimethyl carbonate (DMC) production and a techno-economic analysis is performed to determine the feasibility of the process. The experimental results show the production of an average percentage of CO₂ of 97 vol.% for CuO, 92 vol.% for NiO and 91 vol.% for Fe₂O₃ during the MW-CLC. Further, the post MW-CLC residue analysis confirms the reduction of the OC to their respective metals i.e., Ni (79.9 wt.%), Cu (78.5 wt.%) and Fe (80.4 wt.%). The integration of the MW-CLC process ensures the production of 51.21 g/s of DMC and 142–215 kW of electricity from the proposed plants. This results in the maximum net energy efficiency of 46.47% and the lowest cost of electricity of 68.19 $/MWh for NiO as the OC. The cost of methanol and DMC production is found in between 0.62–0.89 $/kg and 0.95–1.38 $/kg, respectively.</div></div>","PeriodicalId":334,"journal":{"name":"International Journal of Greenhouse Gas Control","volume":"141 ","pages":"Article 104325"},"PeriodicalIF":4.6,"publicationDate":"2025-02-01","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"143095747","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}

{"title":"Towards industrial deployment of pressure tomography for CO2 storage monitoring: Uncertainty and megatonne scale-up","authors":"Samuel J. Jackson,&nbsp;James Gunning,&nbsp;Jonathan Ennis-King,&nbsp;Tess Dance,&nbsp;Charles Jenkins","doi":"10.1016/j.ijggc.2024.104299","DOIUrl":"10.1016/j.ijggc.2024.104299","url":null,"abstract":"<div><div>Pressure tomography was successfully demonstrated as a viable CO<span><math><msub><mrow></mrow><mrow><mn>2</mn></mrow></msub></math></span> storage monitoring technique in the Otway Stage 3 field project. In this work, we build on the initial pilot demonstration, using the results to assess megatonne-scale industrial deployment. Firstly, we develop an uncertainty analysis approach which facilitates risk-based decision making. We present a Bayesian model averaging approach which estimates statistical bounds on the estimated CO<span><math><msub><mrow></mrow><mrow><mn>2</mn></mrow></msub></math></span> plume footprints for each monitor survey, and delineates the increasing confidence in the plume locatability as more CO<span><math><msub><mrow></mrow><mrow><mn>2</mn></mrow></msub></math></span> is injected. To facilitate well-array design at other sites, we demonstrate the use of a gate system; a single well-pair to monitor encroaching CO<span><math><msub><mrow></mrow><mrow><mn>2</mn></mrow></msub></math></span>, which could be useful for key-risk areas such as spill-points or fault regions. Finally, non-dimensional analysis reveals the key control of the well separation, <span><math><mi>r</mi></math></span>, in operational design; the minimum water injection time scales with <span><math><msup><mrow><mi>r</mi></mrow><mrow><mn>2</mn></mrow></msup></math></span>, and peak-pressure scales with <span><math><mrow><mn>1</mn><mo>/</mo><msup><mrow><mi>r</mi></mrow><mrow><mn>2</mn></mrow></msup></mrow></math></span>. Realistic well separations <span><math><mo>&lt;</mo></math></span>2 km are found to be desirable, which is adequate to capture key migration pathways and risk areas in most megatonne-scale industrial operations.</div></div>","PeriodicalId":334,"journal":{"name":"International Journal of Greenhouse Gas Control","volume":"141 ","pages":"Article 104299"},"PeriodicalIF":4.6,"publicationDate":"2025-02-01","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"143095749","PeriodicalName":null,"FirstCategoryId":null,"ListUrlMain":null,"RegionNum":3,"RegionCategory":"工程技术","ArticlePicture":[],"TitleCN":null,"AbstractTextCN":null,"PMCID":"OA","EPubDate":null,"PubModel":null,"JCR":null,"JCRName":null,"Score":null,"Total":0}

{"title":"Assessment of CO2 sequestration potential and economics in Colorado, USA","authors":"Yanrui Ning ,&nbsp;Jeremy Boak ,&nbsp;Ali Tura ,&nbsp;Manika Prasad","doi":"10.1016/j.ijggc.2024.104301","DOIUrl":"10.1016/j.ijggc.2024.104301","url":null,"abstract":"<div><div>Carbon Capture, Utilization, and Sequestration (CCUS) is widely considered essential to mitigating anthropogenic climate change. This study, supported by the regional U.S. Department of Energy (DOE) initiative, Carbon Utilization and Storage Partnership (CUSP), evaluates the potential, progress, challenges, and economics of CCUS in Colorado, USA. We examine carbon capture, transportation, and storage potential in oil and gas reservoirs, saline aquifers, and CO₂-enhanced oil recovery (EOR) operations. Additionally, we conduct an economic analysis and discuss the leakage risks posed by legacy wells, which may impact the safety and security of CO₂ storage. It was found that the nine facilities with the greatest CO₂ emissions in Colorado overlie the Denver-Julesburg (DJ) Basin, and half of these are in the Wattenberg field. The DJ Basin, especially the Wattenberg field, is the top-ranked carbon storage target in Colorado for this reason, as well as because: 1) low-permeability formations (Niobrara and Codell) can be used for enhanced oil recovery, and 2) stacked saline aquifers, such as the Dakota, Entrada, Fountain, Lyons, and Morrison Formations, have a high capacity for carbon storage. Through a refined analysis of the efficiency factor, our study provides more accurate assessments of storage capacity, demonstrating that saline aquifers possess significantly higher carbon storage capacities than oil and gas reservoirs. In the Wattenberg field, simulation studies demonstrate that approximately 18 % of injected CO₂ can be stored over a four-year CO₂-EOR process. Additionally, CO₂-EOR reduces overall CO₂ emissions per barrel of oil by 76 % compared to conventional production methods. Economic analysis indicates that CO₂-EOR is an effective approach to offset the high costs associated with CCUS.</div></div>","PeriodicalId":334,"journal":{"name":"International Journal of Greenhouse Gas Control","volume":"141 ","pages":"Article 104301"},"PeriodicalIF":4.6,"publicationDate":"2025-02-01","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"143095762","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}

{"title":"Volumetric carbon storage capacity estimation at Mississippi Canyon Block 118 in the Gulf of Mexico using Post-Stack Seismic Inversion","authors":"Silas Adeoluwa Samuel,&nbsp;Camelia C. Knapp,&nbsp;James H. Knapp","doi":"10.1016/j.ijggc.2025.104319","DOIUrl":"10.1016/j.ijggc.2025.104319","url":null,"abstract":"<div><div>The world's population is estimated to be 10 billion by 2050 and as a result, energy demand would increase exponentially. Additionally, global carbon emissions due to our surpassing need for energy to generate power for transportation and industrial activities would increase significantly. Despite significant technological advances, global warming due to greenhouse gas emissions from anthropogenic activities continues to have a deleterious effect on the climate. Geologic carbon storage provides a sustainable solution for limiting the adverse environmental footprints of anthropogenic activities, as well as for enhanced oil recovery and providing raw materials for industrial products. The high storage potential of depleted hydrocarbon reservoirs and saline aquifers can provide an abode for captured greenhouse gases like carbon dioxide. This research focuses on delineating potential geologic sites for carbon storage at the Mississippi Canyon block 118 (MC-118) field on the northern slope of the Gulf of Mexico. This site is located on a passive margin that is significantly influenced by salt tectonics and slope failure. Furthermore, salt tectonics controls the basin's geometric architecture resulting in complex faulting and sediment-salt interplays. Hence, MC-118 proves to be a challenging terrain to characterize reservoirs for carbon storage. Likewise, estimating the storage capacity of each prospective carbon storage site is of utmost importance. Rock physics modeling and petrophysical characterization involving post-stack seismic inversion are employed in estimating reservoir properties such as lithology and porosity. Acoustic impedance, a seismic attribute useful in delineating lithology, was extracted from post-stack seismic inversion modeling. By integrating geophysical characterization and post-stack seismic inversion, suitable sites with ample carbon storage capacity could be delineated and these workflows can be applied at other locations.</div></div>","PeriodicalId":334,"journal":{"name":"International Journal of Greenhouse Gas Control","volume":"141 ","pages":"Article 104319"},"PeriodicalIF":4.6,"publicationDate":"2025-02-01","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"143095889","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}

{"title":"An experimental study of the mineral carbonation potential of the Jizan Group basalts","authors":"Abdirizak Omar ,&nbsp;Mouadh Addassi ,&nbsp;Davide Berno ,&nbsp;Abdulwahab Alqahtani ,&nbsp;Niccolo Menegoni ,&nbsp;Serguey Arkadakskiy ,&nbsp;Jakub Fedorik ,&nbsp;Zeyad Ahmed ,&nbsp;Noushad Kunnummal ,&nbsp;Sigurdur R. Gislason ,&nbsp;Thomas Finkbeiner ,&nbsp;Abdulkader Afifi ,&nbsp;Hussein Hoteit ,&nbsp;Eric H. Oelkers","doi":"10.1016/j.ijggc.2025.104323","DOIUrl":"10.1016/j.ijggc.2025.104323","url":null,"abstract":"<div><div>The ability of Jizan basalts, a potential subsurface mineral carbon storage formation located in southwest Saudi Arabia, to carbonate water-dissolved CO₂ has been examined through a set of closed system batch fluid-rock experiments performed at 60 °C. Two Jizan basalt samples were collected from a CO₂ injection pilot test well at depths of 375 and 665 m below surface. The basalt samples are dominated by intermediate plagioclase (An<span><math><mrow><mo>∼</mo><mn>60</mn></mrow></math></span>) and a Ca-Mg pyroxene with minor chlorite and zeolite. The cleaned basalts were placed into individual sealed reactors along with either aqueous sodium carbonate or sodium bicarbonate solutions, and the experiments were conducted over a period of up to 250 days. The reactive fluid compositions in all experiments suggest that the dissolution of plagioclase dominates the basalt dissolution; calculations suggest that the fluids rapidly approach pyroxene equilibrium. The reactive fluids rapidly become saturated with respect to calcite. SEM imaging and EDS analysis confirm calcite growth on the basalt grains. In contrast, Al-bearing secondary minerals were not identified despite apparently being retained by the solid phases during the experiments. Notably, the dissolution rates of the Jizan basalts slowed considerably over time during the static batch experiments. This observation suggests that the relatively rapid dissolution of basalt by acidic CO₂-rich fluids in a dynamic flow system creating a dissolution zone and precipitation zone, is essential for efficient in situ mineralization of CO₂ in basalts.</div></div>","PeriodicalId":334,"journal":{"name":"International Journal of Greenhouse Gas Control","volume":"141 ","pages":"Article 104323"},"PeriodicalIF":4.6,"publicationDate":"2025-02-01","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"143095891","PeriodicalName":null,"FirstCategoryId":null,"ListUrlMain":null,"RegionNum":3,"RegionCategory":"工程技术","ArticlePicture":[],"TitleCN":null,"AbstractTextCN":null,"PMCID":"OA","EPubDate":null,"PubModel":null,"JCR":null,"JCRName":null,"Score":null,"Total":0}

{"title":"Evaluating the regional geological characteristics of the St. Peter Sandstone and Everton Formation for CO2 storage in Southern Illinois: A case study on site-specific injection feasibility in Washington County, Illinois","authors":"Mansour Khosravi,&nbsp;Zohreh Askari,&nbsp;Roland T. Okwen,&nbsp;Kendall Taft","doi":"10.1016/j.ijggc.2024.104292","DOIUrl":"10.1016/j.ijggc.2024.104292","url":null,"abstract":"<div><div>This study provides a detailed investigation of CO₂ storage potential in the St. Peter Sandstone and Everton Formation in Southern Illinois, employing a comprehensive, multidisciplinary approach that integrates geological and petrophysical analysis, seismic evaluations, and reservoir modeling. The objective of this study is to thoroughly characterize the geological and petrophysical attributes of these formations, emphasizing the lithology, thickness, and spatial distribution of porosity and permeability. A regional geocellular model was developed to identify specific areas within the St. Peter Sandstone and Everton Formation with significant CO₂ storage potential. The parameters used to identify these areas include average thickness, porosity, permeability, and brine salinity. The evaluation of the petrophysical logs and core intervals indicate that the St. Peter Sandstone is predominantly characterized by its fine to medium, well-sorted pure quartz sandstone composition, which is notably devoid of clay minerals. Furthermore, the Everton Formation exists locally in southwestern and southern Illinois and has two distinct intervals: the upper dolomite and the lower fine to medium grained, well-sorted quartz sandstone intervals. The Everton sandstone interval in southwest Illinois has reservoir properties similar to the St. Peter Sandstone. Regional variation in porosity and permeability is evident, with high porosity values in the west-central region of Illinois diminishing gradually towards the southern parts of the state. A portion of the regional geocellular model was used as input to dynamic reservoir simulation of CO₂ injection via the Lively Grove 1 well in Washington County, Illinois. A 30-year injection phase and a 50-year post-injection phase were simulated. Dynamic reservoir simulations were performed to assess the long-term viability of securely storing CO₂ within the St. Peter Sandstone and Everton Formation. Preliminary simulation results indicate that over two million metric tonnes of CO₂ can be securely injected annually into the St. Peter Sandstone and Everton Formation via a single well, thereby underscoring the practical implications of the study's findings for effective CO₂ management. Significantly, the study identifies the west-central part of Illinois as a highly suitable location for CO₂ storage within these formations. This insight is instrumental for developing targeted CO₂ storage strategies in the Illinois Basin, contributing to broader carbon mitigation efforts worldwide. The research emphasizes the role of geological storage in lowering atmospheric CO₂ concentrations, marking a critical step forward in combating climate change. Moreover, it highlights the indispensable role of the St. Peter Sandstone and Everton Formation in advancing carbon storage techniques.</div></div>","PeriodicalId":334,"journal":{"name":"International Journal of Greenhouse Gas Control","volume":"141 ","pages":"Article 104292"},"PeriodicalIF":4.6,"publicationDate":"2025-02-01","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"143095158","PeriodicalName":null,"FirstCategoryId":null,"ListUrlMain":null,"RegionNum":3,"RegionCategory":"工程技术","ArticlePicture":[],"TitleCN":null,"AbstractTextCN":null,"PMCID":"OA","EPubDate":null,"PubModel":null,"JCR":null,"JCRName":null,"Score":null,"Total":0}

{"title":"Biomass and coal cofiring gasification with pre-combustion carbon capture: Impact of mixed feedstocks on CO2 absorption using a physical solvent","authors":"Kathryn H. Smith ,&nbsp;Joshua J. Stanislowski ,&nbsp;Michael L. Swanson ,&nbsp;Nicholas S. Siefert","doi":"10.1016/j.ijggc.2024.104300","DOIUrl":"10.1016/j.ijggc.2024.104300","url":null,"abstract":"<div><div>Advances in co-gasification of coal and biomass are resulting in more interest in poly-generation facilities that can produce hydrogen rich syngas for producing chemicals, fuels and energy, with much lower carbon emissions. When biomass is blended with hydrocarbon feedstocks like coal (biomass cofiring) and when the carbon dioxide (CO₂) produced during the gasification process is captured using pre-combustion CO₂ capture technologies, it is possible to emit less CO₂ into the atmosphere than it took to grow the biomass material, resulting in net negative or low CO₂ emissions.</div><div>Here, we present the first carbon capture pilot plant data for CO₂ removal from coal and biomass derived syngas using physical solvent absorption. The physical solvent (DEPG at 35.0 L·<em>h</em>⁻¹ and 10.5 °C) was tested in a packed absorption column under pre-combustion CO₂ capture conditions using the biomass derived syngas mixtures (3.54 MPa at 3.4 std. m³·<em>h</em>⁻¹ and 53.1 °C) to assess any changes in the absorption process resulting from co-gasification. Overall, the CO₂ absorption performance of the solvent did not appear to be impacted by the varying feedstock compositions as indicated by average CO₂ removal efficiency of 97.3 % with a standard deviation of 1.6 % across all trials. Despite minor accumulation of organic gas species in the solvent and gas streams exiting the absorber, there did not appear to be any strong correlations between CO₂ capture performance and coal type or biomass type or mixture concentration. These results indicate traditional physical solvent absorption processes can be used with minimal impact from novel gasification feedstock mixtures including coal, wood and corn stover mixtures, but longer term testing is recommended to fully assess the impact of accumulating inorganic and organic species from biomass feedstock.</div></div>","PeriodicalId":334,"journal":{"name":"International Journal of Greenhouse Gas Control","volume":"141 ","pages":"Article 104300"},"PeriodicalIF":4.6,"publicationDate":"2025-02-01","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"143095679","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}