TECHNICAL PROGRAMME | Energy Infrastructure – Future Pathways
CCS Hub Facilities
Forum 9 | Hall 10 - Technical Programme 2
13
October
14:00
15:30
UTC+3
As industry and governments pursue the technology of carbon capture and storage to reduce the emission of CO2 into the atmosphere, a growing number of nations and jurisdictions are establishing CCS hubs to support industrial scale deployment of these technologies. These hubs are specific geographic regions with the geological, technological, and regulatory regimes in-place to support the capture and storage of anthropogenic carbon emissions. The purpose of this session is to present case-studies, highlight challenges and opportunities, and identify pathways to accelerate CCS activities worldwide.
Carbon Capture and Storage (CCS) is an important decarbonisation technology that plays a major role in meeting Greenhouse Gas (GHG) reduction targets in the oil and gas industry. QatarEnergy LNG has implemented the first CCS project of its kind in Qatar by converting its acid gas injection system, operational since 2005, into a dedicated CO₂ injection facility in 2019 with a design injection capacity of 2.2 million tonnes per annum (MTPA). This abstract presents the journey, results, and learnings from this landmark environmental project representing one of the largest and most impactful carbon mitigation efforts in the region. The CO₂ utilised by QatarEnergy LNG’s CCS facility is separated from natural gas as part of LNG production. It is then compressed and transported to a deep geological formation for injection and permanent storage. The facility is integrated within QatarEnergy LNG’s gas processing infrastructure, and as of the end of 2024, it has successfully sequestered approximately 7.5 MTPA of CO₂ with the equivalent environmental impact of powering 260,000 homes or removing 120,000 gasoline-powered vehicles from the road on an annual basis. The CCS project has delivered strong technical performance across key injection parameters, including stable pressure, high injectivity index, and no containment breaches over a multi-year period. Data from 2019 to 2024 illustrates a consistent and safe CO₂ storage profile, verified by pressure sensors and subsurface modeling. Key lessons emerged from the project included early-stage integration of stakeholders across engineering, operations, and environmental domains, robust monitoring technologies and subsurface analysis and alignment with Qatar’s National Vision 2030 elevated the strategic significance of the project beyond emissions abatement. In conclusion, QatarEnergy LNG’s CO2 injection facility serves as a benchmark for successful CCS implementation in the region. Its evolution from an acid gas injection system to a dedicated CO2 storage facility exemplifies effective adaptation to emerging environmental imperatives. The insights garnered from this case study aim to inform and guide decarbonisation initiatives within the energy sector while providing a model for LNG operators worldwide to embed CCS at scale using existing infrastructure to ensure measurable and verifiable GHG reductions.
Carbon Capture and Storage (CCS) is a pivotal technology for mitigating greenhouse gas emissions and achieving global climate goals. The process entails capturing carbon dioxide (CO₂) from industrial and energy sources, transporting it in compressed form, and permanently storing it in deep geological formations to prevent atmospheric re-release. Secure geological storage is critical to the long-term efficacy of CCS, relying on multiple trapping mechanisms, structural, residual, solubility, and mineral, to ensure containment and minimize leakage risks. Suitable formations, including deep saline aquifers, depleted hydrocarbon reservoirs, unmineable coal seams, and basalts with natural mineralization potential, provide robust storage options due to their capacity and stability.
A comprehensive CCS initiative is underway to develop a scalable portfolio of CO₂ storage sites, aligning with national emissions reduction targets, and fostering regional CCS hubs in Saudi Arabia. This initiative employs a phased, multidisciplinary approach that integrates geoscience, engineering, and strategic planning to identify, evaluate, and manage high-potential storage locations. The methodology prioritizes technical rigor, geographic diversity, and cost-effectiveness, ensuring both environmental and economic viability.
The initiative commenced with regional geological screening, leveraging extensive geological surveys, petroleum basin data, and academic research to identify promising basins. A stringent set of exclusion criteria eliminated unsuitable areas, focusing on formations with optimal storage attributes, such as deep saline aquifers and depleted reservoirs, and basalts with natural mineralization potential. Candidate basins were further evaluated based on proximity to major CO₂ emission sources and the feasibility of pipeline infrastructure, optimizing transport costs and operational efficiency. This screening process yielded a prioritized set of high-potential basins strategically positioned to support large-scale CCS deployment.
Selected basins are undergoing rigorous site-specific assessments through an integrated CO₂ evaluation framework. This includes advanced geophysical, geological, petrophysical, and geomechanical studies to characterize subsurface properties, followed by static and dynamic reservoir modeling to estimate storage capacity, injectivity, seal integrity, and potential leakage risks. An uncertainty and risk assessment framework quantifies variables, enabling the calculation of risk-adjusted storage capacities and facilitating the ranking of sites within each basin. Surface-level considerations, such as existing infrastructure, alignment with emission source locations, and strategic importance are incorporated to ensure pragmatic site selection.
Preliminary results indicate significant storage potential across identified basins, with several sites demonstrating high injectivity and robust sealing mechanisms. The approach ensures scalability by designing sites to accommodate future expansion of CCS operations. By integrating cutting-edge geoscience with practical infrastructure planning, this initiative establishes a technically sound and strategically aligned CCS portfolio. Saudi Arabia’s leadership in CCS deployment advances national climate goals and positions the initiative as a global pioneer in CCS, contributing substantially to international efforts to combat climate change.
A comprehensive CCS initiative is underway to develop a scalable portfolio of CO₂ storage sites, aligning with national emissions reduction targets, and fostering regional CCS hubs in Saudi Arabia. This initiative employs a phased, multidisciplinary approach that integrates geoscience, engineering, and strategic planning to identify, evaluate, and manage high-potential storage locations. The methodology prioritizes technical rigor, geographic diversity, and cost-effectiveness, ensuring both environmental and economic viability.
The initiative commenced with regional geological screening, leveraging extensive geological surveys, petroleum basin data, and academic research to identify promising basins. A stringent set of exclusion criteria eliminated unsuitable areas, focusing on formations with optimal storage attributes, such as deep saline aquifers and depleted reservoirs, and basalts with natural mineralization potential. Candidate basins were further evaluated based on proximity to major CO₂ emission sources and the feasibility of pipeline infrastructure, optimizing transport costs and operational efficiency. This screening process yielded a prioritized set of high-potential basins strategically positioned to support large-scale CCS deployment.
Selected basins are undergoing rigorous site-specific assessments through an integrated CO₂ evaluation framework. This includes advanced geophysical, geological, petrophysical, and geomechanical studies to characterize subsurface properties, followed by static and dynamic reservoir modeling to estimate storage capacity, injectivity, seal integrity, and potential leakage risks. An uncertainty and risk assessment framework quantifies variables, enabling the calculation of risk-adjusted storage capacities and facilitating the ranking of sites within each basin. Surface-level considerations, such as existing infrastructure, alignment with emission source locations, and strategic importance are incorporated to ensure pragmatic site selection.
Preliminary results indicate significant storage potential across identified basins, with several sites demonstrating high injectivity and robust sealing mechanisms. The approach ensures scalability by designing sites to accommodate future expansion of CCS operations. By integrating cutting-edge geoscience with practical infrastructure planning, this initiative establishes a technically sound and strategically aligned CCS portfolio. Saudi Arabia’s leadership in CCS deployment advances national climate goals and positions the initiative as a global pioneer in CCS, contributing substantially to international efforts to combat climate change.
CO2 injection into reservoirs for enhanced oil recovery and sequestration is the most efficiency way to realize the carbon neutrality goal. Various types of reservoirs could be the targets for CO2 sequestration but which one should be the best choice is still unclear, especially for the huge reserves of heavy oil reservoirs and low permeability reservoirs. The sealing property of cap rock, displacement efficiency of CO2 flooding and CO2 dissolution ability in the oil jointly determined the CO2 sequestration potential.
This work compared the CO2 sequestration potential between heavy oil reservoirs and low permeability light oil reservoirs via a series of experiments and numerical simulations. The breakthrough pressure of CO2 in the caprock, the CO2 dissolution amount in heavy oil and light oil and oil displacement effective by CO2 flooding were investigated to evaluate CO2 sequestration capability via dissolution and capillary trapping in two types reservoirs. Moreover, the numerical simulation of CO2 flooding in a heavy oil reservoir and low permeability reservoir were performed based on the above experimental data to quantitatively clarify the CO2 sequestration potential.
The breakthrough pressure of the mudstone caprock of the heavy oil reservoir was 35 times higher than that of the silty mudstone caprock of the low permeability reservoir, which indicated the CO2 sequestration pressure in the low permeability reservoir was higher than that in the heavy oi reservoir. The solubility of CO2 in the heavy oil was 2 times lower than that in the light oil. The CO2 sequestration amount per unit pore volume was slightly higher in the heavy oil reservoir than that in the light oil reservoir under a certain temperature and pressure condition, and it increased while temperature increased due to the incremental displacement efficiency of heavy oil. The proportion of CO2 sequestration by capillary trapping in low permeability cores could reach 87% while the CO2 sequestration by dissolution in the heavy oil reservoir was nearly 30%. Numerical simulation found that in the real reservoir conduction, the CO2 sequestration amount per unit pore volume of low permeability light oil reservoir was 1.5 times than that of the heavy oil reservoir because the low permeability reservoir possessed a larger reservoir pressure and higher CO2 displacement efficiency.
Our work found compare to the heavy oil reservoir, the low permeability light oil reservoir presented a larger CO2 sequestration potential. The CO2 flooding could significantly enhance the heavy oil recovery, especially in coordination with the temperature increment. We expect this work could point out the application direction for the CO2 enhanced oil recovery and sequestration.
This work compared the CO2 sequestration potential between heavy oil reservoirs and low permeability light oil reservoirs via a series of experiments and numerical simulations. The breakthrough pressure of CO2 in the caprock, the CO2 dissolution amount in heavy oil and light oil and oil displacement effective by CO2 flooding were investigated to evaluate CO2 sequestration capability via dissolution and capillary trapping in two types reservoirs. Moreover, the numerical simulation of CO2 flooding in a heavy oil reservoir and low permeability reservoir were performed based on the above experimental data to quantitatively clarify the CO2 sequestration potential.
The breakthrough pressure of the mudstone caprock of the heavy oil reservoir was 35 times higher than that of the silty mudstone caprock of the low permeability reservoir, which indicated the CO2 sequestration pressure in the low permeability reservoir was higher than that in the heavy oi reservoir. The solubility of CO2 in the heavy oil was 2 times lower than that in the light oil. The CO2 sequestration amount per unit pore volume was slightly higher in the heavy oil reservoir than that in the light oil reservoir under a certain temperature and pressure condition, and it increased while temperature increased due to the incremental displacement efficiency of heavy oil. The proportion of CO2 sequestration by capillary trapping in low permeability cores could reach 87% while the CO2 sequestration by dissolution in the heavy oil reservoir was nearly 30%. Numerical simulation found that in the real reservoir conduction, the CO2 sequestration amount per unit pore volume of low permeability light oil reservoir was 1.5 times than that of the heavy oil reservoir because the low permeability reservoir possessed a larger reservoir pressure and higher CO2 displacement efficiency.
Our work found compare to the heavy oil reservoir, the low permeability light oil reservoir presented a larger CO2 sequestration potential. The CO2 flooding could significantly enhance the heavy oil recovery, especially in coordination with the temperature increment. We expect this work could point out the application direction for the CO2 enhanced oil recovery and sequestration.
Iran, with the fourth largest proven oil reserves in the world, faces two major challenges: decreasing oil production in the mature fields and increasing pressure to reduce carbon emissions in the energy sector. One proposed solution is to combine enhanced oil recovery (EOR) with carbon capture and storage (CCS) by injecting CO₂ into depleted or partially depleted reservoirs. This study examines the technical and geological feasibility of establishing CCS hubs in Iran, according to actual data from domestic reservoirs.
This analysis examines several oil reservoirs in the southern and southwestern of Iran, including the Maroon, Ahvaz, and Aghajari fields. According to data from the National Iranian Oil Company (NIOC), these fields have an estimated CO2 storage capacity of more than 4.3 billion tons. For example, the Aghajari field alone has the potential to store about 730 million tons of CO₂, which is equivalent to decades of injection under a standard EOR program. Injection at pressures of 1100 up to 1500 psi can provide miscibility in these formations and increase oil recovery by up to 12%.
This study uses seismic and petrophysical data to investigate formation integrity, properties of caprock sealing, and regional fault systems. Also, the separation of carbon dioxide from produced oil—a major operational bottleneck—has been investigated, according to existing gas separation and recovery units. The deployment of these infrastructures reduces the new investment costs and make the integrated CCS hubs more economically viable.
Although Iran currently does not have an official mechanism for carbon pricing, the feasibility study of this plan has been done using global carbon credit prices between $30 and $100 per ton. The results show that the break-even point of the project is achieved in less than 10 years under optimal recovery conditions. Having the dual benefit of increasing oil recovery and permanent CO₂ storage, this plan is aligned with Iran's strategic goals to increase the life of reservoirs and reduce carbon emissions.
Several CO₂-EOR projects have been done in Iran, mainly focusing on enhancing oil recovery and reducing greenhouse gas emissions. A pilot project at the Ramin oil field utilized CO₂ captured from the Ramin Power Plant, aiming to increase oil recovery by 16–80%. Also, feasibility studies by Alborz Energy examined over 40 reservoirs for CO₂ injection, leading to the design of necessary capture and injection infrastructure. Additional evaluations estimated that each ton of injected CO₂ could yield 2–8 additional barrels of oil.
This paper suggests that CCS hubs based on CO2-EOR in Iran are technically and geologically feasible. With appropriate regulatory frameworks and investment in monitoring and verification, these hubs could form the backbone of Iran’s long-term carbon management infrastructure.
This analysis examines several oil reservoirs in the southern and southwestern of Iran, including the Maroon, Ahvaz, and Aghajari fields. According to data from the National Iranian Oil Company (NIOC), these fields have an estimated CO2 storage capacity of more than 4.3 billion tons. For example, the Aghajari field alone has the potential to store about 730 million tons of CO₂, which is equivalent to decades of injection under a standard EOR program. Injection at pressures of 1100 up to 1500 psi can provide miscibility in these formations and increase oil recovery by up to 12%.
This study uses seismic and petrophysical data to investigate formation integrity, properties of caprock sealing, and regional fault systems. Also, the separation of carbon dioxide from produced oil—a major operational bottleneck—has been investigated, according to existing gas separation and recovery units. The deployment of these infrastructures reduces the new investment costs and make the integrated CCS hubs more economically viable.
Although Iran currently does not have an official mechanism for carbon pricing, the feasibility study of this plan has been done using global carbon credit prices between $30 and $100 per ton. The results show that the break-even point of the project is achieved in less than 10 years under optimal recovery conditions. Having the dual benefit of increasing oil recovery and permanent CO₂ storage, this plan is aligned with Iran's strategic goals to increase the life of reservoirs and reduce carbon emissions.
Several CO₂-EOR projects have been done in Iran, mainly focusing on enhancing oil recovery and reducing greenhouse gas emissions. A pilot project at the Ramin oil field utilized CO₂ captured from the Ramin Power Plant, aiming to increase oil recovery by 16–80%. Also, feasibility studies by Alborz Energy examined over 40 reservoirs for CO₂ injection, leading to the design of necessary capture and injection infrastructure. Additional evaluations estimated that each ton of injected CO₂ could yield 2–8 additional barrels of oil.
This paper suggests that CCS hubs based on CO2-EOR in Iran are technically and geologically feasible. With appropriate regulatory frameworks and investment in monitoring and verification, these hubs could form the backbone of Iran’s long-term carbon management infrastructure.
Carbon Capture and Storage (CCS) is an important decarbonisation technology that plays a major role in meeting Greenhouse Gas (GHG) reduction targets in the oil and gas industry. QatarEnergy LNG has implemented the first CCS project of its kind in Qatar by converting its acid gas injection system, operational since 2005, into a dedicated CO₂ injection facility in 2019 with a design injection capacity of 2.2 million tonnes per annum (MTPA). This abstract presents the journey, results, and learnings from this landmark environmental project representing one of the largest and most impactful carbon mitigation efforts in the region. The CO₂ utilised by QatarEnergy LNG’s CCS facility is separated from natural gas as part of LNG production. It is then compressed and transported to a deep geological formation for injection and permanent storage. The facility is integrated within QatarEnergy LNG’s gas processing infrastructure, and as of the end of 2024, it has successfully sequestered approximately 7.5 MTPA of CO₂ with the equivalent environmental impact of powering 260,000 homes or removing 120,000 gasoline-powered vehicles from the road on an annual basis. The CCS project has delivered strong technical performance across key injection parameters, including stable pressure, high injectivity index, and no containment breaches over a multi-year period. Data from 2019 to 2024 illustrates a consistent and safe CO₂ storage profile, verified by pressure sensors and subsurface modeling. Key lessons emerged from the project included early-stage integration of stakeholders across engineering, operations, and environmental domains, robust monitoring technologies and subsurface analysis and alignment with Qatar’s National Vision 2030 elevated the strategic significance of the project beyond emissions abatement. In conclusion, QatarEnergy LNG’s CO2 injection facility serves as a benchmark for successful CCS implementation in the region. Its evolution from an acid gas injection system to a dedicated CO2 storage facility exemplifies effective adaptation to emerging environmental imperatives. The insights garnered from this case study aim to inform and guide decarbonisation initiatives within the energy sector while providing a model for LNG operators worldwide to embed CCS at scale using existing infrastructure to ensure measurable and verifiable GHG reductions.
Carbon Capture and Storage (CCS) is a pivotal technology for mitigating greenhouse gas emissions and achieving global climate goals. The process entails capturing carbon dioxide (CO₂) from industrial and energy sources, transporting it in compressed form, and permanently storing it in deep geological formations to prevent atmospheric re-release. Secure geological storage is critical to the long-term efficacy of CCS, relying on multiple trapping mechanisms, structural, residual, solubility, and mineral, to ensure containment and minimize leakage risks. Suitable formations, including deep saline aquifers, depleted hydrocarbon reservoirs, unmineable coal seams, and basalts with natural mineralization potential, provide robust storage options due to their capacity and stability.
A comprehensive CCS initiative is underway to develop a scalable portfolio of CO₂ storage sites, aligning with national emissions reduction targets, and fostering regional CCS hubs in Saudi Arabia. This initiative employs a phased, multidisciplinary approach that integrates geoscience, engineering, and strategic planning to identify, evaluate, and manage high-potential storage locations. The methodology prioritizes technical rigor, geographic diversity, and cost-effectiveness, ensuring both environmental and economic viability.
The initiative commenced with regional geological screening, leveraging extensive geological surveys, petroleum basin data, and academic research to identify promising basins. A stringent set of exclusion criteria eliminated unsuitable areas, focusing on formations with optimal storage attributes, such as deep saline aquifers and depleted reservoirs, and basalts with natural mineralization potential. Candidate basins were further evaluated based on proximity to major CO₂ emission sources and the feasibility of pipeline infrastructure, optimizing transport costs and operational efficiency. This screening process yielded a prioritized set of high-potential basins strategically positioned to support large-scale CCS deployment.
Selected basins are undergoing rigorous site-specific assessments through an integrated CO₂ evaluation framework. This includes advanced geophysical, geological, petrophysical, and geomechanical studies to characterize subsurface properties, followed by static and dynamic reservoir modeling to estimate storage capacity, injectivity, seal integrity, and potential leakage risks. An uncertainty and risk assessment framework quantifies variables, enabling the calculation of risk-adjusted storage capacities and facilitating the ranking of sites within each basin. Surface-level considerations, such as existing infrastructure, alignment with emission source locations, and strategic importance are incorporated to ensure pragmatic site selection.
Preliminary results indicate significant storage potential across identified basins, with several sites demonstrating high injectivity and robust sealing mechanisms. The approach ensures scalability by designing sites to accommodate future expansion of CCS operations. By integrating cutting-edge geoscience with practical infrastructure planning, this initiative establishes a technically sound and strategically aligned CCS portfolio. Saudi Arabia’s leadership in CCS deployment advances national climate goals and positions the initiative as a global pioneer in CCS, contributing substantially to international efforts to combat climate change.
A comprehensive CCS initiative is underway to develop a scalable portfolio of CO₂ storage sites, aligning with national emissions reduction targets, and fostering regional CCS hubs in Saudi Arabia. This initiative employs a phased, multidisciplinary approach that integrates geoscience, engineering, and strategic planning to identify, evaluate, and manage high-potential storage locations. The methodology prioritizes technical rigor, geographic diversity, and cost-effectiveness, ensuring both environmental and economic viability.
The initiative commenced with regional geological screening, leveraging extensive geological surveys, petroleum basin data, and academic research to identify promising basins. A stringent set of exclusion criteria eliminated unsuitable areas, focusing on formations with optimal storage attributes, such as deep saline aquifers and depleted reservoirs, and basalts with natural mineralization potential. Candidate basins were further evaluated based on proximity to major CO₂ emission sources and the feasibility of pipeline infrastructure, optimizing transport costs and operational efficiency. This screening process yielded a prioritized set of high-potential basins strategically positioned to support large-scale CCS deployment.
Selected basins are undergoing rigorous site-specific assessments through an integrated CO₂ evaluation framework. This includes advanced geophysical, geological, petrophysical, and geomechanical studies to characterize subsurface properties, followed by static and dynamic reservoir modeling to estimate storage capacity, injectivity, seal integrity, and potential leakage risks. An uncertainty and risk assessment framework quantifies variables, enabling the calculation of risk-adjusted storage capacities and facilitating the ranking of sites within each basin. Surface-level considerations, such as existing infrastructure, alignment with emission source locations, and strategic importance are incorporated to ensure pragmatic site selection.
Preliminary results indicate significant storage potential across identified basins, with several sites demonstrating high injectivity and robust sealing mechanisms. The approach ensures scalability by designing sites to accommodate future expansion of CCS operations. By integrating cutting-edge geoscience with practical infrastructure planning, this initiative establishes a technically sound and strategically aligned CCS portfolio. Saudi Arabia’s leadership in CCS deployment advances national climate goals and positions the initiative as a global pioneer in CCS, contributing substantially to international efforts to combat climate change.
Iran, with the fourth largest proven oil reserves in the world, faces two major challenges: decreasing oil production in the mature fields and increasing pressure to reduce carbon emissions in the energy sector. One proposed solution is to combine enhanced oil recovery (EOR) with carbon capture and storage (CCS) by injecting CO₂ into depleted or partially depleted reservoirs. This study examines the technical and geological feasibility of establishing CCS hubs in Iran, according to actual data from domestic reservoirs.
This analysis examines several oil reservoirs in the southern and southwestern of Iran, including the Maroon, Ahvaz, and Aghajari fields. According to data from the National Iranian Oil Company (NIOC), these fields have an estimated CO2 storage capacity of more than 4.3 billion tons. For example, the Aghajari field alone has the potential to store about 730 million tons of CO₂, which is equivalent to decades of injection under a standard EOR program. Injection at pressures of 1100 up to 1500 psi can provide miscibility in these formations and increase oil recovery by up to 12%.
This study uses seismic and petrophysical data to investigate formation integrity, properties of caprock sealing, and regional fault systems. Also, the separation of carbon dioxide from produced oil—a major operational bottleneck—has been investigated, according to existing gas separation and recovery units. The deployment of these infrastructures reduces the new investment costs and make the integrated CCS hubs more economically viable.
Although Iran currently does not have an official mechanism for carbon pricing, the feasibility study of this plan has been done using global carbon credit prices between $30 and $100 per ton. The results show that the break-even point of the project is achieved in less than 10 years under optimal recovery conditions. Having the dual benefit of increasing oil recovery and permanent CO₂ storage, this plan is aligned with Iran's strategic goals to increase the life of reservoirs and reduce carbon emissions.
Several CO₂-EOR projects have been done in Iran, mainly focusing on enhancing oil recovery and reducing greenhouse gas emissions. A pilot project at the Ramin oil field utilized CO₂ captured from the Ramin Power Plant, aiming to increase oil recovery by 16–80%. Also, feasibility studies by Alborz Energy examined over 40 reservoirs for CO₂ injection, leading to the design of necessary capture and injection infrastructure. Additional evaluations estimated that each ton of injected CO₂ could yield 2–8 additional barrels of oil.
This paper suggests that CCS hubs based on CO2-EOR in Iran are technically and geologically feasible. With appropriate regulatory frameworks and investment in monitoring and verification, these hubs could form the backbone of Iran’s long-term carbon management infrastructure.
This analysis examines several oil reservoirs in the southern and southwestern of Iran, including the Maroon, Ahvaz, and Aghajari fields. According to data from the National Iranian Oil Company (NIOC), these fields have an estimated CO2 storage capacity of more than 4.3 billion tons. For example, the Aghajari field alone has the potential to store about 730 million tons of CO₂, which is equivalent to decades of injection under a standard EOR program. Injection at pressures of 1100 up to 1500 psi can provide miscibility in these formations and increase oil recovery by up to 12%.
This study uses seismic and petrophysical data to investigate formation integrity, properties of caprock sealing, and regional fault systems. Also, the separation of carbon dioxide from produced oil—a major operational bottleneck—has been investigated, according to existing gas separation and recovery units. The deployment of these infrastructures reduces the new investment costs and make the integrated CCS hubs more economically viable.
Although Iran currently does not have an official mechanism for carbon pricing, the feasibility study of this plan has been done using global carbon credit prices between $30 and $100 per ton. The results show that the break-even point of the project is achieved in less than 10 years under optimal recovery conditions. Having the dual benefit of increasing oil recovery and permanent CO₂ storage, this plan is aligned with Iran's strategic goals to increase the life of reservoirs and reduce carbon emissions.
Several CO₂-EOR projects have been done in Iran, mainly focusing on enhancing oil recovery and reducing greenhouse gas emissions. A pilot project at the Ramin oil field utilized CO₂ captured from the Ramin Power Plant, aiming to increase oil recovery by 16–80%. Also, feasibility studies by Alborz Energy examined over 40 reservoirs for CO₂ injection, leading to the design of necessary capture and injection infrastructure. Additional evaluations estimated that each ton of injected CO₂ could yield 2–8 additional barrels of oil.
This paper suggests that CCS hubs based on CO2-EOR in Iran are technically and geologically feasible. With appropriate regulatory frameworks and investment in monitoring and verification, these hubs could form the backbone of Iran’s long-term carbon management infrastructure.
CO2 injection into reservoirs for enhanced oil recovery and sequestration is the most efficiency way to realize the carbon neutrality goal. Various types of reservoirs could be the targets for CO2 sequestration but which one should be the best choice is still unclear, especially for the huge reserves of heavy oil reservoirs and low permeability reservoirs. The sealing property of cap rock, displacement efficiency of CO2 flooding and CO2 dissolution ability in the oil jointly determined the CO2 sequestration potential.
This work compared the CO2 sequestration potential between heavy oil reservoirs and low permeability light oil reservoirs via a series of experiments and numerical simulations. The breakthrough pressure of CO2 in the caprock, the CO2 dissolution amount in heavy oil and light oil and oil displacement effective by CO2 flooding were investigated to evaluate CO2 sequestration capability via dissolution and capillary trapping in two types reservoirs. Moreover, the numerical simulation of CO2 flooding in a heavy oil reservoir and low permeability reservoir were performed based on the above experimental data to quantitatively clarify the CO2 sequestration potential.
The breakthrough pressure of the mudstone caprock of the heavy oil reservoir was 35 times higher than that of the silty mudstone caprock of the low permeability reservoir, which indicated the CO2 sequestration pressure in the low permeability reservoir was higher than that in the heavy oi reservoir. The solubility of CO2 in the heavy oil was 2 times lower than that in the light oil. The CO2 sequestration amount per unit pore volume was slightly higher in the heavy oil reservoir than that in the light oil reservoir under a certain temperature and pressure condition, and it increased while temperature increased due to the incremental displacement efficiency of heavy oil. The proportion of CO2 sequestration by capillary trapping in low permeability cores could reach 87% while the CO2 sequestration by dissolution in the heavy oil reservoir was nearly 30%. Numerical simulation found that in the real reservoir conduction, the CO2 sequestration amount per unit pore volume of low permeability light oil reservoir was 1.5 times than that of the heavy oil reservoir because the low permeability reservoir possessed a larger reservoir pressure and higher CO2 displacement efficiency.
Our work found compare to the heavy oil reservoir, the low permeability light oil reservoir presented a larger CO2 sequestration potential. The CO2 flooding could significantly enhance the heavy oil recovery, especially in coordination with the temperature increment. We expect this work could point out the application direction for the CO2 enhanced oil recovery and sequestration.
This work compared the CO2 sequestration potential between heavy oil reservoirs and low permeability light oil reservoirs via a series of experiments and numerical simulations. The breakthrough pressure of CO2 in the caprock, the CO2 dissolution amount in heavy oil and light oil and oil displacement effective by CO2 flooding were investigated to evaluate CO2 sequestration capability via dissolution and capillary trapping in two types reservoirs. Moreover, the numerical simulation of CO2 flooding in a heavy oil reservoir and low permeability reservoir were performed based on the above experimental data to quantitatively clarify the CO2 sequestration potential.
The breakthrough pressure of the mudstone caprock of the heavy oil reservoir was 35 times higher than that of the silty mudstone caprock of the low permeability reservoir, which indicated the CO2 sequestration pressure in the low permeability reservoir was higher than that in the heavy oi reservoir. The solubility of CO2 in the heavy oil was 2 times lower than that in the light oil. The CO2 sequestration amount per unit pore volume was slightly higher in the heavy oil reservoir than that in the light oil reservoir under a certain temperature and pressure condition, and it increased while temperature increased due to the incremental displacement efficiency of heavy oil. The proportion of CO2 sequestration by capillary trapping in low permeability cores could reach 87% while the CO2 sequestration by dissolution in the heavy oil reservoir was nearly 30%. Numerical simulation found that in the real reservoir conduction, the CO2 sequestration amount per unit pore volume of low permeability light oil reservoir was 1.5 times than that of the heavy oil reservoir because the low permeability reservoir possessed a larger reservoir pressure and higher CO2 displacement efficiency.
Our work found compare to the heavy oil reservoir, the low permeability light oil reservoir presented a larger CO2 sequestration potential. The CO2 flooding could significantly enhance the heavy oil recovery, especially in coordination with the temperature increment. We expect this work could point out the application direction for the CO2 enhanced oil recovery and sequestration.
