Pub Date : 2025-02-01DOI: 10.1016/j.ijggc.2025.104318
Jose Eduardo Ubillus , Sahar Bakhshian , Hailun Ni , David DiCarlo , Tip Meckel
Small-scale heterogeneities can significantly affect the fate of the plume and trapping during COmigration. We conducted geologic carbon storage field-scale simulations to investigate the impact of small-scale heterogeneities on plume dynamics and trapping performance. Small-scale heterogeneities have been shown to increase the amount of trapped COduring buoyancy-driven flow. The trapped saturation is validated by previous sandbox experimental work during buoyancy-driven flow in realistic heterogeneous domains and is implemented through the critical COsaturation parameter (i.e., the first non-zero value in the drainage COrelative permeability curve). Depending on the type and degree of heterogeneity, various critical COsaturation values are exhibited. Furthermore, we investigated the effect of small-scale heterogeneties when multiple capillary pressure models are employed. This study demonstrates that an increase in critical COsaturation reduces the COplume size and lateral extent, accompanying an increase in residual trapping and a decrease in solubility trapping. Finally, we show that independent of the capillary pressure model used, an increase in critical saturation leads to similar COplume dynamics distribution and trapping performance. These results emphasize the importance of quantifying the effect of small-scale heterogeneity as they affect the large-scale behavior of the COplume.
{"title":"Informing field-scale CO2storage simulations with sandbox experiments: The effect of small-scale heterogeneities","authors":"Jose Eduardo Ubillus , Sahar Bakhshian , Hailun Ni , David DiCarlo , Tip Meckel","doi":"10.1016/j.ijggc.2025.104318","DOIUrl":"10.1016/j.ijggc.2025.104318","url":null,"abstract":"<div><div>Small-scale heterogeneities can significantly affect the fate of the <span><math><mrow><mi>C</mi><msub><mrow><mi>O</mi></mrow><mrow><mn>2</mn></mrow></msub></mrow></math></span> plume and trapping during CO<span><math><mrow><msub><mrow></mrow><mrow><mn>2</mn></mrow></msub><mspace></mspace></mrow></math></span>migration. We conducted geologic carbon storage field-scale simulations to investigate the impact of small-scale heterogeneities on plume dynamics and trapping performance. Small-scale heterogeneities have been shown to increase the amount of trapped CO<span><math><mrow><msub><mrow></mrow><mrow><mn>2</mn></mrow></msub><mspace></mspace></mrow></math></span>during buoyancy-driven flow. The trapped <span><math><mrow><mi>C</mi><msub><mrow><mi>O</mi></mrow><mrow><mn>2</mn></mrow></msub></mrow></math></span> saturation is validated by previous sandbox experimental work during buoyancy-driven flow in realistic heterogeneous domains and is implemented through the critical CO<span><math><mrow><msub><mrow></mrow><mrow><mn>2</mn></mrow></msub><mspace></mspace></mrow></math></span>saturation parameter (i.e., the first non-zero value in the drainage CO<span><math><mrow><msub><mrow></mrow><mrow><mn>2</mn></mrow></msub><mspace></mspace></mrow></math></span>relative permeability curve). Depending on the type and degree of heterogeneity, various critical CO<span><math><mrow><msub><mrow></mrow><mrow><mn>2</mn></mrow></msub><mspace></mspace></mrow></math></span>saturation values are exhibited. Furthermore, we investigated the effect of small-scale heterogeneties when multiple capillary pressure models are employed. This study demonstrates that an increase in critical CO<span><math><mrow><msub><mrow></mrow><mrow><mn>2</mn></mrow></msub><mspace></mspace></mrow></math></span>saturation reduces the CO<span><math><mrow><msub><mrow></mrow><mrow><mn>2</mn></mrow></msub><mspace></mspace></mrow></math></span>plume size and lateral extent, accompanying an increase in residual trapping and a decrease in solubility trapping. Finally, we show that independent of the capillary pressure model used, an increase in critical saturation leads to similar CO<span><math><mrow><msub><mrow></mrow><mrow><mn>2</mn></mrow></msub><mspace></mspace></mrow></math></span>plume dynamics distribution and trapping performance. These results emphasize the importance of quantifying the effect of small-scale heterogeneity as they affect the large-scale behavior of the CO<span><math><mrow><msub><mrow></mrow><mrow><mn>2</mn></mrow></msub><mspace></mspace></mrow></math></span>plume.</div></div>","PeriodicalId":334,"journal":{"name":"International Journal of Greenhouse Gas Control","volume":"141 ","pages":"Article 104318"},"PeriodicalIF":4.6,"publicationDate":"2025-02-01","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"143095890","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 : 2025-02-01DOI: 10.1016/j.ijggc.2025.104309
Ebbe Hauge Jensen , Rikke Cilius Pedersen , Isaac Appelquist Løge , Gcinisizwe Msimisi Dlamini , Randi Neerup , Christian Riber , Brian Elmegaard , Jonas Kjær Jensen , Philip Loldrup Fosbøl
CO2 capture, utilization, and storage is a key technology to mitigate the climate crisis, and the development of a CO2 infrastructure is critical for its future large-scale implementation. Successful deployment of a CO2 infrastructure depends largely on the compatibility between industry links, which is currently limited by unaligned CO2 purity specifications. Therefore, there is a need to understand the economic and technical implications of purity specifications throughout the whole value chain. This work presents, a highly detailed study encompassing the entire CO2 conditioning system, including compression, dehydration, liquefaction, and purification. A single, common CO2 conditioning system derived from operational facilities and designed for post-combustion CO2 feeds was applied for conditioning of four different feed gases. The investigation includes a techno-economic analysis considering capital and operational expenses for twelve different combinations of CO2 feed streams and outlet product specifications. The feed sources represent a range of CO2 purities from high purity to low purity and were derived from post-combustion, pre-combustion, and oxy-fuel combustion processes, while the considered product specifications include CO2 storage in depleted gas fields, saline aquifer, and utilization in the food industr. For the investigated systems, it is found that low-purity CO2 was the most expensive source gas to condition to commercial specifications due to a high content of non-condensable gases. The levelized costs for CO2 conditioning amounted to approximately 25 EUR/t CO2, 27 EUR/t CO2, 34 EUR/t CO2, and 46 EUR/t CO2 for the investigated high purity, medium-high purity, medium-low purity, and low purity CO2 cases, respectively. In the investigated cases, only the specifications of low-volatile species were relevant. The impurity limit specifications were relatively close across the investigated commercial specifications, therefore, these did not show significant cost differences. The study clarifies the economic impact on the CO2 conditioning process from imposing equivalent purity constraints on CO2 from different sources.
{"title":"The cost of impurities: A techno-economic assessment on conditioning of captured CO2 to commercial specifications","authors":"Ebbe Hauge Jensen , Rikke Cilius Pedersen , Isaac Appelquist Løge , Gcinisizwe Msimisi Dlamini , Randi Neerup , Christian Riber , Brian Elmegaard , Jonas Kjær Jensen , Philip Loldrup Fosbøl","doi":"10.1016/j.ijggc.2025.104309","DOIUrl":"10.1016/j.ijggc.2025.104309","url":null,"abstract":"<div><div>CO<sub>2</sub> capture, utilization, and storage is a key technology to mitigate the climate crisis, and the development of a CO<sub>2</sub> infrastructure is critical for its future large-scale implementation. Successful deployment of a CO<sub>2</sub> infrastructure depends largely on the compatibility between industry links, which is currently limited by unaligned CO<sub>2</sub> purity specifications. Therefore, there is a need to understand the economic and technical implications of purity specifications throughout the whole value chain. This work presents, a highly detailed study encompassing the entire CO<sub>2</sub> conditioning system, including compression, dehydration, liquefaction, and purification. A single, common CO<sub>2</sub> conditioning system derived from operational facilities and designed for post-combustion CO<sub>2</sub> feeds was applied for conditioning of four different feed gases. The investigation includes a techno-economic analysis considering capital and operational expenses for twelve different combinations of CO<sub>2</sub> feed streams and outlet product specifications. The feed sources represent a range of CO<sub>2</sub> purities from high purity to low purity and were derived from post-combustion, pre-combustion, and oxy-fuel combustion processes, while the considered product specifications include CO<sub>2</sub> storage in depleted gas fields, saline aquifer, and utilization in the food industr. For the investigated systems, it is found that low-purity CO<sub>2</sub> was the most expensive source gas to condition to commercial specifications due to a high content of non-condensable gases. The levelized costs for CO<sub>2</sub> conditioning amounted to approximately 25 EUR/t CO<sub>2</sub>, 27 EUR/t CO<sub>2</sub>, 34 EUR/t CO<sub>2</sub>, and 46 EUR/t CO<sub>2</sub> for the investigated high purity, medium-high purity, medium-low purity, and low purity CO<sub>2</sub> cases, respectively. In the investigated cases, only the specifications of low-volatile species were relevant. The impurity limit specifications were relatively close across the investigated commercial specifications, therefore, these did not show significant cost differences. The study clarifies the economic impact on the CO<sub>2</sub> conditioning process from imposing equivalent purity constraints on CO<sub>2</sub> from different sources.</div></div>","PeriodicalId":334,"journal":{"name":"International Journal of Greenhouse Gas Control","volume":"141 ","pages":"Article 104309"},"PeriodicalIF":4.6,"publicationDate":"2025-02-01","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"143095745","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}
Pub Date : 2025-02-01DOI: 10.1016/j.ijggc.2025.104314
Sascha Serno , Gareth Johnson , Adrian J. Boyce , Stuart M.V. Gilfillan
Residual trapping is a critical component of secure geological CO2 storage. Quantification of the amount of CO2 residually trapped plays a key role in predicting CO2 plume migration, immobilisation and storage security. However, it is difficult to determine pore-space saturation of CO2 within a subsurface reservoir. δ18O of CO2 and reservoir fluids from a variety of field-scale CO2 injection settings have provided estimates of in-situ CO2 reservoir saturations. This is due to O isotope exchange between CO2 and H2O and subsequent changes in δ18OH2O values due to the presence of free phase CO2. Here, we present results from laboratory experiments to measure the O isotope equilibration time at ambient conditions and O isotope behaviour in both CO2 and water during fluid cycling in a closed system. This provides an analogue of O isotopic exchange within a single-well push-pull injection and production scenario and is primarily motivated to help understand varying estimates of the amount of residual trapping obtained from O isotope measurements during the Otway 2Bext single well push-pull test. We find that full O isotope equilibration between CO2 and water is established after 72 hours and water δ18O does not change after 48 hours. The maximum change in δ18O of water of 1.16 % during the back-production phase of our fluid cycling experiment using waters enriched in δ18O would be negligible in field-scale projects, when unenriched water and CO2 sources are used, considering standard analytical uncertainties. However, our results show that changes in δ18O values of CO2 during a back-production scenario may be larger than 3.52 %, hence it may be inaccurate to solely use O isotope composition of CO2 to quantify CO2 pore-space saturation in a single-well push-pull configuration.
{"title":"Constraining O isotope equilibrium exchange between CO2 and water during fluid cycling in a closed system","authors":"Sascha Serno , Gareth Johnson , Adrian J. Boyce , Stuart M.V. Gilfillan","doi":"10.1016/j.ijggc.2025.104314","DOIUrl":"10.1016/j.ijggc.2025.104314","url":null,"abstract":"<div><div>Residual trapping is a critical component of secure geological CO<sub>2</sub> storage. Quantification of the amount of CO<sub>2</sub> residually trapped plays a key role in predicting CO<sub>2</sub> plume migration, immobilisation and storage security. However, it is difficult to determine pore-space saturation of CO<sub>2</sub> within a subsurface reservoir. δ<sup>18</sup>O of CO<sub>2</sub> and reservoir fluids from a variety of field-scale CO<sub>2</sub> injection settings have provided estimates of in-situ CO<sub>2</sub> reservoir saturations. This is due to O isotope exchange between CO<sub>2</sub> and H<sub>2</sub>O and subsequent changes in δ<sup>18</sup>O<sub>H2O</sub> values due to the presence of free phase CO<sub>2</sub>. Here, we present results from laboratory experiments to measure the O isotope equilibration time at ambient conditions and O isotope behaviour in both CO<sub>2</sub> and water during fluid cycling in a closed system. This provides an analogue of O isotopic exchange within a single-well push-pull injection and production scenario and is primarily motivated to help understand varying estimates of the amount of residual trapping obtained from O isotope measurements during the Otway 2Bext single well push-pull test. We find that full O isotope equilibration between CO<sub>2</sub> and water is established after 72 hours and water δ<sup>18</sup>O does not change after 48 hours. The maximum change in δ<sup>18</sup>O of water of 1.16 % during the back-production phase of our fluid cycling experiment using waters enriched in δ<sup>18</sup>O would be negligible in field-scale projects, when unenriched water and CO<sub>2</sub> sources are used, considering standard analytical uncertainties. However, our results show that changes in δ<sup>18</sup>O values of CO<sub>2</sub> during a back-production scenario may be larger than 3.52 %, hence it may be inaccurate to solely use O isotope composition of CO<sub>2</sub> to quantify CO<sub>2</sub> pore-space saturation in a single-well push-pull configuration.</div></div>","PeriodicalId":334,"journal":{"name":"International Journal of Greenhouse Gas Control","volume":"141 ","pages":"Article 104314"},"PeriodicalIF":4.6,"publicationDate":"2025-02-01","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"143095756","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}
Pub Date : 2025-01-29DOI: 10.1016/j.ijggc.2025.104321
Wenxin Xiang , Shuxun Sang , Sijie Han , Shiqi Liu , Xiaozhi Zhou , Dexi Wang
As a responsible major country, China is leading the world in carbon emissions while actively promoting carbon reduction and emission reduction efforts. CO2 geological sequestration is one of the key direct emission reduction technologies. The North Jiangsu-South Yellow Sea Basin, a significant sedimentary basin in eastern China, holds substantial potential for CO2 geological sequestration. The suitability assessment of CO2 geological sequestration is the basis for the deployment of CO2 sequestration projects, and the key is how to scientifically and effectively select the deployment sites. This study focuses on the Subei-South Yellow Sea Basin, constructing an index system consisting of 3 criterion levels and 14 indicator levels. The AHP-Critic combined method was used for indicator weighting, and a multi-level fuzzy comprehensive evaluation method was applied to assess the CO2 geological sequestration suitability of 13 depression units in the basin. Haian and Qintong Depressions were identified as suitable regions for CO2 geological sequestration in the North Jiangsu-South Yellow Sea Basin, with Baiju, Yancheng, and Gaoyou Depressions categorized as secondary suitable areas. The assessment results offer scientific support for site selection and engineering of CO2 geological sequestration in the North Jiangsu-South Yellow Sea Basin.
{"title":"Assessment of CO2 geological sequestration potential in the Northern Jiangsu-Southern yellow Sea Basin via AHP-CRITIC methodology","authors":"Wenxin Xiang , Shuxun Sang , Sijie Han , Shiqi Liu , Xiaozhi Zhou , Dexi Wang","doi":"10.1016/j.ijggc.2025.104321","DOIUrl":"10.1016/j.ijggc.2025.104321","url":null,"abstract":"<div><div>As a responsible major country, China is leading the world in carbon emissions while actively promoting carbon reduction and emission reduction efforts. CO<sub>2</sub> geological sequestration is one of the key direct emission reduction technologies. The North Jiangsu-South Yellow Sea Basin, a significant sedimentary basin in eastern China, holds substantial potential for CO<sub>2</sub> geological sequestration. The suitability assessment of CO<sub>2</sub> geological sequestration is the basis for the deployment of CO<sub>2</sub> sequestration projects, and the key is how to scientifically and effectively select the deployment sites. This study focuses on the Subei-South Yellow Sea Basin, constructing an index system consisting of 3 criterion levels and 14 indicator levels. The AHP-Critic combined method was used for indicator weighting, and a multi-level fuzzy comprehensive evaluation method was applied to assess the CO<sub>2</sub> geological sequestration suitability of 13 depression units in the basin. Haian and Qintong Depressions were identified as suitable regions for CO<sub>2</sub> geological sequestration in the North Jiangsu-South Yellow Sea Basin, with Baiju, Yancheng, and Gaoyou Depressions categorized as secondary suitable areas. The assessment results offer scientific support for site selection and engineering of CO<sub>2</sub> geological sequestration in the North Jiangsu-South Yellow Sea Basin.</div></div>","PeriodicalId":334,"journal":{"name":"International Journal of Greenhouse Gas Control","volume":"142 ","pages":"Article 104321"},"PeriodicalIF":4.6,"publicationDate":"2025-01-29","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"143165007","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 : 2025-01-01DOI: 10.1016/j.ijggc.2024.104295
Mark White , Alex Rinehart , Peter Rose , Michael Mella , Richard Esser , William Ampomah
A series of six aqueous-soluble and four nonaqueous-soluble tracer experiments and corresponding numerical simulations were executed for the Farnsworth Field in Ochiltree County, Texas, USA, a field which is undergoing tertiary enhanced oil recovery with water-alternating-gas (WAG) production. The combination of field experiments and numerical simulations was designed to identify flow pathways between injectors and producers and potential short circuiting of injected fluids. Field recoveries of aqueous-soluble tracers were dependent on the WAG stages of the tracer injection well, with shorter arrival times for strictly waterflooding and delayed arrival times for alternating injection stages. Aqueous-soluble tracer (i.e., 1,3,6-naphthalene trisulfonate, 1,5-naphthalene disulfonate, 1,6-naphthalene disulfonate, 2-naphthalene sulfonate, 2,6-naphthalene disulfonate, and 2,7-naphthalene disulfonate) arrivals for WAG injectors indicated water bypass was occurring during gas injection stages. Nonaqueous-soluble tracer (i.e., perfluoro-1,2-dimethylcyclohexane, perfluoroethylcyclohexane, perfluoromethylcyclohexane, and perfluoromethylcyclopentane) experiments revealed faster migration velocities than for the aqueous-soluble tracers and flow heterogeneities that resulted in the tracers bypassing nearer production wells. Base-case numerical simulations of the tracer experiments used a geologic model of the Morrow B sandstone production interval with parameters calibrated from history matching simulations, with the Morrow B sandstone sub-divided into hydrologic flow units (HFUs). Alternative simulation scenarios investigated HFU-dependent three-phase relative permeability models and dynamic intrinsic permeability enhancement with exposure to aqueous-dissolved CO2. Compositional petroleum models with four components were shown to be sufficient for tracer modeling compared against a nine-component model, with a factor of four difference in simulation execution time. HFU-dependent relative permeability models and dynamic intrinsic permeability modifications influenced arrival times and production concentrations of both aqueous- and nonaqueous-soluble tracers but did not yield unique flow pathways compared to those observed in the base-case scenario.
{"title":"Modeling approaches for addressing enigmatic migration patterns for aqueous- and nonaqueous-soluble tracers in an enhanced oil recovery field","authors":"Mark White , Alex Rinehart , Peter Rose , Michael Mella , Richard Esser , William Ampomah","doi":"10.1016/j.ijggc.2024.104295","DOIUrl":"10.1016/j.ijggc.2024.104295","url":null,"abstract":"<div><div>A series of six aqueous-soluble and four nonaqueous-soluble tracer experiments and corresponding numerical simulations were executed for the Farnsworth Field in Ochiltree County, Texas, USA, a field which is undergoing tertiary enhanced oil recovery with water-alternating-gas (WAG) production. The combination of field experiments and numerical simulations was designed to identify flow pathways between injectors and producers and potential short circuiting of injected fluids. Field recoveries of aqueous-soluble tracers were dependent on the WAG stages of the tracer injection well, with shorter arrival times for strictly waterflooding and delayed arrival times for alternating injection stages. Aqueous-soluble tracer (i.e., 1,3,6-naphthalene trisulfonate, 1,5-naphthalene disulfonate, 1,6-naphthalene disulfonate, 2-naphthalene sulfonate, 2,6-naphthalene disulfonate, and 2,7-naphthalene disulfonate) arrivals for WAG injectors indicated water bypass was occurring during gas injection stages. Nonaqueous-soluble tracer (i.e., perfluoro-1,2-dimethylcyclohexane, perfluoroethylcyclohexane, perfluoromethylcyclohexane, and perfluoromethylcyclopentane) experiments revealed faster migration velocities than for the aqueous-soluble tracers and flow heterogeneities that resulted in the tracers bypassing nearer production wells. Base-case numerical simulations of the tracer experiments used a geologic model of the Morrow B sandstone production interval with parameters calibrated from history matching simulations, with the Morrow B sandstone sub-divided into hydrologic flow units (HFUs). Alternative simulation scenarios investigated HFU-dependent three-phase relative permeability models and dynamic intrinsic permeability enhancement with exposure to aqueous-dissolved CO<sub>2</sub>. Compositional petroleum models with four components were shown to be sufficient for tracer modeling compared against a nine-component model, with a factor of four difference in simulation execution time. HFU-dependent relative permeability models and dynamic intrinsic permeability modifications influenced arrival times and production concentrations of both aqueous- and nonaqueous-soluble tracers but did not yield unique flow pathways compared to those observed in the base-case scenario.</div></div>","PeriodicalId":334,"journal":{"name":"International Journal of Greenhouse Gas Control","volume":"140 ","pages":"Article 104295"},"PeriodicalIF":4.6,"publicationDate":"2025-01-01","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"143157910","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 : 2024-11-30DOI: 10.1016/j.ijggc.2024.104284
Shruti K. Mishra , Miles A. Henderson , David Jiawei Tu , Alexander Erwin , Robert C. Trentham , Dietrich H. Earnhart , Jean-Lucien Fonquergne , Hannah Gagarin , Jason E Heath
Carbon capture, utilization, and storage (CCUS) is an important pathway for meeting climate mitigation goals. While the economic viability of CCUS is well understood, previous studies do not evaluate the economic feasibility of carbon capture and storage (CCS) in the Permian Basin specifically regarding the new Section 45Q tax credits. We developed a technoeconomic analysis method, evaluated the economic feasibility of CCS at the acid gas injection (AGI) wells, and assessed the implication of Section 45Q tax credits for CCS at the AGIs. We find that the compressors, well depth, and the permit and monitoring costs drive the facility costs. Compressors are the predominant contributors to capital and operating expenditure driving the levelized cost of CO2 storage. Strategic cost reduction measures identified include 1) sourcing of low-cost electricity and 2) optimizing operational efficiency in well operations. In evaluating the impact of the tax credits on CCS projects, facility scale proved decisive. We found that facilities with an annual injection rate exceeding 10,000 MT storage capacity demonstrate economic viability contingent upon the procurement of inputs at the least cost. The new construction of AGI wells were found to be economically viable at a storage capacity of 100,000 MT. The basin is heavily focused on CCUS (tax credit – $65/MT CO2), which overshadows CCS ($85/MT CO2) opportunities. Balancing the dual objectives of CCS and CCUS requires planning and coordination for optimal resource and pore space utilization to attain the basin's decarbonization potential. We also found that CCS on AGI is a lower cost CCS option as compared to CCS on other industries.
{"title":"Can section 45Q tax credit foster decarbonization? A case study of geologic carbon storage at Acid Gas Injection wells in the Permian Basin","authors":"Shruti K. Mishra , Miles A. Henderson , David Jiawei Tu , Alexander Erwin , Robert C. Trentham , Dietrich H. Earnhart , Jean-Lucien Fonquergne , Hannah Gagarin , Jason E Heath","doi":"10.1016/j.ijggc.2024.104284","DOIUrl":"10.1016/j.ijggc.2024.104284","url":null,"abstract":"<div><div>Carbon capture, utilization, and storage (CCUS) is an important pathway for meeting climate mitigation goals. While the economic viability of CCUS is well understood, previous studies do not evaluate the economic feasibility of carbon capture and storage (CCS) in the Permian Basin specifically regarding the new Section 45Q tax credits. We developed a technoeconomic analysis method, evaluated the economic feasibility of CCS at the acid gas injection (AGI) wells, and assessed the implication of Section 45Q tax credits for CCS at the AGIs. We find that the compressors, well depth, and the permit and monitoring costs drive the facility costs. Compressors are the predominant contributors to capital and operating expenditure driving the levelized cost of CO<sub>2</sub> storage. Strategic cost reduction measures identified include 1) sourcing of low-cost electricity and 2) optimizing operational efficiency in well operations. In evaluating the impact of the tax credits on CCS projects, facility scale proved decisive. We found that facilities with an annual injection rate exceeding 10,000 MT storage capacity demonstrate economic viability contingent upon the procurement of inputs at the least cost. The new construction of AGI wells were found to be economically viable at a storage capacity of 100,000 MT. The basin is heavily focused on CCUS (tax credit – $65/MT CO<sub>2</sub>), which overshadows CCS ($85/MT CO<sub>2</sub>) opportunities. Balancing the dual objectives of CCS and CCUS requires planning and coordination for optimal resource and pore space utilization to attain the basin's decarbonization potential. We also found that CCS on AGI is a lower cost CCS option as compared to CCS on other industries.</div></div>","PeriodicalId":334,"journal":{"name":"International Journal of Greenhouse Gas Control","volume":"140 ","pages":"Article 104284"},"PeriodicalIF":4.6,"publicationDate":"2024-11-30","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"142746281","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}
Pub Date : 2024-11-29DOI: 10.1016/j.ijggc.2024.104282
Ilayda Akkor , Shachit S. Iyer , John Dowdle , Le Wang , Chrysanthos E. Gounaris
Given the urgent need to mitigate increasing CO emissions and alleviate the climate crisis, amine-based post-combustion capture (PCC) processes have emerged as a prominent method to reduce the emissions from industrial point sources. While many technological advancements have been introduced for such processes, leading to decreased energy requirements for capture, there are still only a few commercial installations because of their high costs. Therefore, these processes can benefit from process optimization to enhance their economic viability. This work presents a new open-source, rate-based, equation-oriented model of a novel PCC process that uses piperazine as the amine solvent. The model was implemented in Python, in accordance with the Pyomo-based IDAES modeling and optimization framework. The proposed nonlinear model can be used for both simulation and optimization. To ensure its robust convergence, we further devise a rigorous, multi-level cascade initialization scheme, whose principles can further be applied towards the initialization of similar process models. The model was validated with published pilot plant data and then optimized for pilot and commercial scales with an economic objective that considers both capital and operational costs. Results show that process optimization can indeed improve the economics of this technology, leading to 15.6% yearly savings at the pilot scale compared to the baseline case considered in the study. Additional parametric analyses were performed to understand how the flue gas flowrate and CO concentration, as well as the target capture rate, affects the cost of capture.
{"title":"Mathematical modeling and economic optimization of a piperazine-based post-combustion carbon capture process","authors":"Ilayda Akkor , Shachit S. Iyer , John Dowdle , Le Wang , Chrysanthos E. Gounaris","doi":"10.1016/j.ijggc.2024.104282","DOIUrl":"10.1016/j.ijggc.2024.104282","url":null,"abstract":"<div><div>Given the urgent need to mitigate increasing CO<span><math><msub><mrow></mrow><mrow><mn>2</mn></mrow></msub></math></span> emissions and alleviate the climate crisis, amine-based post-combustion capture (PCC) processes have emerged as a prominent method to reduce the emissions from industrial point sources. While many technological advancements have been introduced for such processes, leading to decreased energy requirements for capture, there are still only a few commercial installations because of their high costs. Therefore, these processes can benefit from process optimization to enhance their economic viability. This work presents a new open-source, rate-based, equation-oriented model of a novel PCC process that uses piperazine as the amine solvent. The model was implemented in Python, in accordance with the Pyomo-based <em>IDAES</em> modeling and optimization framework. The proposed nonlinear model can be used for both simulation and optimization. To ensure its robust convergence, we further devise a rigorous, multi-level cascade initialization scheme, whose principles can further be applied towards the initialization of similar process models. The model was validated with published pilot plant data and then optimized for pilot and commercial scales with an economic objective that considers both capital and operational costs. Results show that process optimization can indeed improve the economics of this technology, leading to 15.6% yearly savings at the pilot scale compared to the baseline case considered in the study. Additional parametric analyses were performed to understand how the flue gas flowrate and CO<span><math><msub><mrow></mrow><mrow><mn>2</mn></mrow></msub></math></span> concentration, as well as the target capture rate, affects the cost of capture.</div></div>","PeriodicalId":334,"journal":{"name":"International Journal of Greenhouse Gas Control","volume":"140 ","pages":"Article 104282"},"PeriodicalIF":4.6,"publicationDate":"2024-11-29","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"142746280","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 : 2024-11-21DOI: 10.1016/j.ijggc.2024.104268
Sally Homsy , Tommy Schmitt , Sarah Leptinsky , Hari Mantripragada , Alexander Zoelle , Timothy Fout , Travis Shultz , Ronald Munson , Dan Hancu , Nagamani Gavvalapalli , Jeffrey Hoffmann , Gregory Hackett
Recent United States Department of Energy (DOE) sponsored front-end engineering design (FEED) studies for retrofitting existing fossil-fueled power plants with state-of-the-art carbon capture technology contain previously overlooked real-world design considerations for near-term deployment of carbon capture. Insights from examining seven recently published FEED study reports are summarized in this paper. This includes a discussion of the design, performance, and cost implications associated with (1) location-specific considerations such as water availability, land availability, and accessibility; (2) host-plant-specific factors such as flue gas specifications, allowable degree of integration between the capture system and host plant, and operational mode; and (3) miscellaneous factors such as market conditions, permitting requirements, and business case incentives. This manuscript highlights (1) water availability as a key design and cost driver, with host plant steam extraction increasing capture system cooling water availability, (2) modularization and constructability impacts on the number of capture trains, (3) the impacts of host plant operational mode and capacity factor on the business case for installing capture, and (4) the merit of continued research, development, and demonstration efforts addressing steam extraction, host plant tie-in at the stack, solvent reclamation and air emissions control.
{"title":"Insights from FEED studies for retrofitting existing fossil power plants with carbon capture technology","authors":"Sally Homsy , Tommy Schmitt , Sarah Leptinsky , Hari Mantripragada , Alexander Zoelle , Timothy Fout , Travis Shultz , Ronald Munson , Dan Hancu , Nagamani Gavvalapalli , Jeffrey Hoffmann , Gregory Hackett","doi":"10.1016/j.ijggc.2024.104268","DOIUrl":"10.1016/j.ijggc.2024.104268","url":null,"abstract":"<div><div>Recent United States Department of Energy (DOE) sponsored front-end engineering design (FEED) studies for retrofitting existing fossil-fueled power plants with state-of-the-art carbon capture technology contain previously overlooked real-world design considerations for near-term deployment of carbon capture. Insights from examining seven recently published FEED study reports are summarized in this paper. This includes a discussion of the design, performance, and cost implications associated with (1) location-specific considerations such as water availability, land availability, and accessibility; (2) host-plant-specific factors such as flue gas specifications, allowable degree of integration between the capture system and host plant, and operational mode; and (3) miscellaneous factors such as market conditions, permitting requirements, and business case incentives. This manuscript highlights (1) water availability as a key design and cost driver, with host plant steam extraction increasing capture system cooling water availability, (2) modularization and constructability impacts on the number of capture trains, (3) the impacts of host plant operational mode and capacity factor on the business case for installing capture, and (4) the merit of continued research, development, and demonstration efforts addressing steam extraction, host plant tie-in at the stack, solvent reclamation and air emissions control.</div></div>","PeriodicalId":334,"journal":{"name":"International Journal of Greenhouse Gas Control","volume":"140 ","pages":"Article 104268"},"PeriodicalIF":4.6,"publicationDate":"2024-11-21","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"142698352","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 reports the cradle-to-wheel life cycle greenhouse gas (GHG) emissions resulting from enhanced oil recovery (EOR) using CO2 sourced from direct air capture (DAC). A Monte Carlo simulation model representing variability in technology, location, and supply chain is used to model the possible range of carbon intensities (CI) of oil produced through DAC-EOR. Crude oil produced through DAC-EOR is expected to have a CI of 449 tCO2/mbbl. With 95% confidence, the CI is between 345 tCO2/mbbl to 553 tCO2/mbbl. Producing net-zero GHG emission oil through DAC-EOR is thus highly improbable. An example case of DAC-EOR in the U.S. Permian Basin shows that only in the unlikely instance of the most storage efficient sites using 100% renewable energy does DAC-EOR result in “carbon-negative” oil production.
{"title":"Putting the genie back in the bottle: Decarbonizing petroleum with direct air capture and enhanced oil recovery","authors":"Jayant Singh , Udayan Singh , Gonzalo Rodriguez Garcia , Vikram Vishal , Robert Anex","doi":"10.1016/j.ijggc.2024.104281","DOIUrl":"10.1016/j.ijggc.2024.104281","url":null,"abstract":"<div><div>This study reports the cradle-to-wheel life cycle greenhouse gas (GHG) emissions resulting from enhanced oil recovery (EOR) using CO<sub>2</sub> sourced from direct air capture (DAC). A Monte Carlo simulation model representing variability in technology, location, and supply chain is used to model the possible range of carbon intensities (CI) of oil produced through DAC-EOR. Crude oil produced through DAC-EOR is expected to have a CI of 449 tCO<sub>2</sub>/mbbl. With 95% confidence, the CI is between 345 tCO<sub>2</sub>/mbbl to 553 tCO<sub>2</sub>/mbbl. Producing net-zero GHG emission oil through DAC-EOR is thus highly improbable. An example case of DAC-EOR in the U.S. Permian Basin shows that only in the unlikely instance of the most storage efficient sites using 100% renewable energy does DAC-EOR result in “carbon-negative” oil production.</div></div>","PeriodicalId":334,"journal":{"name":"International Journal of Greenhouse Gas Control","volume":"139 ","pages":"Article 104281"},"PeriodicalIF":4.6,"publicationDate":"2024-11-14","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"142660318","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 : 2024-11-06DOI: 10.1016/j.ijggc.2024.104279
Markus Secomandi , Markku Nikku , Borja Arias , Jouni Ritvanen
Calcium looping (CaL), typically capable of reducing CO2 emissions by approximately 90%, is a technology well suited to capturing CO2 emissions from a wide array of industrial processes. An approach in which Ca(OH)2 is injected into the carbonator to increase the carbon capture efficiency of the CaL process to 99% was evaluated in this study using a one-and-a-half-dimensional reactor model. The effect of several key parameters was considered, including the injection flow rate, injection elevation, and the formation rate of CO2 in the freeboard of the carbonator due to the combustion of char particles elutriated from the calciner. The main finding was that capture rates of 99% appear attainable, given that enough Ca(OH)2 is injected and that the injection occurs at a suitable location, i.e., the sorbent is allowed sufficient residence time in the reactor.
{"title":"A conceptual evaluation of the use of Ca(OH)2 for attaining carbon capture rates of 99% in the calcium looping process","authors":"Markus Secomandi , Markku Nikku , Borja Arias , Jouni Ritvanen","doi":"10.1016/j.ijggc.2024.104279","DOIUrl":"10.1016/j.ijggc.2024.104279","url":null,"abstract":"<div><div>Calcium looping (CaL), typically capable of reducing CO<sub>2</sub> emissions by approximately 90%, is a technology well suited to capturing CO<sub>2</sub> emissions from a wide array of industrial processes. An approach in which Ca(OH)<sub>2</sub> is injected into the carbonator to increase the carbon capture efficiency of the CaL process to 99% was evaluated in this study using a one-and-a-half-dimensional reactor model. The effect of several key parameters was considered, including the injection flow rate, injection elevation, and the formation rate of CO<sub>2</sub> in the freeboard of the carbonator due to the combustion of char particles elutriated from the calciner. The main finding was that capture rates of 99% appear attainable, given that enough Ca(OH)<sub>2</sub> is injected and that the injection occurs at a suitable location, i.e., the sorbent is allowed sufficient residence time in the reactor.</div></div>","PeriodicalId":334,"journal":{"name":"International Journal of Greenhouse Gas Control","volume":"139 ","pages":"Article 104279"},"PeriodicalIF":4.6,"publicationDate":"2024-11-06","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"142592839","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}
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