TECHNICAL PROGRAMME | Energy Infrastructure – Future Pathways
CCS Hub Facilities
Forum 9 | Digital Poster Plaza 2
29
April
11:30
13:30
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) technologies are increasingly recognized as essential tools for decarbonizing hydrocarbon-producing countries, where extensive oil and gas infrastructure offers a strategic advantage for early CCS deployment. This paper examines the potential for integrating CCS technologies by leveraging existing assets such as natural gas processing plants, transmission pipeline networks, and depleted oil and gas reservoirs. These assets provide a cost-effective foundation for large-scale CO₂ capture, transport, and permanent geological storage. The study analyzes key technical considerations required for successful CCS implementation, including the capture of high-purity CO₂ from industrial sources, compression systems optimization, transport via adapted pipelines, and safe injection into suitable subsurface formations. Particular attention is given to corrosion risks in pipelines, material compatibility, pressure management, and long-term monitoring technologies essential for ensuring storage integrity and addressing public and regulatory concerns. The role of industrial clusters—including refineries, petrochemical plants, and gas processing units—as priority hubs for early CCS projects is also explored. These concentrated emission sources offer economic and logistical advantages for pilot-scale deployment. Additionally, the study investigates carbon utilization opportunities, such as enhanced oil recovery (CO₂-EOR), mineral carbonation, and conversion into synthetic fuels or carbon-based products, which can improve the commercial viability of CCS projects. Infrastructure readiness assessments reveal that minimal modifications to existing pipeline and processing infrastructure may enable early-stage CCS deployment, while highlighting the need for targeted investments in compression, dehydration, and monitoring technologies. Regulatory frameworks, permitting processes, and safety standards are identified as critical gaps that must be addressed to accelerate project implementation. The paper concludes with a strategic roadmap for phased CCS deployment, emphasizing the importance of pilot demonstration projects, public-private partnerships, and regional cooperation. By capitalizing on existing hydrocarbon infrastructure, hydrocarbon-based economies can position themselves to achieve substantial CO₂ emission reductions, comply with international climate objectives, and ensure long-term energy security and economic resilience in the face of global energy transition.
Modern oil and gas production faces the challenges of increasing efficiency and reducing environmental impact. Our purpose was to develop the enhanced CO2 sequestration via its mineralization into mining and industrial wastes in surface conditions. The objectives of the study were: 1) demonstrating the high potential of industrial wastes to sequester CO2, 2) identifying key factors enhancing carbonization intensity, and 3) developing the extraction of the strategic components from the CO2 mineralization products.
The investigation of CO2 mineralization by mining and industrial waste was carried out using the original experimental technique. The experiments simulate physical-chemical conditions on the surface in locations of waste storage, which is especially relevant for further scaling of the technology and its direct testing at industrial facilities. The technique allows monitoring in detail over time the intensity of the mineralization process and determining the degree of CO2 sequestration by the solid material. Among the factors regulating the efficiency of mineralization, the main ones are the granulometric composition of waste, temperature, humidity of the environment, and fluid composition.
The investigation demonstrated the critical role of the granulometric composition of waste, the composition and amount of solution, and temperature on the kinetics of the carbonatization reaction and the efficiency of the CO2 mineralization process into industrial waste. As a result, the impact of each physicochemical parameter on the rate and degree of mineralization was identified, and the most effective waste treatment conditions for obtaining maximum CO2 binding into carbonates were demonstrated. The first series of laboratory tests on the samples of metallurgical slags, as well as basic and ultrabasic rocks of the mining industry, were conducted at room temperature and atmospheric pressure. The results demonstrate the dynamics of CO2 uptake over 10 wt.% for the first month of treatment with the maximum uptake over 25 wt.%. The research allows to conclude that the proposed technique provides not only efficient CO2 sequestration into solid mineral phases but also suggests sustainable solutions for the management of the large groups of inorganic wastes, namely mine tailings, iron and steelmaking slags and cement wastes. The proposed technique is also an effective route for the disintegration of materials for the subsequent recovery of residual minerals.
The research demonstrated the huge potential of inorganic waste, accumulated annually by millions of tons in mining, industrial, and power facilities, for CO2 mineralization. New breakthrough approach to waste management in surface conditions has been developed and applied. In addition to high CO2 binding, the technique allows for cheaper disintegration of waste to recover residual minerals. Thus, we have been able to optimize solutions to the challenges of industries while ensuring the sustainable development conditions.
Co-author/s:
Audrey Kovalskii, Research Science Specialist, Aramco Innovations LLC - Aramco Research Center.
The investigation of CO2 mineralization by mining and industrial waste was carried out using the original experimental technique. The experiments simulate physical-chemical conditions on the surface in locations of waste storage, which is especially relevant for further scaling of the technology and its direct testing at industrial facilities. The technique allows monitoring in detail over time the intensity of the mineralization process and determining the degree of CO2 sequestration by the solid material. Among the factors regulating the efficiency of mineralization, the main ones are the granulometric composition of waste, temperature, humidity of the environment, and fluid composition.
The investigation demonstrated the critical role of the granulometric composition of waste, the composition and amount of solution, and temperature on the kinetics of the carbonatization reaction and the efficiency of the CO2 mineralization process into industrial waste. As a result, the impact of each physicochemical parameter on the rate and degree of mineralization was identified, and the most effective waste treatment conditions for obtaining maximum CO2 binding into carbonates were demonstrated. The first series of laboratory tests on the samples of metallurgical slags, as well as basic and ultrabasic rocks of the mining industry, were conducted at room temperature and atmospheric pressure. The results demonstrate the dynamics of CO2 uptake over 10 wt.% for the first month of treatment with the maximum uptake over 25 wt.%. The research allows to conclude that the proposed technique provides not only efficient CO2 sequestration into solid mineral phases but also suggests sustainable solutions for the management of the large groups of inorganic wastes, namely mine tailings, iron and steelmaking slags and cement wastes. The proposed technique is also an effective route for the disintegration of materials for the subsequent recovery of residual minerals.
The research demonstrated the huge potential of inorganic waste, accumulated annually by millions of tons in mining, industrial, and power facilities, for CO2 mineralization. New breakthrough approach to waste management in surface conditions has been developed and applied. In addition to high CO2 binding, the technique allows for cheaper disintegration of waste to recover residual minerals. Thus, we have been able to optimize solutions to the challenges of industries while ensuring the sustainable development conditions.
Co-author/s:
Audrey Kovalskii, Research Science Specialist, Aramco Innovations LLC - Aramco Research Center.
Introduction and Objective:
Reducing greenhouse gas emissions and achieving net zero carbon targets have become global priorities in addressing climate change, requiring comprehensive and interdisciplinary solutions. Energy efficiency and reducing energy losses are key strategies in this pathway, playing a crucial role in directly minimizing greenhouse gas emissions. This study aims to review and analyze various net zero carbon initiatives and projects across different countries and continents that focus on enhancing energy efficiency and reducing energy waste, as well as to examine their measurable impacts on greenhouse gas emission reductions.
Methodology:
This systematic review was conducted up to August 2025 by two independent reviewers. Initially, keywords related to energy, energy efficiency, greenhouse gas reduction, climate change, decarbonization, and sustainability were identified. Comprehensive searches were performed in reputable global databases such as Scopus, Web of Science, PubMed, and Google Scholar to collect research articles, policy reports, and case studies. Data regarding article characteristics, study types, geographic regions, technologies or solutions discussed, environmental and economic impacts, and data quality were extracted and analyzed using a customized form developed by the researchers. Collected sources were categorized into developed and developing regions and reviewed. Technical innovations, key projects, and evidence of environmental and economic impacts were critically described and analyzed to provide a comprehensive global overview with regional differences.
Results:
Policy reviews and decarbonization projects across various regions revealed the following:
Western and Northern Europe
North America
Asia
Africa and Latin America
Key Innovations in Decarbonization
All of these technologies and policies have played effective roles in reducing greenhouse gas emissions and improving energy efficiency.
Conclusion:
Overall, the global decarbonization trend is primarily driven by the development and deployment of advanced technologies, implementation of stringent environmental policies, and enhancement of energy efficiency. These approaches manifest differently according to regional conditions, priorities, and specific needs of each country or area. Digital technologies and clean energies are recognized as key enablers of this transformation, playing vital roles in improving energy management and reducing environmental impacts.
Co-author/s:
Mehdi Saberi, Oil Company Employee, Pars Special Economic Energy Zone (PSEEZ), National Iranian Oil Company (NIOC).
Fatemeh Kamraninia, Oil Company Employee, Pars Special Economic Energy Zone (PSEEZ), National Iranian Oil Company (NIOC).
Reducing greenhouse gas emissions and achieving net zero carbon targets have become global priorities in addressing climate change, requiring comprehensive and interdisciplinary solutions. Energy efficiency and reducing energy losses are key strategies in this pathway, playing a crucial role in directly minimizing greenhouse gas emissions. This study aims to review and analyze various net zero carbon initiatives and projects across different countries and continents that focus on enhancing energy efficiency and reducing energy waste, as well as to examine their measurable impacts on greenhouse gas emission reductions.
Methodology:
This systematic review was conducted up to August 2025 by two independent reviewers. Initially, keywords related to energy, energy efficiency, greenhouse gas reduction, climate change, decarbonization, and sustainability were identified. Comprehensive searches were performed in reputable global databases such as Scopus, Web of Science, PubMed, and Google Scholar to collect research articles, policy reports, and case studies. Data regarding article characteristics, study types, geographic regions, technologies or solutions discussed, environmental and economic impacts, and data quality were extracted and analyzed using a customized form developed by the researchers. Collected sources were categorized into developed and developing regions and reviewed. Technical innovations, key projects, and evidence of environmental and economic impacts were critically described and analyzed to provide a comprehensive global overview with regional differences.
Results:
Policy reviews and decarbonization projects across various regions revealed the following:
Western and Northern Europe
- The European Union leads with stringent greenhouse gas reduction policies. Their projects include optimized district heating systems, net-zero energy buildings, and advanced energy management utilizing digital twins.
- Advanced technologies encompass energy recovery in wastewater treatment, innovative building insulations, and improved efficiency in maritime transport powered by clean fuels.
- Energy efficiency improvements in buildings and district heating have reduced up to 30% of energy losses.
- Digital twin technologies have played an essential role in monitoring and optimizing energy usage, reducing costs and emissions.
North America
- Successful projects include net-zero-energy wastewater treatment, industrial and building energy efficiency upgrades, and the use of carbon-neutral biogas.
- Integration of digital technologies with renewable energies in regional grids has significantly reduced greenhouse gas emissions.
- Increased efficiency and emissions reduction across various industrial sectors are among the key achievements.
Asia
- China and India are recognized as key players in clean energy projects.
- The adoption of innovative technologies such as clean hydrogen production, artificial intelligence, energy system digitalization, port energy management, and advanced transportation has contributed to optimizing energy consumption and carbon reduction.
- Diverse projects targeting decarbonization of key industries and the transportation sector using novel technologies like hydrogen and ammonia are underway.
Africa and Latin America
- Focus is placed on optimizing agricultural practices, rural electrification combining solar and gas energy, and low-cost local energy management projects.
- Localized projects adapted to regional conditions have lowered energy costs and contributed to decarbonization.
- Effectiveness and Progress
- In steel, cement, and oil industries, decarbonization and energy efficiency initiatives have led to significant reductions in greenhouse gas emissions.
- Net-zero carbon buildings and district heating systems reported up to 30% reductions in energy waste.
- Digital technologies, including digital twins, have been key to cost reductions and effectiveness improvements.
- Emerging technologies such as methane-to-hydrogen conversion and the use of carbon-neutral biogas have effectively expanded in specific sectors.
Key Innovations in Decarbonization
- Advanced membrane-based carbon capture technologies
- Clean hydrogen production using liquid metal catalysts
- AI-driven digitalization of energy management
- Application of phase change materials (PCM) in buildings for energy optimization
- Integration of renewable energies with effective consumption management
- Upgrading transportation systems with alternative fuels like hydrogen and ammonia
- Enhancing efficiency of maritime and land fleets with cutting-edge technologies
All of these technologies and policies have played effective roles in reducing greenhouse gas emissions and improving energy efficiency.
Conclusion:
Overall, the global decarbonization trend is primarily driven by the development and deployment of advanced technologies, implementation of stringent environmental policies, and enhancement of energy efficiency. These approaches manifest differently according to regional conditions, priorities, and specific needs of each country or area. Digital technologies and clean energies are recognized as key enablers of this transformation, playing vital roles in improving energy management and reducing environmental impacts.
Co-author/s:
Mehdi Saberi, Oil Company Employee, Pars Special Economic Energy Zone (PSEEZ), National Iranian Oil Company (NIOC).
Fatemeh Kamraninia, Oil Company Employee, Pars Special Economic Energy Zone (PSEEZ), National Iranian Oil Company (NIOC).
In response to growing environmental concerns and increasing global focus on reducing greenhouse gas emissions, Carbon Capture, Utilization, and Storage (CCUS) has emerged as one of the most effective engineering solutions to combat climate change. One of the key methods within this technology is the injection of carbon dioxide (CO₂) into geological formations for long-term storage. However, challenges such as high gas mobility, early breakthrough, uneven flow distribution, and poor performance in heterogeneous porous media have prompted the exploration of complementary methods to improve flow control. Among these, the use of CO₂ foam as a flow control and efficiency-enhancing agent has received significant attention in both research and industrial applications. CO₂-based foam exhibits high viscosity and the ability to drastically reduce gas mobility. This leads to improved flow stability, prevention of preferential flow in high-permeability zones, and enhanced sweep efficiency throughout the reservoir. Furthermore, in multiphase systems containing residual oil, foam can improve displacement efficiency and increase oil recovery, making it a dual-purpose and economically attractive option for integrated CCUS-EOR projects. Findings from laboratory experiments, numerical simulations, and field trials have demonstrated that CO₂ foam can multiply gas storage capacity while simultaneously reducing the risk of CO₂ leakage and unwanted migration. This technology has proven particularly effective in dual-layer systems with permeability contrast, aiding in the optimization of injection processes in complex reservoirs. In summary, the application of foam in CCUS not only enhances gas injection performance at an industrial scale but also facilitates the implementation of safe, stable, and cost-effective storage projects. Further development of this approach requires research into foam stability, optimal formulation design, and comprehensive economic evaluation.
Keywords: CCUS, CO₂ foam, Gas mobility control, Heterogeneous reservoirs, EOR, Subsurface CO₂ Storage.
Co-author/s:
Mohammad Simjoo, Associate Professor, Sahand University of Technology.
Keywords: CCUS, CO₂ foam, Gas mobility control, Heterogeneous reservoirs, EOR, Subsurface CO₂ Storage.
Co-author/s:
Mohammad Simjoo, Associate Professor, Sahand University of Technology.
Saudi Arabia's commitment to net-zero target by 2060 requires a rapid and effective decarbonization of its industrial sector, with carbon capture and storage (CCS) hubs emerging as a critical enabler. This paper presents a comprehensive study on the development of a major CCS geological storage hub in Saudi Arabia, targeting large-scale CO2 sequestration from industrial emitters. The research addresses key technical and economic factors to de-risk and optimize the CCS hub, providing a detailed roadmap for its successful deployment.
The methodology integrates multi-disciplinary workflows, including the analysis of regional geological and geophysical data to screen and characterize potential storage sites, utilize the advanced integrated reservoir modelling to estimate CO2 injectivity, predict CO2 plume migration, evaluate the containment integrity, and a techno-economic assessment of infrastructure. A primary focus is a deep saline aquifer that offers significant storage capacity for the large industrial clusters in the area. The study also evaluates pipeline network optimization for CO2 transport from multiple sources to the geological storage sites, considering factors such as CO2 purity, volume, and operational pressures.
Key findings include a robust quantification of the CO2 storage resource, detailed injectivity analysis and containment integrity assessment demonstrating the hub’s long-term viability, and an optimized plan for phased infrastructure development. The research provides a detailed understanding of the geological containment risks and presents a robust measurement, monitoring and verification (MMV) plan. This analysis demonstrates how a centralized CCS hub can significantly lower down the cost of decarbonization for individual emitters by leveraging economies of scale.
In conclusion, this study validates the technical feasibility and economic attractiveness of a large-scale geological CCS hub in Saudi Arabia. The results provide a critical foundation for project investment decisions, paving the way for a large-scale, sustainable industrial decarbonization effort. The hub will be a cornerstone of the Kingdom's net-zero strategy, showcasing a viable and scalable pathway for the oil and gas industry to lead the energy transition.
Co-author/s:
Ahmed Ghamdi, Senior Geophysical Consultant, Saudi Aramco.
Sylvester Egbeni, Geophysical Specialist, Saudi Aramco.
The methodology integrates multi-disciplinary workflows, including the analysis of regional geological and geophysical data to screen and characterize potential storage sites, utilize the advanced integrated reservoir modelling to estimate CO2 injectivity, predict CO2 plume migration, evaluate the containment integrity, and a techno-economic assessment of infrastructure. A primary focus is a deep saline aquifer that offers significant storage capacity for the large industrial clusters in the area. The study also evaluates pipeline network optimization for CO2 transport from multiple sources to the geological storage sites, considering factors such as CO2 purity, volume, and operational pressures.
Key findings include a robust quantification of the CO2 storage resource, detailed injectivity analysis and containment integrity assessment demonstrating the hub’s long-term viability, and an optimized plan for phased infrastructure development. The research provides a detailed understanding of the geological containment risks and presents a robust measurement, monitoring and verification (MMV) plan. This analysis demonstrates how a centralized CCS hub can significantly lower down the cost of decarbonization for individual emitters by leveraging economies of scale.
In conclusion, this study validates the technical feasibility and economic attractiveness of a large-scale geological CCS hub in Saudi Arabia. The results provide a critical foundation for project investment decisions, paving the way for a large-scale, sustainable industrial decarbonization effort. The hub will be a cornerstone of the Kingdom's net-zero strategy, showcasing a viable and scalable pathway for the oil and gas industry to lead the energy transition.
Co-author/s:
Ahmed Ghamdi, Senior Geophysical Consultant, Saudi Aramco.
Sylvester Egbeni, Geophysical Specialist, Saudi Aramco.
This research presents a groundbreaking, land-based system for carbon capture and utilization (CCU), meticulously designed for direct integration with the infrastructure of the petroleum industry. The solution addresses a critical challenge: decarbonizing operations in regions where water is scarce and land availability is a constraint. At its heart are modular photobioreactors, constructed from transparent Plexiglas to maximize sunlight penetration. These closed-loop vessels are filled with seawater and inoculated with selectively bred, high-performance strains of macroalgae (seaweed), chosen for their rapid growth rates and exceptional CO₂ absorption capabilities.
The process involves diverting industrial flue gas—a primary source of emissions—from a facility’s exhaust stream and bubbling it directly into the nutrient-rich saltwater within the reactors. Here, the seaweed performs enhanced photosynthesis, efficiently converting the captured carbon dioxide into dense, harvestable biomass. This biological sequestration method is a significant departure from more energy-intensive mechanical CCS approaches.
The system’s core innovation lies in its intelligent, closed-loop design, which is deliberately modular for scalable deployment in arid environments synonymous with major oil-producing nations. This design eliminates dependence on freshwater resources and protects the cultivation process from external contaminants and predators. Operational efficiency is managed by a sophisticated smart control system, driven by a dense network of Internet of Things (IoT) sensors. These sensors provide continuous, real-time data on a suite of critical parameters, including pH balance, nutrient concentration, temperature, and dissolved oxygen levels. The automation system responds instantly to these readings, fine-tuning the environment to maintain optimal growth conditions 24/7, thereby maximizing both sequestration efficiency and biomass yield.
The harvested seaweed biomass serves as a sustainable, carbon-negative feedstock, creating a tangible circular carbon economy. It can be processed into a portfolio of valuable products that support broader sustainability goals. These include advanced third-generation biofuels, which offer a carbon-neutral alternative for transportation; protein-rich animal feed that can alleviate pressure on agricultural land; and organic fertilizers that promote soil health. This transformation of a liability—CO₂ emissions—into a suite of marketable commodities provides a compelling economic incentive for adoption.
Currently at Technology Readiness Level (TRL) 4, this project has been validated at the laboratory scale, demonstrating a practical and profitable pathway for petroleum operators to reduce their carbon footprint. It aligns perfectly with national visions for a greener future, such as the Saudi Green Initiative, by offering a viable, technology-driven CCU solution. This system not only supports the industry’s urgent decarbonization goals but also fosters economic diversification, contributing to a more resilient and sustainable energy landscape.
The process involves diverting industrial flue gas—a primary source of emissions—from a facility’s exhaust stream and bubbling it directly into the nutrient-rich saltwater within the reactors. Here, the seaweed performs enhanced photosynthesis, efficiently converting the captured carbon dioxide into dense, harvestable biomass. This biological sequestration method is a significant departure from more energy-intensive mechanical CCS approaches.
The system’s core innovation lies in its intelligent, closed-loop design, which is deliberately modular for scalable deployment in arid environments synonymous with major oil-producing nations. This design eliminates dependence on freshwater resources and protects the cultivation process from external contaminants and predators. Operational efficiency is managed by a sophisticated smart control system, driven by a dense network of Internet of Things (IoT) sensors. These sensors provide continuous, real-time data on a suite of critical parameters, including pH balance, nutrient concentration, temperature, and dissolved oxygen levels. The automation system responds instantly to these readings, fine-tuning the environment to maintain optimal growth conditions 24/7, thereby maximizing both sequestration efficiency and biomass yield.
The harvested seaweed biomass serves as a sustainable, carbon-negative feedstock, creating a tangible circular carbon economy. It can be processed into a portfolio of valuable products that support broader sustainability goals. These include advanced third-generation biofuels, which offer a carbon-neutral alternative for transportation; protein-rich animal feed that can alleviate pressure on agricultural land; and organic fertilizers that promote soil health. This transformation of a liability—CO₂ emissions—into a suite of marketable commodities provides a compelling economic incentive for adoption.
Currently at Technology Readiness Level (TRL) 4, this project has been validated at the laboratory scale, demonstrating a practical and profitable pathway for petroleum operators to reduce their carbon footprint. It aligns perfectly with national visions for a greener future, such as the Saudi Green Initiative, by offering a viable, technology-driven CCU solution. This system not only supports the industry’s urgent decarbonization goals but also fosters economic diversification, contributing to a more resilient and sustainable energy landscape.
The Kingdom of Saudi Arabia (KSA) generates an estimated 18 – 30 million tons of municipal solid waste (MSW) annually, and this is expected to increase in the upcoming years with population growth. Currently, most of this waste is disposed in landfills, leading to land use pressures, and methane emissions. There is a national target to divert 94% of MSW from landfill by 2035, through recycling, waste-to-energy (WtE), composting, and other means. WtE incinerators reduce landfill waste volumes, lower greenhouse gas (GHG) emissions, and recover useful energy in the form of electricity. However, there is a gap in the literature on the capacity for WtEs with carbon capture and storage (CCS) to offer carbon-neutral power and negative emissions in KSA. This study addresses this gap and provides a comparative assessment of the techno-economic and life cycle performance of WtE power plants, integrated with and without CCS, to identify their value to the system.
Thermodynamic process models were developed to design two separate MSW WtE plant configurations – with and without CCS. The model takes inputs such as the MSW throughput, feed composition, steam cycle parameters, and CCS system parameters to calculate the net power output, lifecycle GHG emissions, and total system costs. A nominal design throughput of 25 t/h of MSW is used to evaluate the key performance indicators for both of the aforementioned cases. At plant level, a WtE generator without CCS produces nearly 19 MW, reflecting an overall cycle efficiency of 25%. When coupled with CCS using a 90% capture rate, this reduces to 12 MW, owing to the energy penalties associated with solvent regeneration and CO2 compression.
Diverting all the MSW generation in KSA (18 Mt/yr – lower estimate) to WtE plants produces approximately 13 TWh/year of power, helping to diversify the generation mix. However, the combustion of fossil-derived plastics and other wastes in MSW results in a carbon intensity of approximately 325 kg CO2,eq/MWh of power. When integrated with CCS, the WtE plants can produce approximately 9 TWh/yr of zero-carbon electricity, and 8.5 Mt CO2/yr of negative emissions in the KSA.
From a whole-systems perspective, both WtE systems achieve more than 90% reductions in landfill volume, significantly extending their lifetimes, and mitigating uncontrolled methane release. The marginal cost of carbon abatement for WtE with CCS, defined as the sum total of marginal cost of CO2 avoidance, and removal, is lower ($200 – $450/ ton) than that for direct air capture and storage ($400 – 1000/ ton), thus increasing the potential for commercial deployment. These findings are sensitive to the plant design and operation, as well as the feed compositions, but it highlights WtE with CCS as a unique contributor to the Kingdom’s energy system and circular carbon economy.
Thermodynamic process models were developed to design two separate MSW WtE plant configurations – with and without CCS. The model takes inputs such as the MSW throughput, feed composition, steam cycle parameters, and CCS system parameters to calculate the net power output, lifecycle GHG emissions, and total system costs. A nominal design throughput of 25 t/h of MSW is used to evaluate the key performance indicators for both of the aforementioned cases. At plant level, a WtE generator without CCS produces nearly 19 MW, reflecting an overall cycle efficiency of 25%. When coupled with CCS using a 90% capture rate, this reduces to 12 MW, owing to the energy penalties associated with solvent regeneration and CO2 compression.
Diverting all the MSW generation in KSA (18 Mt/yr – lower estimate) to WtE plants produces approximately 13 TWh/year of power, helping to diversify the generation mix. However, the combustion of fossil-derived plastics and other wastes in MSW results in a carbon intensity of approximately 325 kg CO2,eq/MWh of power. When integrated with CCS, the WtE plants can produce approximately 9 TWh/yr of zero-carbon electricity, and 8.5 Mt CO2/yr of negative emissions in the KSA.
From a whole-systems perspective, both WtE systems achieve more than 90% reductions in landfill volume, significantly extending their lifetimes, and mitigating uncontrolled methane release. The marginal cost of carbon abatement for WtE with CCS, defined as the sum total of marginal cost of CO2 avoidance, and removal, is lower ($200 – $450/ ton) than that for direct air capture and storage ($400 – 1000/ ton), thus increasing the potential for commercial deployment. These findings are sensitive to the plant design and operation, as well as the feed compositions, but it highlights WtE with CCS as a unique contributor to the Kingdom’s energy system and circular carbon economy.
Decarbonizing hard-to-abate industries in Saudi Arabia will require CO₂ storage at hub scale, linking multiple emitters to shared subsurface complexes. This paper presents a comparative screening of candidate fields to identify which settings are best suited to near-term and scalable carbon storage. A multi-criteria decision framework integrates (i) subsurface potential—effective storage capacity, injectivity, pressure management options, caprock quality, structural simplicity, and legacy well density; (ii) risk and integrity—age/vintage of completions, well barrier condition, fault/fracture reactivation risk, and brine displacement pathways; and (iii) surface & system fit—proximity to major CO₂ sources, pipeline/power/water access, monitoring feasibility, land use, and permitting readiness.
Using representative datasets from mature onshore carbonates, regional aquifers, and offshore settings, each site is given a normalized “readiness score." A coupled flow–geomechanics model estimates plume footprint and pressure evolution under hub-scale injection scenarios, while a Bayesian integrity module quantifies wellbore leakage likelihood as a function of vintage and barrier diagnostics. Cost and schedule lenses—right-of-way, tie-in options, phased build-out, and MRV requirements—are layered to produce a storage advantage index that ranks sites by near-term viability and long-term scalability.
Results highlight trade-offs: high-injectivity mature reservoirs with dense legacy well stock may require upfront integrity retrofits but offer favorable infrastructure and learning curves; regionally extensive aquifers provide capacity and pressure buffering yet demand larger MRV footprints; offshore sites reduce onshore land conflict but increase CAPEX and logistics complexity. We outline a hub development playbook—pilot (≤1 Mt/yr), scale (5–10 Mt/yr), and network (>20 Mt/yr)—with decision gates tied to integrity KPIs and observed pressure behavior. The framework gives policymakers and operators a transparent, data-driven basis to prioritize CCS hubs that minimize risk, leverage existing drilling capabilities, and accelerate national carbon-management goals.
Using representative datasets from mature onshore carbonates, regional aquifers, and offshore settings, each site is given a normalized “readiness score." A coupled flow–geomechanics model estimates plume footprint and pressure evolution under hub-scale injection scenarios, while a Bayesian integrity module quantifies wellbore leakage likelihood as a function of vintage and barrier diagnostics. Cost and schedule lenses—right-of-way, tie-in options, phased build-out, and MRV requirements—are layered to produce a storage advantage index that ranks sites by near-term viability and long-term scalability.
Results highlight trade-offs: high-injectivity mature reservoirs with dense legacy well stock may require upfront integrity retrofits but offer favorable infrastructure and learning curves; regionally extensive aquifers provide capacity and pressure buffering yet demand larger MRV footprints; offshore sites reduce onshore land conflict but increase CAPEX and logistics complexity. We outline a hub development playbook—pilot (≤1 Mt/yr), scale (5–10 Mt/yr), and network (>20 Mt/yr)—with decision gates tied to integrity KPIs and observed pressure behavior. The framework gives policymakers and operators a transparent, data-driven basis to prioritize CCS hubs that minimize risk, leverage existing drilling capabilities, and accelerate national carbon-management goals.
An important method for increasing crude oil recovery in carbonate reservoirs is using natural gas injection for pressure maintenance or miscible flooding. With the global energy transition, natural gas has become more valuable over the past two decades and is increasingly consumed as a cleaner fuel than crude oil. This has limited crude oil producers' access to natural gas for enhanced recovery.
When natural gas is combusted in furnaces to generate electricity in thermal power plants or used in refineries and petrochemical plants, it produces carbon dioxide in the form of flue gas (composed of 72% nitrogen, 17% water vapor, and 11% carbon dioxide).
Collecting, purifying, compressing, transporting, and injecting this gas into oil fields creates a cleaner cycle than the traditional fossil fuel-based energy industry. This process prevents flue gas emissions (containing carbon dioxide) from being released into the atmosphere by storing them underground. Additionally, the energy efficiency of thermal power plants and furnaces improves when the produced gas is utilized in a closed cycle. Meanwhile, oil field recovery increases, and the need for valuable natural gas injection is replaced by less valuable flue gas (an enriched CO₂ + N₂ mixture).
Our research team has studied this technology in three parts:
The results have been acceptable in both simulation and laboratory phases. This article presents the surface process, which includes all stages of combustion gas collection, primary separation, multi-stage cooling and compression, transportation from the power plant to the field, and pressurization for injection.
A dehydration and compression unit was designed for post-combustion gas at 60°C, 1.5 bar pressure, and a mass flow rate of 2.5 million tons per year, assuming the oil field is located 35 km from the power plant. Material corrosion was considered a key limiting factor in purification and dehydration (down to 4 ppm H₂O). The dehydration process uses a multi-stage compression and cooling system combined with an absorption-based dehydration unit. To minimize energy consumption, the maximum temperature in each cycle was maintained at 95°C, reducing operating costs. The total power consumption for three flue gas collection scenarios (25%, 60%, and 100% of the power plant's output) was 7 MW, 15 MW, and 24 MW, respectively.
The simulation was followed by an economic study, with investment costs, operational results, and return on investment reported. The results demonstrate both technical and economic advantages for using power plant flue gas in purification processes while reducing carbon emissions.
Co-author/s:
Asadollah Hooshmand, Researcher, University of Tehran.
Mehdi Tabibnejad Azizi, Engineer, MAPNA Oil and Gas Development Company.
When natural gas is combusted in furnaces to generate electricity in thermal power plants or used in refineries and petrochemical plants, it produces carbon dioxide in the form of flue gas (composed of 72% nitrogen, 17% water vapor, and 11% carbon dioxide).
Collecting, purifying, compressing, transporting, and injecting this gas into oil fields creates a cleaner cycle than the traditional fossil fuel-based energy industry. This process prevents flue gas emissions (containing carbon dioxide) from being released into the atmosphere by storing them underground. Additionally, the energy efficiency of thermal power plants and furnaces improves when the produced gas is utilized in a closed cycle. Meanwhile, oil field recovery increases, and the need for valuable natural gas injection is replaced by less valuable flue gas (an enriched CO₂ + N₂ mixture).
Our research team has studied this technology in three parts:
- The process of capturing and purifying combustion gas (surface operations)
- Reservoir engineering and implementing enhanced oil recovery (subsurface operations)
- Economic and environmental aspects
The results have been acceptable in both simulation and laboratory phases. This article presents the surface process, which includes all stages of combustion gas collection, primary separation, multi-stage cooling and compression, transportation from the power plant to the field, and pressurization for injection.
A dehydration and compression unit was designed for post-combustion gas at 60°C, 1.5 bar pressure, and a mass flow rate of 2.5 million tons per year, assuming the oil field is located 35 km from the power plant. Material corrosion was considered a key limiting factor in purification and dehydration (down to 4 ppm H₂O). The dehydration process uses a multi-stage compression and cooling system combined with an absorption-based dehydration unit. To minimize energy consumption, the maximum temperature in each cycle was maintained at 95°C, reducing operating costs. The total power consumption for three flue gas collection scenarios (25%, 60%, and 100% of the power plant's output) was 7 MW, 15 MW, and 24 MW, respectively.
The simulation was followed by an economic study, with investment costs, operational results, and return on investment reported. The results demonstrate both technical and economic advantages for using power plant flue gas in purification processes while reducing carbon emissions.
Co-author/s:
Asadollah Hooshmand, Researcher, University of Tehran.
Mehdi Tabibnejad Azizi, Engineer, MAPNA Oil and Gas Development Company.
Bassam Bakalh
Chair
Expert, Ministry of Energy National Program for Circular Carbon Economy
Ministry of Energy
Yu Matsuno
Vice Chair
General Manager of Business Development Dept. II
Japan Petroleum Exploration Co., Ltd.
Decarbonizing hard-to-abate industries in Saudi Arabia will require CO₂ storage at hub scale, linking multiple emitters to shared subsurface complexes. This paper presents a comparative screening of candidate fields to identify which settings are best suited to near-term and scalable carbon storage. A multi-criteria decision framework integrates (i) subsurface potential—effective storage capacity, injectivity, pressure management options, caprock quality, structural simplicity, and legacy well density; (ii) risk and integrity—age/vintage of completions, well barrier condition, fault/fracture reactivation risk, and brine displacement pathways; and (iii) surface & system fit—proximity to major CO₂ sources, pipeline/power/water access, monitoring feasibility, land use, and permitting readiness.
Using representative datasets from mature onshore carbonates, regional aquifers, and offshore settings, each site is given a normalized “readiness score." A coupled flow–geomechanics model estimates plume footprint and pressure evolution under hub-scale injection scenarios, while a Bayesian integrity module quantifies wellbore leakage likelihood as a function of vintage and barrier diagnostics. Cost and schedule lenses—right-of-way, tie-in options, phased build-out, and MRV requirements—are layered to produce a storage advantage index that ranks sites by near-term viability and long-term scalability.
Results highlight trade-offs: high-injectivity mature reservoirs with dense legacy well stock may require upfront integrity retrofits but offer favorable infrastructure and learning curves; regionally extensive aquifers provide capacity and pressure buffering yet demand larger MRV footprints; offshore sites reduce onshore land conflict but increase CAPEX and logistics complexity. We outline a hub development playbook—pilot (≤1 Mt/yr), scale (5–10 Mt/yr), and network (>20 Mt/yr)—with decision gates tied to integrity KPIs and observed pressure behavior. The framework gives policymakers and operators a transparent, data-driven basis to prioritize CCS hubs that minimize risk, leverage existing drilling capabilities, and accelerate national carbon-management goals.
Using representative datasets from mature onshore carbonates, regional aquifers, and offshore settings, each site is given a normalized “readiness score." A coupled flow–geomechanics model estimates plume footprint and pressure evolution under hub-scale injection scenarios, while a Bayesian integrity module quantifies wellbore leakage likelihood as a function of vintage and barrier diagnostics. Cost and schedule lenses—right-of-way, tie-in options, phased build-out, and MRV requirements—are layered to produce a storage advantage index that ranks sites by near-term viability and long-term scalability.
Results highlight trade-offs: high-injectivity mature reservoirs with dense legacy well stock may require upfront integrity retrofits but offer favorable infrastructure and learning curves; regionally extensive aquifers provide capacity and pressure buffering yet demand larger MRV footprints; offshore sites reduce onshore land conflict but increase CAPEX and logistics complexity. We outline a hub development playbook—pilot (≤1 Mt/yr), scale (5–10 Mt/yr), and network (>20 Mt/yr)—with decision gates tied to integrity KPIs and observed pressure behavior. The framework gives policymakers and operators a transparent, data-driven basis to prioritize CCS hubs that minimize risk, leverage existing drilling capabilities, and accelerate national carbon-management goals.
Abbas Bahreini
Speaker
Senior Oil Consultant
Pars Special Economic Energy Zone (PSEEZ), National Iranian Oil Company (NIOC)
Introduction and Objective:
Reducing greenhouse gas emissions and achieving net zero carbon targets have become global priorities in addressing climate change, requiring comprehensive and interdisciplinary solutions. Energy efficiency and reducing energy losses are key strategies in this pathway, playing a crucial role in directly minimizing greenhouse gas emissions. This study aims to review and analyze various net zero carbon initiatives and projects across different countries and continents that focus on enhancing energy efficiency and reducing energy waste, as well as to examine their measurable impacts on greenhouse gas emission reductions.
Methodology:
This systematic review was conducted up to August 2025 by two independent reviewers. Initially, keywords related to energy, energy efficiency, greenhouse gas reduction, climate change, decarbonization, and sustainability were identified. Comprehensive searches were performed in reputable global databases such as Scopus, Web of Science, PubMed, and Google Scholar to collect research articles, policy reports, and case studies. Data regarding article characteristics, study types, geographic regions, technologies or solutions discussed, environmental and economic impacts, and data quality were extracted and analyzed using a customized form developed by the researchers. Collected sources were categorized into developed and developing regions and reviewed. Technical innovations, key projects, and evidence of environmental and economic impacts were critically described and analyzed to provide a comprehensive global overview with regional differences.
Results:
Policy reviews and decarbonization projects across various regions revealed the following:
Western and Northern Europe
North America
Asia
Africa and Latin America
Key Innovations in Decarbonization
All of these technologies and policies have played effective roles in reducing greenhouse gas emissions and improving energy efficiency.
Conclusion:
Overall, the global decarbonization trend is primarily driven by the development and deployment of advanced technologies, implementation of stringent environmental policies, and enhancement of energy efficiency. These approaches manifest differently according to regional conditions, priorities, and specific needs of each country or area. Digital technologies and clean energies are recognized as key enablers of this transformation, playing vital roles in improving energy management and reducing environmental impacts.
Co-author/s:
Mehdi Saberi, Oil Company Employee, Pars Special Economic Energy Zone (PSEEZ), National Iranian Oil Company (NIOC).
Fatemeh Kamraninia, Oil Company Employee, Pars Special Economic Energy Zone (PSEEZ), National Iranian Oil Company (NIOC).
Reducing greenhouse gas emissions and achieving net zero carbon targets have become global priorities in addressing climate change, requiring comprehensive and interdisciplinary solutions. Energy efficiency and reducing energy losses are key strategies in this pathway, playing a crucial role in directly minimizing greenhouse gas emissions. This study aims to review and analyze various net zero carbon initiatives and projects across different countries and continents that focus on enhancing energy efficiency and reducing energy waste, as well as to examine their measurable impacts on greenhouse gas emission reductions.
Methodology:
This systematic review was conducted up to August 2025 by two independent reviewers. Initially, keywords related to energy, energy efficiency, greenhouse gas reduction, climate change, decarbonization, and sustainability were identified. Comprehensive searches were performed in reputable global databases such as Scopus, Web of Science, PubMed, and Google Scholar to collect research articles, policy reports, and case studies. Data regarding article characteristics, study types, geographic regions, technologies or solutions discussed, environmental and economic impacts, and data quality were extracted and analyzed using a customized form developed by the researchers. Collected sources were categorized into developed and developing regions and reviewed. Technical innovations, key projects, and evidence of environmental and economic impacts were critically described and analyzed to provide a comprehensive global overview with regional differences.
Results:
Policy reviews and decarbonization projects across various regions revealed the following:
Western and Northern Europe
- The European Union leads with stringent greenhouse gas reduction policies. Their projects include optimized district heating systems, net-zero energy buildings, and advanced energy management utilizing digital twins.
- Advanced technologies encompass energy recovery in wastewater treatment, innovative building insulations, and improved efficiency in maritime transport powered by clean fuels.
- Energy efficiency improvements in buildings and district heating have reduced up to 30% of energy losses.
- Digital twin technologies have played an essential role in monitoring and optimizing energy usage, reducing costs and emissions.
North America
- Successful projects include net-zero-energy wastewater treatment, industrial and building energy efficiency upgrades, and the use of carbon-neutral biogas.
- Integration of digital technologies with renewable energies in regional grids has significantly reduced greenhouse gas emissions.
- Increased efficiency and emissions reduction across various industrial sectors are among the key achievements.
Asia
- China and India are recognized as key players in clean energy projects.
- The adoption of innovative technologies such as clean hydrogen production, artificial intelligence, energy system digitalization, port energy management, and advanced transportation has contributed to optimizing energy consumption and carbon reduction.
- Diverse projects targeting decarbonization of key industries and the transportation sector using novel technologies like hydrogen and ammonia are underway.
Africa and Latin America
- Focus is placed on optimizing agricultural practices, rural electrification combining solar and gas energy, and low-cost local energy management projects.
- Localized projects adapted to regional conditions have lowered energy costs and contributed to decarbonization.
- Effectiveness and Progress
- In steel, cement, and oil industries, decarbonization and energy efficiency initiatives have led to significant reductions in greenhouse gas emissions.
- Net-zero carbon buildings and district heating systems reported up to 30% reductions in energy waste.
- Digital technologies, including digital twins, have been key to cost reductions and effectiveness improvements.
- Emerging technologies such as methane-to-hydrogen conversion and the use of carbon-neutral biogas have effectively expanded in specific sectors.
Key Innovations in Decarbonization
- Advanced membrane-based carbon capture technologies
- Clean hydrogen production using liquid metal catalysts
- AI-driven digitalization of energy management
- Application of phase change materials (PCM) in buildings for energy optimization
- Integration of renewable energies with effective consumption management
- Upgrading transportation systems with alternative fuels like hydrogen and ammonia
- Enhancing efficiency of maritime and land fleets with cutting-edge technologies
All of these technologies and policies have played effective roles in reducing greenhouse gas emissions and improving energy efficiency.
Conclusion:
Overall, the global decarbonization trend is primarily driven by the development and deployment of advanced technologies, implementation of stringent environmental policies, and enhancement of energy efficiency. These approaches manifest differently according to regional conditions, priorities, and specific needs of each country or area. Digital technologies and clean energies are recognized as key enablers of this transformation, playing vital roles in improving energy management and reducing environmental impacts.
Co-author/s:
Mehdi Saberi, Oil Company Employee, Pars Special Economic Energy Zone (PSEEZ), National Iranian Oil Company (NIOC).
Fatemeh Kamraninia, Oil Company Employee, Pars Special Economic Energy Zone (PSEEZ), National Iranian Oil Company (NIOC).
Afshin Emamikhah
Speaker
Research and Technology Specialist
Iranian Gas Engineering and Development Company (IGEDC)
Carbon capture and storage (CCS) technologies are increasingly recognized as essential tools for decarbonizing hydrocarbon-producing countries, where extensive oil and gas infrastructure offers a strategic advantage for early CCS deployment. This paper examines the potential for integrating CCS technologies by leveraging existing assets such as natural gas processing plants, transmission pipeline networks, and depleted oil and gas reservoirs. These assets provide a cost-effective foundation for large-scale CO₂ capture, transport, and permanent geological storage. The study analyzes key technical considerations required for successful CCS implementation, including the capture of high-purity CO₂ from industrial sources, compression systems optimization, transport via adapted pipelines, and safe injection into suitable subsurface formations. Particular attention is given to corrosion risks in pipelines, material compatibility, pressure management, and long-term monitoring technologies essential for ensuring storage integrity and addressing public and regulatory concerns. The role of industrial clusters—including refineries, petrochemical plants, and gas processing units—as priority hubs for early CCS projects is also explored. These concentrated emission sources offer economic and logistical advantages for pilot-scale deployment. Additionally, the study investigates carbon utilization opportunities, such as enhanced oil recovery (CO₂-EOR), mineral carbonation, and conversion into synthetic fuels or carbon-based products, which can improve the commercial viability of CCS projects. Infrastructure readiness assessments reveal that minimal modifications to existing pipeline and processing infrastructure may enable early-stage CCS deployment, while highlighting the need for targeted investments in compression, dehydration, and monitoring technologies. Regulatory frameworks, permitting processes, and safety standards are identified as critical gaps that must be addressed to accelerate project implementation. The paper concludes with a strategic roadmap for phased CCS deployment, emphasizing the importance of pilot demonstration projects, public-private partnerships, and regional cooperation. By capitalizing on existing hydrocarbon infrastructure, hydrocarbon-based economies can position themselves to achieve substantial CO₂ emission reductions, comply with international climate objectives, and ensure long-term energy security and economic resilience in the face of global energy transition.
Amirhossein Molaei
Speaker
MSc Graduate in Petroleum and Natural Gas Engineering
Sahand University of Technology
In response to growing environmental concerns and increasing global focus on reducing greenhouse gas emissions, Carbon Capture, Utilization, and Storage (CCUS) has emerged as one of the most effective engineering solutions to combat climate change. One of the key methods within this technology is the injection of carbon dioxide (CO₂) into geological formations for long-term storage. However, challenges such as high gas mobility, early breakthrough, uneven flow distribution, and poor performance in heterogeneous porous media have prompted the exploration of complementary methods to improve flow control. Among these, the use of CO₂ foam as a flow control and efficiency-enhancing agent has received significant attention in both research and industrial applications. CO₂-based foam exhibits high viscosity and the ability to drastically reduce gas mobility. This leads to improved flow stability, prevention of preferential flow in high-permeability zones, and enhanced sweep efficiency throughout the reservoir. Furthermore, in multiphase systems containing residual oil, foam can improve displacement efficiency and increase oil recovery, making it a dual-purpose and economically attractive option for integrated CCUS-EOR projects. Findings from laboratory experiments, numerical simulations, and field trials have demonstrated that CO₂ foam can multiply gas storage capacity while simultaneously reducing the risk of CO₂ leakage and unwanted migration. This technology has proven particularly effective in dual-layer systems with permeability contrast, aiding in the optimization of injection processes in complex reservoirs. In summary, the application of foam in CCUS not only enhances gas injection performance at an industrial scale but also facilitates the implementation of safe, stable, and cost-effective storage projects. Further development of this approach requires research into foam stability, optimal formulation design, and comprehensive economic evaluation.
Keywords: CCUS, CO₂ foam, Gas mobility control, Heterogeneous reservoirs, EOR, Subsurface CO₂ Storage.
Co-author/s:
Mohammad Simjoo, Associate Professor, Sahand University of Technology.
Keywords: CCUS, CO₂ foam, Gas mobility control, Heterogeneous reservoirs, EOR, Subsurface CO₂ Storage.
Co-author/s:
Mohammad Simjoo, Associate Professor, Sahand University of Technology.
Sayeed Rushd
Speaker
Associate Professor
King Faisal University, Al Ahsa, Saudi Arabia
This research presents a groundbreaking, land-based system for carbon capture and utilization (CCU), meticulously designed for direct integration with the infrastructure of the petroleum industry. The solution addresses a critical challenge: decarbonizing operations in regions where water is scarce and land availability is a constraint. At its heart are modular photobioreactors, constructed from transparent Plexiglas to maximize sunlight penetration. These closed-loop vessels are filled with seawater and inoculated with selectively bred, high-performance strains of macroalgae (seaweed), chosen for their rapid growth rates and exceptional CO₂ absorption capabilities.
The process involves diverting industrial flue gas—a primary source of emissions—from a facility’s exhaust stream and bubbling it directly into the nutrient-rich saltwater within the reactors. Here, the seaweed performs enhanced photosynthesis, efficiently converting the captured carbon dioxide into dense, harvestable biomass. This biological sequestration method is a significant departure from more energy-intensive mechanical CCS approaches.
The system’s core innovation lies in its intelligent, closed-loop design, which is deliberately modular for scalable deployment in arid environments synonymous with major oil-producing nations. This design eliminates dependence on freshwater resources and protects the cultivation process from external contaminants and predators. Operational efficiency is managed by a sophisticated smart control system, driven by a dense network of Internet of Things (IoT) sensors. These sensors provide continuous, real-time data on a suite of critical parameters, including pH balance, nutrient concentration, temperature, and dissolved oxygen levels. The automation system responds instantly to these readings, fine-tuning the environment to maintain optimal growth conditions 24/7, thereby maximizing both sequestration efficiency and biomass yield.
The harvested seaweed biomass serves as a sustainable, carbon-negative feedstock, creating a tangible circular carbon economy. It can be processed into a portfolio of valuable products that support broader sustainability goals. These include advanced third-generation biofuels, which offer a carbon-neutral alternative for transportation; protein-rich animal feed that can alleviate pressure on agricultural land; and organic fertilizers that promote soil health. This transformation of a liability—CO₂ emissions—into a suite of marketable commodities provides a compelling economic incentive for adoption.
Currently at Technology Readiness Level (TRL) 4, this project has been validated at the laboratory scale, demonstrating a practical and profitable pathway for petroleum operators to reduce their carbon footprint. It aligns perfectly with national visions for a greener future, such as the Saudi Green Initiative, by offering a viable, technology-driven CCU solution. This system not only supports the industry’s urgent decarbonization goals but also fosters economic diversification, contributing to a more resilient and sustainable energy landscape.
The process involves diverting industrial flue gas—a primary source of emissions—from a facility’s exhaust stream and bubbling it directly into the nutrient-rich saltwater within the reactors. Here, the seaweed performs enhanced photosynthesis, efficiently converting the captured carbon dioxide into dense, harvestable biomass. This biological sequestration method is a significant departure from more energy-intensive mechanical CCS approaches.
The system’s core innovation lies in its intelligent, closed-loop design, which is deliberately modular for scalable deployment in arid environments synonymous with major oil-producing nations. This design eliminates dependence on freshwater resources and protects the cultivation process from external contaminants and predators. Operational efficiency is managed by a sophisticated smart control system, driven by a dense network of Internet of Things (IoT) sensors. These sensors provide continuous, real-time data on a suite of critical parameters, including pH balance, nutrient concentration, temperature, and dissolved oxygen levels. The automation system responds instantly to these readings, fine-tuning the environment to maintain optimal growth conditions 24/7, thereby maximizing both sequestration efficiency and biomass yield.
The harvested seaweed biomass serves as a sustainable, carbon-negative feedstock, creating a tangible circular carbon economy. It can be processed into a portfolio of valuable products that support broader sustainability goals. These include advanced third-generation biofuels, which offer a carbon-neutral alternative for transportation; protein-rich animal feed that can alleviate pressure on agricultural land; and organic fertilizers that promote soil health. This transformation of a liability—CO₂ emissions—into a suite of marketable commodities provides a compelling economic incentive for adoption.
Currently at Technology Readiness Level (TRL) 4, this project has been validated at the laboratory scale, demonstrating a practical and profitable pathway for petroleum operators to reduce their carbon footprint. It aligns perfectly with national visions for a greener future, such as the Saudi Green Initiative, by offering a viable, technology-driven CCU solution. This system not only supports the industry’s urgent decarbonization goals but also fosters economic diversification, contributing to a more resilient and sustainable energy landscape.
The Kingdom of Saudi Arabia (KSA) generates an estimated 18 – 30 million tons of municipal solid waste (MSW) annually, and this is expected to increase in the upcoming years with population growth. Currently, most of this waste is disposed in landfills, leading to land use pressures, and methane emissions. There is a national target to divert 94% of MSW from landfill by 2035, through recycling, waste-to-energy (WtE), composting, and other means. WtE incinerators reduce landfill waste volumes, lower greenhouse gas (GHG) emissions, and recover useful energy in the form of electricity. However, there is a gap in the literature on the capacity for WtEs with carbon capture and storage (CCS) to offer carbon-neutral power and negative emissions in KSA. This study addresses this gap and provides a comparative assessment of the techno-economic and life cycle performance of WtE power plants, integrated with and without CCS, to identify their value to the system.
Thermodynamic process models were developed to design two separate MSW WtE plant configurations – with and without CCS. The model takes inputs such as the MSW throughput, feed composition, steam cycle parameters, and CCS system parameters to calculate the net power output, lifecycle GHG emissions, and total system costs. A nominal design throughput of 25 t/h of MSW is used to evaluate the key performance indicators for both of the aforementioned cases. At plant level, a WtE generator without CCS produces nearly 19 MW, reflecting an overall cycle efficiency of 25%. When coupled with CCS using a 90% capture rate, this reduces to 12 MW, owing to the energy penalties associated with solvent regeneration and CO2 compression.
Diverting all the MSW generation in KSA (18 Mt/yr – lower estimate) to WtE plants produces approximately 13 TWh/year of power, helping to diversify the generation mix. However, the combustion of fossil-derived plastics and other wastes in MSW results in a carbon intensity of approximately 325 kg CO2,eq/MWh of power. When integrated with CCS, the WtE plants can produce approximately 9 TWh/yr of zero-carbon electricity, and 8.5 Mt CO2/yr of negative emissions in the KSA.
From a whole-systems perspective, both WtE systems achieve more than 90% reductions in landfill volume, significantly extending their lifetimes, and mitigating uncontrolled methane release. The marginal cost of carbon abatement for WtE with CCS, defined as the sum total of marginal cost of CO2 avoidance, and removal, is lower ($200 – $450/ ton) than that for direct air capture and storage ($400 – 1000/ ton), thus increasing the potential for commercial deployment. These findings are sensitive to the plant design and operation, as well as the feed compositions, but it highlights WtE with CCS as a unique contributor to the Kingdom’s energy system and circular carbon economy.
Thermodynamic process models were developed to design two separate MSW WtE plant configurations – with and without CCS. The model takes inputs such as the MSW throughput, feed composition, steam cycle parameters, and CCS system parameters to calculate the net power output, lifecycle GHG emissions, and total system costs. A nominal design throughput of 25 t/h of MSW is used to evaluate the key performance indicators for both of the aforementioned cases. At plant level, a WtE generator without CCS produces nearly 19 MW, reflecting an overall cycle efficiency of 25%. When coupled with CCS using a 90% capture rate, this reduces to 12 MW, owing to the energy penalties associated with solvent regeneration and CO2 compression.
Diverting all the MSW generation in KSA (18 Mt/yr – lower estimate) to WtE plants produces approximately 13 TWh/year of power, helping to diversify the generation mix. However, the combustion of fossil-derived plastics and other wastes in MSW results in a carbon intensity of approximately 325 kg CO2,eq/MWh of power. When integrated with CCS, the WtE plants can produce approximately 9 TWh/yr of zero-carbon electricity, and 8.5 Mt CO2/yr of negative emissions in the KSA.
From a whole-systems perspective, both WtE systems achieve more than 90% reductions in landfill volume, significantly extending their lifetimes, and mitigating uncontrolled methane release. The marginal cost of carbon abatement for WtE with CCS, defined as the sum total of marginal cost of CO2 avoidance, and removal, is lower ($200 – $450/ ton) than that for direct air capture and storage ($400 – 1000/ ton), thus increasing the potential for commercial deployment. These findings are sensitive to the plant design and operation, as well as the feed compositions, but it highlights WtE with CCS as a unique contributor to the Kingdom’s energy system and circular carbon economy.
Modern oil and gas production faces the challenges of increasing efficiency and reducing environmental impact. Our purpose was to develop the enhanced CO2 sequestration via its mineralization into mining and industrial wastes in surface conditions. The objectives of the study were: 1) demonstrating the high potential of industrial wastes to sequester CO2, 2) identifying key factors enhancing carbonization intensity, and 3) developing the extraction of the strategic components from the CO2 mineralization products.
The investigation of CO2 mineralization by mining and industrial waste was carried out using the original experimental technique. The experiments simulate physical-chemical conditions on the surface in locations of waste storage, which is especially relevant for further scaling of the technology and its direct testing at industrial facilities. The technique allows monitoring in detail over time the intensity of the mineralization process and determining the degree of CO2 sequestration by the solid material. Among the factors regulating the efficiency of mineralization, the main ones are the granulometric composition of waste, temperature, humidity of the environment, and fluid composition.
The investigation demonstrated the critical role of the granulometric composition of waste, the composition and amount of solution, and temperature on the kinetics of the carbonatization reaction and the efficiency of the CO2 mineralization process into industrial waste. As a result, the impact of each physicochemical parameter on the rate and degree of mineralization was identified, and the most effective waste treatment conditions for obtaining maximum CO2 binding into carbonates were demonstrated. The first series of laboratory tests on the samples of metallurgical slags, as well as basic and ultrabasic rocks of the mining industry, were conducted at room temperature and atmospheric pressure. The results demonstrate the dynamics of CO2 uptake over 10 wt.% for the first month of treatment with the maximum uptake over 25 wt.%. The research allows to conclude that the proposed technique provides not only efficient CO2 sequestration into solid mineral phases but also suggests sustainable solutions for the management of the large groups of inorganic wastes, namely mine tailings, iron and steelmaking slags and cement wastes. The proposed technique is also an effective route for the disintegration of materials for the subsequent recovery of residual minerals.
The research demonstrated the huge potential of inorganic waste, accumulated annually by millions of tons in mining, industrial, and power facilities, for CO2 mineralization. New breakthrough approach to waste management in surface conditions has been developed and applied. In addition to high CO2 binding, the technique allows for cheaper disintegration of waste to recover residual minerals. Thus, we have been able to optimize solutions to the challenges of industries while ensuring the sustainable development conditions.
Co-author/s:
Audrey Kovalskii, Research Science Specialist, Aramco Innovations LLC - Aramco Research Center.
The investigation of CO2 mineralization by mining and industrial waste was carried out using the original experimental technique. The experiments simulate physical-chemical conditions on the surface in locations of waste storage, which is especially relevant for further scaling of the technology and its direct testing at industrial facilities. The technique allows monitoring in detail over time the intensity of the mineralization process and determining the degree of CO2 sequestration by the solid material. Among the factors regulating the efficiency of mineralization, the main ones are the granulometric composition of waste, temperature, humidity of the environment, and fluid composition.
The investigation demonstrated the critical role of the granulometric composition of waste, the composition and amount of solution, and temperature on the kinetics of the carbonatization reaction and the efficiency of the CO2 mineralization process into industrial waste. As a result, the impact of each physicochemical parameter on the rate and degree of mineralization was identified, and the most effective waste treatment conditions for obtaining maximum CO2 binding into carbonates were demonstrated. The first series of laboratory tests on the samples of metallurgical slags, as well as basic and ultrabasic rocks of the mining industry, were conducted at room temperature and atmospheric pressure. The results demonstrate the dynamics of CO2 uptake over 10 wt.% for the first month of treatment with the maximum uptake over 25 wt.%. The research allows to conclude that the proposed technique provides not only efficient CO2 sequestration into solid mineral phases but also suggests sustainable solutions for the management of the large groups of inorganic wastes, namely mine tailings, iron and steelmaking slags and cement wastes. The proposed technique is also an effective route for the disintegration of materials for the subsequent recovery of residual minerals.
The research demonstrated the huge potential of inorganic waste, accumulated annually by millions of tons in mining, industrial, and power facilities, for CO2 mineralization. New breakthrough approach to waste management in surface conditions has been developed and applied. In addition to high CO2 binding, the technique allows for cheaper disintegration of waste to recover residual minerals. Thus, we have been able to optimize solutions to the challenges of industries while ensuring the sustainable development conditions.
Co-author/s:
Audrey Kovalskii, Research Science Specialist, Aramco Innovations LLC - Aramco Research Center.
Mahdi Zeinali Hassanvand
Speaker
Researcher and Academic Staff
Research Institute of Petroleum Industry
An important method for increasing crude oil recovery in carbonate reservoirs is using natural gas injection for pressure maintenance or miscible flooding. With the global energy transition, natural gas has become more valuable over the past two decades and is increasingly consumed as a cleaner fuel than crude oil. This has limited crude oil producers' access to natural gas for enhanced recovery.
When natural gas is combusted in furnaces to generate electricity in thermal power plants or used in refineries and petrochemical plants, it produces carbon dioxide in the form of flue gas (composed of 72% nitrogen, 17% water vapor, and 11% carbon dioxide).
Collecting, purifying, compressing, transporting, and injecting this gas into oil fields creates a cleaner cycle than the traditional fossil fuel-based energy industry. This process prevents flue gas emissions (containing carbon dioxide) from being released into the atmosphere by storing them underground. Additionally, the energy efficiency of thermal power plants and furnaces improves when the produced gas is utilized in a closed cycle. Meanwhile, oil field recovery increases, and the need for valuable natural gas injection is replaced by less valuable flue gas (an enriched CO₂ + N₂ mixture).
Our research team has studied this technology in three parts:
The results have been acceptable in both simulation and laboratory phases. This article presents the surface process, which includes all stages of combustion gas collection, primary separation, multi-stage cooling and compression, transportation from the power plant to the field, and pressurization for injection.
A dehydration and compression unit was designed for post-combustion gas at 60°C, 1.5 bar pressure, and a mass flow rate of 2.5 million tons per year, assuming the oil field is located 35 km from the power plant. Material corrosion was considered a key limiting factor in purification and dehydration (down to 4 ppm H₂O). The dehydration process uses a multi-stage compression and cooling system combined with an absorption-based dehydration unit. To minimize energy consumption, the maximum temperature in each cycle was maintained at 95°C, reducing operating costs. The total power consumption for three flue gas collection scenarios (25%, 60%, and 100% of the power plant's output) was 7 MW, 15 MW, and 24 MW, respectively.
The simulation was followed by an economic study, with investment costs, operational results, and return on investment reported. The results demonstrate both technical and economic advantages for using power plant flue gas in purification processes while reducing carbon emissions.
Co-author/s:
Asadollah Hooshmand, Researcher, University of Tehran.
Mehdi Tabibnejad Azizi, Engineer, MAPNA Oil and Gas Development Company.
When natural gas is combusted in furnaces to generate electricity in thermal power plants or used in refineries and petrochemical plants, it produces carbon dioxide in the form of flue gas (composed of 72% nitrogen, 17% water vapor, and 11% carbon dioxide).
Collecting, purifying, compressing, transporting, and injecting this gas into oil fields creates a cleaner cycle than the traditional fossil fuel-based energy industry. This process prevents flue gas emissions (containing carbon dioxide) from being released into the atmosphere by storing them underground. Additionally, the energy efficiency of thermal power plants and furnaces improves when the produced gas is utilized in a closed cycle. Meanwhile, oil field recovery increases, and the need for valuable natural gas injection is replaced by less valuable flue gas (an enriched CO₂ + N₂ mixture).
Our research team has studied this technology in three parts:
- The process of capturing and purifying combustion gas (surface operations)
- Reservoir engineering and implementing enhanced oil recovery (subsurface operations)
- Economic and environmental aspects
The results have been acceptable in both simulation and laboratory phases. This article presents the surface process, which includes all stages of combustion gas collection, primary separation, multi-stage cooling and compression, transportation from the power plant to the field, and pressurization for injection.
A dehydration and compression unit was designed for post-combustion gas at 60°C, 1.5 bar pressure, and a mass flow rate of 2.5 million tons per year, assuming the oil field is located 35 km from the power plant. Material corrosion was considered a key limiting factor in purification and dehydration (down to 4 ppm H₂O). The dehydration process uses a multi-stage compression and cooling system combined with an absorption-based dehydration unit. To minimize energy consumption, the maximum temperature in each cycle was maintained at 95°C, reducing operating costs. The total power consumption for three flue gas collection scenarios (25%, 60%, and 100% of the power plant's output) was 7 MW, 15 MW, and 24 MW, respectively.
The simulation was followed by an economic study, with investment costs, operational results, and return on investment reported. The results demonstrate both technical and economic advantages for using power plant flue gas in purification processes while reducing carbon emissions.
Co-author/s:
Asadollah Hooshmand, Researcher, University of Tehran.
Mehdi Tabibnejad Azizi, Engineer, MAPNA Oil and Gas Development Company.
Saudi Arabia's commitment to net-zero target by 2060 requires a rapid and effective decarbonization of its industrial sector, with carbon capture and storage (CCS) hubs emerging as a critical enabler. This paper presents a comprehensive study on the development of a major CCS geological storage hub in Saudi Arabia, targeting large-scale CO2 sequestration from industrial emitters. The research addresses key technical and economic factors to de-risk and optimize the CCS hub, providing a detailed roadmap for its successful deployment.
The methodology integrates multi-disciplinary workflows, including the analysis of regional geological and geophysical data to screen and characterize potential storage sites, utilize the advanced integrated reservoir modelling to estimate CO2 injectivity, predict CO2 plume migration, evaluate the containment integrity, and a techno-economic assessment of infrastructure. A primary focus is a deep saline aquifer that offers significant storage capacity for the large industrial clusters in the area. The study also evaluates pipeline network optimization for CO2 transport from multiple sources to the geological storage sites, considering factors such as CO2 purity, volume, and operational pressures.
Key findings include a robust quantification of the CO2 storage resource, detailed injectivity analysis and containment integrity assessment demonstrating the hub’s long-term viability, and an optimized plan for phased infrastructure development. The research provides a detailed understanding of the geological containment risks and presents a robust measurement, monitoring and verification (MMV) plan. This analysis demonstrates how a centralized CCS hub can significantly lower down the cost of decarbonization for individual emitters by leveraging economies of scale.
In conclusion, this study validates the technical feasibility and economic attractiveness of a large-scale geological CCS hub in Saudi Arabia. The results provide a critical foundation for project investment decisions, paving the way for a large-scale, sustainable industrial decarbonization effort. The hub will be a cornerstone of the Kingdom's net-zero strategy, showcasing a viable and scalable pathway for the oil and gas industry to lead the energy transition.
Co-author/s:
Ahmed Ghamdi, Senior Geophysical Consultant, Saudi Aramco.
Sylvester Egbeni, Geophysical Specialist, Saudi Aramco.
The methodology integrates multi-disciplinary workflows, including the analysis of regional geological and geophysical data to screen and characterize potential storage sites, utilize the advanced integrated reservoir modelling to estimate CO2 injectivity, predict CO2 plume migration, evaluate the containment integrity, and a techno-economic assessment of infrastructure. A primary focus is a deep saline aquifer that offers significant storage capacity for the large industrial clusters in the area. The study also evaluates pipeline network optimization for CO2 transport from multiple sources to the geological storage sites, considering factors such as CO2 purity, volume, and operational pressures.
Key findings include a robust quantification of the CO2 storage resource, detailed injectivity analysis and containment integrity assessment demonstrating the hub’s long-term viability, and an optimized plan for phased infrastructure development. The research provides a detailed understanding of the geological containment risks and presents a robust measurement, monitoring and verification (MMV) plan. This analysis demonstrates how a centralized CCS hub can significantly lower down the cost of decarbonization for individual emitters by leveraging economies of scale.
In conclusion, this study validates the technical feasibility and economic attractiveness of a large-scale geological CCS hub in Saudi Arabia. The results provide a critical foundation for project investment decisions, paving the way for a large-scale, sustainable industrial decarbonization effort. The hub will be a cornerstone of the Kingdom's net-zero strategy, showcasing a viable and scalable pathway for the oil and gas industry to lead the energy transition.
Co-author/s:
Ahmed Ghamdi, Senior Geophysical Consultant, Saudi Aramco.
Sylvester Egbeni, Geophysical Specialist, Saudi Aramco.
