TECHNICAL PROGRAMME | Energy Technologies – Future Pathways
GHG Emissions (Scope 1&2) Abatement (CO2, Methane) - Detection; CO2 Capture; CCUS; DAC; Carbon Products
Forum 20 | Digital Poster Plaza 4
28
April
12:30
14:30
UTC+3
This forum will explore innovative approaches and technologies for the detection and abatement of Scope 1 and 2 greenhouse gas emissions, including CO2 and methane. Topics will cover advanced detection methods, CO2 capture techniques, and carbon capture, utilisation, and storage (CCUS) strategies. Additionally, the forum will delve into direct air capture (DAC) technologies and the development of carbon products. Attendees will gain insights into the latest advancements and practical applications in reducing greenhouse gas emissions.
Objective/Scope
Methane abatement has become a top priority for oil and gas operators striving to balance operational efficiency and compliance. This paper presents GHGSat’s satellite-based methane monitoring system, which integrates proprietary satellite tasking and automated data processing to accelerate plume detection and deliver emissions intelligence within hours. The objective is to demonstrate how these innovations have shortened the time between detection and action, enabling operators to reduce emissions, mitigate risks, and enhance accountability across complex operations.
Methods/Process
GHGSat’s methane detection workflow begins with proprietary AI-enhanced satellite tasking guided by a proprietary algorithm that accounts for environmental conditions, emission source persistence, and operator needs. Observations are automatically processed via a cloud computing infrastructure, where an AI plume detector is used to flag observations with potential emissions. Observations are then prioritized by plume rank for further manual processing by human operators. A source-rate retrieval algorithm quantifies emissions and select detections are assessed against historic datasets to refine models and identify trends. This approach has reduced turnaround time, enabling faster detection and timely mitigation in oil and gas operations.
Results/Observations/Conclusions
The integration of AI-driven satellite tasking and automated processing has transformed methane detection at scale. In 2024, GHGSat conducted more than 77,000 satellite observations, identifying over 20,000 plumes above 100 kg/hr. Oil and gas operations accounted for 54% of these detections, with average emission rates of 307 kg/hr and a persistence rate of 16%. Advanced tasking algorithms increased revisit frequency by up to 30%, allowing for more consistent monitoring of priority assets.
Operational impact has been significant. Automated workflows now deliver emissions data within 24 hours, which is a significant improvement from 2021, when data was delivered in 72 hours, enabling operators to act on leaks faster.
These advancements highlight how near-real-time emissions intelligence can support regulatory compliance, safeguard reputations, and improve operational efficiency. As methane regulations remain a focus worldwide, rapid detection and reliable reporting are becoming essential tools for energy companies to drive accountability and demonstrate responsible operations.
Novel/Additive Information
The novelty of GHGSat’s approach lies in its ability to remotely monitor assets around the globe at any time and deliver facility-level insights. With newer satellites scheduled for launch by the end of 2025, monitoring capacity will expand by 50%, improving revisit rates and global coverage. Beyond methane, new sensor capabilities are extending to CO₂ and offshore monitoring. These advancements demonstrate how satellite intelligence can deliver verified, actionable data to accelerate methane abatement across the energy sector.
Methane abatement has become a top priority for oil and gas operators striving to balance operational efficiency and compliance. This paper presents GHGSat’s satellite-based methane monitoring system, which integrates proprietary satellite tasking and automated data processing to accelerate plume detection and deliver emissions intelligence within hours. The objective is to demonstrate how these innovations have shortened the time between detection and action, enabling operators to reduce emissions, mitigate risks, and enhance accountability across complex operations.
Methods/Process
GHGSat’s methane detection workflow begins with proprietary AI-enhanced satellite tasking guided by a proprietary algorithm that accounts for environmental conditions, emission source persistence, and operator needs. Observations are automatically processed via a cloud computing infrastructure, where an AI plume detector is used to flag observations with potential emissions. Observations are then prioritized by plume rank for further manual processing by human operators. A source-rate retrieval algorithm quantifies emissions and select detections are assessed against historic datasets to refine models and identify trends. This approach has reduced turnaround time, enabling faster detection and timely mitigation in oil and gas operations.
Results/Observations/Conclusions
The integration of AI-driven satellite tasking and automated processing has transformed methane detection at scale. In 2024, GHGSat conducted more than 77,000 satellite observations, identifying over 20,000 plumes above 100 kg/hr. Oil and gas operations accounted for 54% of these detections, with average emission rates of 307 kg/hr and a persistence rate of 16%. Advanced tasking algorithms increased revisit frequency by up to 30%, allowing for more consistent monitoring of priority assets.
Operational impact has been significant. Automated workflows now deliver emissions data within 24 hours, which is a significant improvement from 2021, when data was delivered in 72 hours, enabling operators to act on leaks faster.
These advancements highlight how near-real-time emissions intelligence can support regulatory compliance, safeguard reputations, and improve operational efficiency. As methane regulations remain a focus worldwide, rapid detection and reliable reporting are becoming essential tools for energy companies to drive accountability and demonstrate responsible operations.
Novel/Additive Information
The novelty of GHGSat’s approach lies in its ability to remotely monitor assets around the globe at any time and deliver facility-level insights. With newer satellites scheduled for launch by the end of 2025, monitoring capacity will expand by 50%, improving revisit rates and global coverage. Beyond methane, new sensor capabilities are extending to CO₂ and offshore monitoring. These advancements demonstrate how satellite intelligence can deliver verified, actionable data to accelerate methane abatement across the energy sector.
Across the deserts of MENA, regions like Iraq, Libya, and Oman, upstream oil and gas operations are often set in remote, off-grid locations. Harsh terrain and limited infrastructure make power delivery a constant challenge. For years, diesel generators have been the default. But they’re costly to maintain, difficult to fuel in remote areas, and environmentally damaging.
Traditionally, these locations rely on diesel generators. While reliable, they come with serious limitations, sky-high fuel costs, risky and complex delivery logistics, and a significant environmental footprint. For nations pushing hard on climate commitments and cleaner energy goals, diesel is no longer a viable long-term solution.
That’s where technology-driven innovation steps in. Today’s hybrid systems can combine solar energy, abundant in desert environments, with diesel backup to deliver a far more reliable, sustainable, and cost-effective power model. These systems intelligently shift loads, reduce diesel dependence, and operate with minimal intervention, making them ideal for rugged, remote settings.
GET Global Group’s On Demand Energy Services (ODES) brings this vision to life. ODES is a plug-and-play hybrid power framework, designed to meet the real-world needs of off-grid oilfield operations. Offered under a Power Purchase Agreement (PPA), the model removes all capital expenditure for clients. GET handles the complete lifecycle, from site assessment and design to deployment and remote monitoring.
ODES delivers reliable power, lowers fuel dependency, and makes sustainable operations possible, right at the heart of the desert.
Traditionally, these locations rely on diesel generators. While reliable, they come with serious limitations, sky-high fuel costs, risky and complex delivery logistics, and a significant environmental footprint. For nations pushing hard on climate commitments and cleaner energy goals, diesel is no longer a viable long-term solution.
That’s where technology-driven innovation steps in. Today’s hybrid systems can combine solar energy, abundant in desert environments, with diesel backup to deliver a far more reliable, sustainable, and cost-effective power model. These systems intelligently shift loads, reduce diesel dependence, and operate with minimal intervention, making them ideal for rugged, remote settings.
GET Global Group’s On Demand Energy Services (ODES) brings this vision to life. ODES is a plug-and-play hybrid power framework, designed to meet the real-world needs of off-grid oilfield operations. Offered under a Power Purchase Agreement (PPA), the model removes all capital expenditure for clients. GET handles the complete lifecycle, from site assessment and design to deployment and remote monitoring.
ODES delivers reliable power, lowers fuel dependency, and makes sustainable operations possible, right at the heart of the desert.
On December 11, 2024, Law No. 15.042/2024 was enacted, establishing the Brazilian Greenhouse Gas Emissions Trading Scheme (SBCE). This measure lays the foundation for a regulated carbon market in Brazil.
The law creates a cap-and-trade system, where the government sets emission limits for activities, sources, and facilities, distributes Emission Allowances (Cotas Brasileiras de Emissões – CBEs), and allows trading of these allowances among regulated operators. The SBCE primarily applies to the industrial and energy sectors.
CBEs will be allocated to regulated operators either free of charge or through paid mechanisms within the established emission Cap. If an operator exceeds its allowance, it must purchase additional CBEs from other companies or acquire carbon credits from the voluntary market, provided they are recognized as eligible by the Brazilian government. The allocation of CBEs among regulated sectors will be determined by the National Allocation Plan (NDCs), which aligns with Brazil’s climate commitments under the National Climate Plan (Plano Clima).
The approval of Law No. 15.042/2024 represents a significant step toward fulfilling Brazil’s commitments under the Paris Agreement while maintaining the country’s global market competitiveness. This is particularly relevant given the implementation of the Carbon Border Adjustment Mechanism (CBAM) by the European Union in 2023.
The law broadly defines key aspects of the SBCE, including:
• Principles and governance structure;
The National Allocation Plan will determine emission limits and the allocation of allowances across sectors and regulated entities. It will be developed by the SBCE’s managing authority (to be appointed by the federal government) with the support of the Permanent Technical Group, a consultative body including representatives from the government, industry, academia, and civil society. The plan must be approved by the Interministerial Committee on Climate Change (CIM).
The SBCE’s guiding principles include compatibility with Brazil’s Nationally Determined Contribution (NDC), transparency, predictability, economic competitiveness, and cost-effective emissions reduction. Allocation methodologies will consider technological advancements, historical efficiency gains, and marginal abatement costs.
The National Allocation Plan will follow a gradual approach across commitment periods, ensuring regulatory predictability. It must be approved at least 12 months before its implementation, with estimated emission limits projected for two subsequent periods.
The law creates a cap-and-trade system, where the government sets emission limits for activities, sources, and facilities, distributes Emission Allowances (Cotas Brasileiras de Emissões – CBEs), and allows trading of these allowances among regulated operators. The SBCE primarily applies to the industrial and energy sectors.
CBEs will be allocated to regulated operators either free of charge or through paid mechanisms within the established emission Cap. If an operator exceeds its allowance, it must purchase additional CBEs from other companies or acquire carbon credits from the voluntary market, provided they are recognized as eligible by the Brazilian government. The allocation of CBEs among regulated sectors will be determined by the National Allocation Plan (NDCs), which aligns with Brazil’s climate commitments under the National Climate Plan (Plano Clima).
The approval of Law No. 15.042/2024 represents a significant step toward fulfilling Brazil’s commitments under the Paris Agreement while maintaining the country’s global market competitiveness. This is particularly relevant given the implementation of the Carbon Border Adjustment Mechanism (CBAM) by the European Union in 2023.
The law broadly defines key aspects of the SBCE, including:
• Principles and governance structure;
- Legal and tax status of emission assets;
- Technology systems supporting the market;
- Obligations for regulated entities (measurement, reporting, verification, and compliance);
- Enforcement measures and penalties;
- Guidelines for integrating the SBCE with voluntary carbon markets.
The National Allocation Plan will determine emission limits and the allocation of allowances across sectors and regulated entities. It will be developed by the SBCE’s managing authority (to be appointed by the federal government) with the support of the Permanent Technical Group, a consultative body including representatives from the government, industry, academia, and civil society. The plan must be approved by the Interministerial Committee on Climate Change (CIM).
The SBCE’s guiding principles include compatibility with Brazil’s Nationally Determined Contribution (NDC), transparency, predictability, economic competitiveness, and cost-effective emissions reduction. Allocation methodologies will consider technological advancements, historical efficiency gains, and marginal abatement costs.
The National Allocation Plan will follow a gradual approach across commitment periods, ensuring regulatory predictability. It must be approved at least 12 months before its implementation, with estimated emission limits projected for two subsequent periods.
Injecting CO₂ into geological formations offers a promising route to store large‑scale emissions, but monitoring CO₂ flooding in heterogeneous carbonate reservoirs remains difficult yet vital for ensuring storage security and preventing leakage. This study presents an integrated workflow that combines high‑resolution outcrop‑based reservoir modeling, multi‑scenario CO₂ flood simulations, and 4D seismic analysis to track the CO₂ saturation front and evaluate reservoir performance.
Carbonate outcrops serve as analogs for subsurface reservoirs. Detailed mapping of lithologic layers and facies enabled the construction of a 4 × 6 km three‑dimensional sector model equipped with flank injectors and crestal water producers. The model incorporates porosity, permeability, velocity, and density data collected from published literature and in‑house (KAUST) laboratory measurements. Supercritical CO₂ flood simulations were run under two end‑member boundary conditions: (1) closed boundaries representing an isolated system with no connected aquifer; and (2) open boundaries allowing fluid flow outside the model. Elastic properties were updated iteratively over a 50‑year injection period to generate inputs for time‐lapse (4D) seismic modeling. Seismic attribute analysis was then employed to monitor the advancing CO₂ front and detect zones of partial fluid saturation.
The outcrop exhibits meter‑scale lateral facies heterogeneity, with alternating limestone and dolomite beds. Inspired by these field observations, we generated the reservoir model and incorporated subsurface petrophysical data into it. In closed‑boundary scenarios, stromatoporoid‐rich and grainy facies dominate flow pathways, producing an uneven CO₂ front; open boundaries yield a more uniform advance. After 50 years of injection the CO₂ reaches producer wells faster under closed conditions due to stronger injector–producer pressure gradients. Temporal changes in CO₂ saturation alter P- and S-wave velocities, generating amplitude variations in the 4D seismic cubes. RMS amplitudes extracted from the top of the reservoir delineate saturation patterns even at low concentrations; however, small amplitude anomalies are highly susceptible to noise.
Overall this work delivers a realistic high‑resolution carbonate reservoir model together with a comprehensive workflow that illuminates supercritical CO₂ migration pathways. By integrating field analog observations, laboratory measurements, numerical modeling, and seismic simulation we capture multi‑scale heterogeneities critical for monitoring outcomes. The presented approach can serve as a predictive tool for calibrating field‐scale observations during CO₂ flooding projects and as an assurance framework for carbon sequestration initiatives.
Co-author/s:
Billal Aslam, Student, King Abdullah University of Science and Technology.
Gaurav Gairola, Geologist, King Abdullah University of Science and Technology.
Carbonate outcrops serve as analogs for subsurface reservoirs. Detailed mapping of lithologic layers and facies enabled the construction of a 4 × 6 km three‑dimensional sector model equipped with flank injectors and crestal water producers. The model incorporates porosity, permeability, velocity, and density data collected from published literature and in‑house (KAUST) laboratory measurements. Supercritical CO₂ flood simulations were run under two end‑member boundary conditions: (1) closed boundaries representing an isolated system with no connected aquifer; and (2) open boundaries allowing fluid flow outside the model. Elastic properties were updated iteratively over a 50‑year injection period to generate inputs for time‐lapse (4D) seismic modeling. Seismic attribute analysis was then employed to monitor the advancing CO₂ front and detect zones of partial fluid saturation.
The outcrop exhibits meter‑scale lateral facies heterogeneity, with alternating limestone and dolomite beds. Inspired by these field observations, we generated the reservoir model and incorporated subsurface petrophysical data into it. In closed‑boundary scenarios, stromatoporoid‐rich and grainy facies dominate flow pathways, producing an uneven CO₂ front; open boundaries yield a more uniform advance. After 50 years of injection the CO₂ reaches producer wells faster under closed conditions due to stronger injector–producer pressure gradients. Temporal changes in CO₂ saturation alter P- and S-wave velocities, generating amplitude variations in the 4D seismic cubes. RMS amplitudes extracted from the top of the reservoir delineate saturation patterns even at low concentrations; however, small amplitude anomalies are highly susceptible to noise.
Overall this work delivers a realistic high‑resolution carbonate reservoir model together with a comprehensive workflow that illuminates supercritical CO₂ migration pathways. By integrating field analog observations, laboratory measurements, numerical modeling, and seismic simulation we capture multi‑scale heterogeneities critical for monitoring outcomes. The presented approach can serve as a predictive tool for calibrating field‐scale observations during CO₂ flooding projects and as an assurance framework for carbon sequestration initiatives.
Co-author/s:
Billal Aslam, Student, King Abdullah University of Science and Technology.
Gaurav Gairola, Geologist, King Abdullah University of Science and Technology.
Since emergence of the need for carbon capture, solvent based CO2 absorption processes encompassing conventional trayed columns have been dominating. However, these CO2 absorption columns have major limitations of tall size (20 to 30 meters) and huge weight. Main reason for such huge height is due to poor gas-liquid mass transfer efficiency which is governed by gravity.
Hindustan Petroleum Corporation Limited (HPCL), India has developed a novel HiGAS technology for overcoming these limitations. With this breakthrough technology, height of absorption columns can be reduced significantly by 10 times. HiGAS technology uses a Rotating Packed Bed (RPB) made of high surface area packing elements and induces centrifugal forces that are over 100 times of gravity. This reduces the Height Equivalent to Theoretical Plates (HETP) by 50-100 times, resulting in multitude level intensification of mass transfer efficiency and small unit size. First-of-its-kind commercial HP-HiGAS unit has been successfully implemented in HPCL Refinery, India for refinery fuel gas sweetening. This 2.5 meters HIGAS unit designed for removal of acid gas from 4 wt% to 100 ppm has replaced the existing 23 meters absorption column having 28 trays thus resulting in a significant size reduction of 10 times.
HPCL is now setting-up a commercial scale carbon capture unit for producing blue hydrogen based on HP-HiGAS technology. This unit with 24 KTPA CO2 capture capacity is being set-up at the Hydrogen Generation Unit (HGU) in HPCL refinery at an investment of 2 million USD.
HP-HiGAS technology, backed by its significant benefits of low size / foot print, low capital cost and improved safety, is the next generation revolution in carbon capture technologies as it perfectly suits all the CO2 capture requirements. Tapping the huge potential of HiGAS technology worldwide for carbon capture, would create a dramatic impact across the globe.
Hindustan Petroleum Corporation Limited (HPCL), India has developed a novel HiGAS technology for overcoming these limitations. With this breakthrough technology, height of absorption columns can be reduced significantly by 10 times. HiGAS technology uses a Rotating Packed Bed (RPB) made of high surface area packing elements and induces centrifugal forces that are over 100 times of gravity. This reduces the Height Equivalent to Theoretical Plates (HETP) by 50-100 times, resulting in multitude level intensification of mass transfer efficiency and small unit size. First-of-its-kind commercial HP-HiGAS unit has been successfully implemented in HPCL Refinery, India for refinery fuel gas sweetening. This 2.5 meters HIGAS unit designed for removal of acid gas from 4 wt% to 100 ppm has replaced the existing 23 meters absorption column having 28 trays thus resulting in a significant size reduction of 10 times.
HPCL is now setting-up a commercial scale carbon capture unit for producing blue hydrogen based on HP-HiGAS technology. This unit with 24 KTPA CO2 capture capacity is being set-up at the Hydrogen Generation Unit (HGU) in HPCL refinery at an investment of 2 million USD.
HP-HiGAS technology, backed by its significant benefits of low size / foot print, low capital cost and improved safety, is the next generation revolution in carbon capture technologies as it perfectly suits all the CO2 capture requirements. Tapping the huge potential of HiGAS technology worldwide for carbon capture, would create a dramatic impact across the globe.
This research project explores the potential of Late Oligocene basalts in southwestern Saudi Arabia for carbon capture and storage, with a focus on their suitability for CO₂ mineralization. The study builds on the promise of basaltic formations shown in Iceland, where the unique combination of reactive rocks and an active tectonic setting enables the permanent sequestration of CO₂. To investigate this potential, the research team used a combination of field observations, structural mapping, seismic data analysis, drilling data, satellite imagery analysis, and flow tests to characterize the regional faults, fracture networks, and fluid flow paths in the basalt formations. The results of this study identified NE-dipping faults as the primary target for future CO₂ injection and mineralization efforts, with drilling campaigns and injection tests demonstrating high flow rates and broad matrix permeability. Additionally, seismic surveys and potential field data provided valuable insights into the subsurface architecture and fault characteristics, which are consistent with worldwide examples of inner Seaward Dipping Reflectors found in magma-rich rifted margins. The study marks an important achievement as the first successful CO₂ injection into a non-tectonically active system, highlighting the vast potential of inner SDRs as targets for permanent CO₂ mineralization on a global scale. The findings of this research provide invaluable insights for geological and geophysical assessments necessary for accurate subsurface characterization for CO₂ sequestration initiatives, and have significant implications for the development of CCS technologies and the reduction of greenhouse gas emissions. Overall, the study contributes to the advancement of CCS research and identifies suitable locations for CO₂ storage and mineralization, with important implications for the future of CCS and the potential for basaltic formations to play a key role in mitigating climate change.
Co-author/s:
Syed Shah, Geological Specialist, Saudi Aramco.
Julio Almeida De Carvalho, Geophysical Consultant, Saudi Aramco.
Co-author/s:
Syed Shah, Geological Specialist, Saudi Aramco.
Julio Almeida De Carvalho, Geophysical Consultant, Saudi Aramco.
Global warming, high energy consumption, resource depletion, and excessive waste generation are critical challenges facing our planet. Carbon Capture, Utilization, and Storage (CCUS) facilities are designed to mitigate these impacts. These facilities not only capture carbon and convert it into valuable products but also aim to minimize energy consumption and reduce carbon footprints worldwide. Key performance indicators of their effectiveness include reductions in energy consumption, efficient resource utilization, minimal waste generation, and the CO2 footprint per kilogram or ton of product. If multiple CCUS facilities are developed based on the same principles but exhibit high carbon and energy footprints, their overall effectiveness will not contribute positively to global sustainability end with either same or higher. We initiated with the same innovative approach. The existing CCUS plant processes raw CO2 by-products from glycol, converting them into food-grade CO2. The plant is designed to compress and purify approximately 1,500 tons per day of raw CO2 and is capable of producing both gaseous and liquid food-grade CO2. This significant innovation has presented numerous challenges, ranging from conceptual design to sustainable operation to minimize waste and energy. Issues such as design simulation, engineering challenges, design concepts, frequent shutdowns, leakages, equipment failures, unit damages, and prolonged plant outages have posed threats to process safety and EHSS. These challenges have resulted in substantial production losses, high repair costs, significant replacement and engineering expenses, and extended production interruptions. However, innovative solutions have resolved numerous engineering challenges, enabling the unit to operate with high efficiency, maximum resource utilization, and minimal waste generation. The facility was initially designed with a high carbon and energy footprint; however, after implementing these improvements, the footprint has been drastically reduced to a minimum. Our approach not only resolves all plant issues, but also enables further optimization and utilization, addresses potential problems, and reduces energy footprints. A smart solution is required to enhance CO2 liquid production, recycle and reuse waste with minimal energy use, and minimize sustainability impacts while simultaneously increasing production. Furthermore, this solution should not adversely affect the process or unit operations and should require minimal modifications. Positive impacts of CO2 production in sustainability efforts by United and Sabic. Reduction in GHG emissions by over 20%, an energy reduction exceeding 11%, a water usage reduction surpassing 11%, and an improvement in material efficiency of more than 59.1%. Through further innovative initiatives, waste recycling and water consumption have been reduced by over 97%, converting waste into useful water. Energy optimization has led to input reductions of more than 75%, and 99.9% of exhausted CO2 streams are recycled and reused. Reducing CO2 emissions is a key objective of SABIC's sustainability strategy. It is estimated that more than 500,000 tons of CO2 emissions will be saved annually, generating over 10 million dollars in revenue each year from the sale of CO2 as a valuable product.
Co-author/s:
Abdullah Al-tamimi, Process Manager, Sabic.
Co-author/s:
Abdullah Al-tamimi, Process Manager, Sabic.
CO2 capture, utilization, and storage (CCUS) integrated with enhanced oil recovery (EOR) is a strategic approach for large-scale carbon mitigation while optimizing hydrocarbon recovery. This study presents a comprehensive technical and economic assessment of CCUS-EOR potential in Iran, focusing on reservoir evaluation to identify sites suitable for industrial-scale deployment.
A detailed technical framework was developed to assess reservoir engineering parameters, including depth, thickness, dip angle, porosity, permeability, saturation, heterogeneity and lithology. Fluid properties, such as pressure, temperature, viscosity, API gravity, composition, compositional miscibility with CO2, and water cut, were considered to evaluate EOR potential. Finally, the framework incorporated storage capacity to ensure sustainable and efficient CCUS-EOR implementation.
In parallel, a comprehensive economic assessment framework was established, integrating operational feasibility and CO2 supply from industrial and power-generation sources, including both available volumes and the distance of these sources from the reservoirs. The analysis accounts for the costs of CO₂ injection and storage while emphasizing that the primary financial benefit arises from enhanced oil recovery, with additional potential value from carbon credits or emission trading where applicable. This framework allows a realistic evaluation of both the investment requirements and the expected returns of CCUS-EOR projects.
A structured Simultaneous Evaluation of Criteria and Alternatives (SECA)–Additive Ratio Assessment System (ARAS) methodology was applied to combine technical and economic indicators, generating a prioritized ranking of candidate reservoirs. This approach allows systematic identification of sites with maximum carbon mitigation potential while maintaining economic viability. The methodology also accommodates sensitivity analyses to evaluate the impact of key parameters, such as fluid & reservoir properties, CO2 supply fluctuations, and operational cost variations, enhancing the robustness of site selection and prioritization. Application of this framework highlights several Iranian basins, as particularly suitable for CCUS-EOR projects due to favorable geological and operational characteristics.
By integrating engineering, geological, and economic criteria within a unified evaluation framework, this study provides a practical tool for policymakers and industry stakeholders. The proposed approach supports sustainable development of Iran’s oil and gas sector, enabling large-scale carbon reduction initiatives while maximizing hydrocarbon recovery, and establishes a rigorous foundation for informed decision-making in future CCUS-EOR planning and implementation.
Keywords: CO2 Capture and Storage, Enhance Oil Recovery, Technical Assessment, Economic Analysis, SECA, ARAS.
Co-author/s:
Dr. Shahin Kord, Associate Professor, Petroleum University of Technology Ahwaz.
Dr. Nasser Faraz, Head of Process Projects, National Iranian South Oil Company (NISOC).
A detailed technical framework was developed to assess reservoir engineering parameters, including depth, thickness, dip angle, porosity, permeability, saturation, heterogeneity and lithology. Fluid properties, such as pressure, temperature, viscosity, API gravity, composition, compositional miscibility with CO2, and water cut, were considered to evaluate EOR potential. Finally, the framework incorporated storage capacity to ensure sustainable and efficient CCUS-EOR implementation.
In parallel, a comprehensive economic assessment framework was established, integrating operational feasibility and CO2 supply from industrial and power-generation sources, including both available volumes and the distance of these sources from the reservoirs. The analysis accounts for the costs of CO₂ injection and storage while emphasizing that the primary financial benefit arises from enhanced oil recovery, with additional potential value from carbon credits or emission trading where applicable. This framework allows a realistic evaluation of both the investment requirements and the expected returns of CCUS-EOR projects.
A structured Simultaneous Evaluation of Criteria and Alternatives (SECA)–Additive Ratio Assessment System (ARAS) methodology was applied to combine technical and economic indicators, generating a prioritized ranking of candidate reservoirs. This approach allows systematic identification of sites with maximum carbon mitigation potential while maintaining economic viability. The methodology also accommodates sensitivity analyses to evaluate the impact of key parameters, such as fluid & reservoir properties, CO2 supply fluctuations, and operational cost variations, enhancing the robustness of site selection and prioritization. Application of this framework highlights several Iranian basins, as particularly suitable for CCUS-EOR projects due to favorable geological and operational characteristics.
By integrating engineering, geological, and economic criteria within a unified evaluation framework, this study provides a practical tool for policymakers and industry stakeholders. The proposed approach supports sustainable development of Iran’s oil and gas sector, enabling large-scale carbon reduction initiatives while maximizing hydrocarbon recovery, and establishes a rigorous foundation for informed decision-making in future CCUS-EOR planning and implementation.
Keywords: CO2 Capture and Storage, Enhance Oil Recovery, Technical Assessment, Economic Analysis, SECA, ARAS.
Co-author/s:
Dr. Shahin Kord, Associate Professor, Petroleum University of Technology Ahwaz.
Dr. Nasser Faraz, Head of Process Projects, National Iranian South Oil Company (NISOC).
The Diesel Hydrotreater Unit (DHT) plays a crucial role in producing high-quality diesel by removing impurities and improving feedstock properties. As sustainability and cost-effectiveness become priorities, refineries are actively exploring strategies to enhance energy efficiency and minimize carbon emissions.
The DHT at HPCL (Hindustan Petroleum Corporation Limited) is uniquely complexed as an Integrated VGO & Diesel Hydrotreater Unit, processing both Vacuum Gas Oil (VGO) and diesel in separate reactors. There are two parallel trains of operation, one is having Vacuum Gas Oil as feed and the other one having Raw Diesel as feed. This integration increases operational intensity and energy consumption, making efficiency improvements particularly impactful.
This paper presents a set of impactful operational optimization initiatives undertaken in the Integrated Diesel Hydrotreater (DHT) unit, aimed at improving energy efficiency, reducing operating costs, and minimizing environmental impact. Key measures included hot feed maximization to reduce cold feed dependency, and the successful shutdown of one furnace through strategic operational adjustments without compromising throughput. Additional steps such as gas-to-oil ratio optimization, significant flare reduction, and stripping steam optimization were implemented to further enhance system efficiency. Export naphtha reduction was achieved by optimizing fractionator overhead conditions, while operational changes in the Sour Water Stripper (SWS) and Fractionator led to a substantial reduction in steam consumption—by nearly 80 tons per day.
Importantly, these improvements were realized without incurring any additional capital expenditure, making them highly cost-effective and immediately impactful. The absence of investment requirements enhances the attractiveness of these measures, especially from an operational sustainability standpoint. While this abstract highlights some of the most significant actions taken, it is important to note that several other optimizations were also implemented across the unit, each contributing cumulatively to the enhanced performance, energy conservation, and environmental responsibility of the DHT.
By implementing these changes—without any capital investment in new equipment or pipelines— savings of over 6,000 SRFT and CO2 reduction of around 19000 kg/hr were achieved annually. Beyond cost reduction, these initiatives align with broader sustainability goals by minimizing environmental impact while maintaining high operational performance.
In conclusion, optimizing energy usage in an Integrated DHT unit through strategic operational changes not only strengthens cost leadership but also advances sustainability in refining. These initiatives highlight the importance of continuous improvement and innovation in driving more efficient and environmentally responsible refinery operations.
The DHT at HPCL (Hindustan Petroleum Corporation Limited) is uniquely complexed as an Integrated VGO & Diesel Hydrotreater Unit, processing both Vacuum Gas Oil (VGO) and diesel in separate reactors. There are two parallel trains of operation, one is having Vacuum Gas Oil as feed and the other one having Raw Diesel as feed. This integration increases operational intensity and energy consumption, making efficiency improvements particularly impactful.
This paper presents a set of impactful operational optimization initiatives undertaken in the Integrated Diesel Hydrotreater (DHT) unit, aimed at improving energy efficiency, reducing operating costs, and minimizing environmental impact. Key measures included hot feed maximization to reduce cold feed dependency, and the successful shutdown of one furnace through strategic operational adjustments without compromising throughput. Additional steps such as gas-to-oil ratio optimization, significant flare reduction, and stripping steam optimization were implemented to further enhance system efficiency. Export naphtha reduction was achieved by optimizing fractionator overhead conditions, while operational changes in the Sour Water Stripper (SWS) and Fractionator led to a substantial reduction in steam consumption—by nearly 80 tons per day.
Importantly, these improvements were realized without incurring any additional capital expenditure, making them highly cost-effective and immediately impactful. The absence of investment requirements enhances the attractiveness of these measures, especially from an operational sustainability standpoint. While this abstract highlights some of the most significant actions taken, it is important to note that several other optimizations were also implemented across the unit, each contributing cumulatively to the enhanced performance, energy conservation, and environmental responsibility of the DHT.
By implementing these changes—without any capital investment in new equipment or pipelines— savings of over 6,000 SRFT and CO2 reduction of around 19000 kg/hr were achieved annually. Beyond cost reduction, these initiatives align with broader sustainability goals by minimizing environmental impact while maintaining high operational performance.
In conclusion, optimizing energy usage in an Integrated DHT unit through strategic operational changes not only strengthens cost leadership but also advances sustainability in refining. These initiatives highlight the importance of continuous improvement and innovation in driving more efficient and environmentally responsible refinery operations.
Kevin Birn
Chair
Head of Carbon Research & The Center of Emissions Excellence
S&P Global Commodity Insights
Across the deserts of MENA, regions like Iraq, Libya, and Oman, upstream oil and gas operations are often set in remote, off-grid locations. Harsh terrain and limited infrastructure make power delivery a constant challenge. For years, diesel generators have been the default. But they’re costly to maintain, difficult to fuel in remote areas, and environmentally damaging.
Traditionally, these locations rely on diesel generators. While reliable, they come with serious limitations, sky-high fuel costs, risky and complex delivery logistics, and a significant environmental footprint. For nations pushing hard on climate commitments and cleaner energy goals, diesel is no longer a viable long-term solution.
That’s where technology-driven innovation steps in. Today’s hybrid systems can combine solar energy, abundant in desert environments, with diesel backup to deliver a far more reliable, sustainable, and cost-effective power model. These systems intelligently shift loads, reduce diesel dependence, and operate with minimal intervention, making them ideal for rugged, remote settings.
GET Global Group’s On Demand Energy Services (ODES) brings this vision to life. ODES is a plug-and-play hybrid power framework, designed to meet the real-world needs of off-grid oilfield operations. Offered under a Power Purchase Agreement (PPA), the model removes all capital expenditure for clients. GET handles the complete lifecycle, from site assessment and design to deployment and remote monitoring.
ODES delivers reliable power, lowers fuel dependency, and makes sustainable operations possible, right at the heart of the desert.
Traditionally, these locations rely on diesel generators. While reliable, they come with serious limitations, sky-high fuel costs, risky and complex delivery logistics, and a significant environmental footprint. For nations pushing hard on climate commitments and cleaner energy goals, diesel is no longer a viable long-term solution.
That’s where technology-driven innovation steps in. Today’s hybrid systems can combine solar energy, abundant in desert environments, with diesel backup to deliver a far more reliable, sustainable, and cost-effective power model. These systems intelligently shift loads, reduce diesel dependence, and operate with minimal intervention, making them ideal for rugged, remote settings.
GET Global Group’s On Demand Energy Services (ODES) brings this vision to life. ODES is a plug-and-play hybrid power framework, designed to meet the real-world needs of off-grid oilfield operations. Offered under a Power Purchase Agreement (PPA), the model removes all capital expenditure for clients. GET handles the complete lifecycle, from site assessment and design to deployment and remote monitoring.
ODES delivers reliable power, lowers fuel dependency, and makes sustainable operations possible, right at the heart of the desert.
Objective/Scope
Methane abatement has become a top priority for oil and gas operators striving to balance operational efficiency and compliance. This paper presents GHGSat’s satellite-based methane monitoring system, which integrates proprietary satellite tasking and automated data processing to accelerate plume detection and deliver emissions intelligence within hours. The objective is to demonstrate how these innovations have shortened the time between detection and action, enabling operators to reduce emissions, mitigate risks, and enhance accountability across complex operations.
Methods/Process
GHGSat’s methane detection workflow begins with proprietary AI-enhanced satellite tasking guided by a proprietary algorithm that accounts for environmental conditions, emission source persistence, and operator needs. Observations are automatically processed via a cloud computing infrastructure, where an AI plume detector is used to flag observations with potential emissions. Observations are then prioritized by plume rank for further manual processing by human operators. A source-rate retrieval algorithm quantifies emissions and select detections are assessed against historic datasets to refine models and identify trends. This approach has reduced turnaround time, enabling faster detection and timely mitigation in oil and gas operations.
Results/Observations/Conclusions
The integration of AI-driven satellite tasking and automated processing has transformed methane detection at scale. In 2024, GHGSat conducted more than 77,000 satellite observations, identifying over 20,000 plumes above 100 kg/hr. Oil and gas operations accounted for 54% of these detections, with average emission rates of 307 kg/hr and a persistence rate of 16%. Advanced tasking algorithms increased revisit frequency by up to 30%, allowing for more consistent monitoring of priority assets.
Operational impact has been significant. Automated workflows now deliver emissions data within 24 hours, which is a significant improvement from 2021, when data was delivered in 72 hours, enabling operators to act on leaks faster.
These advancements highlight how near-real-time emissions intelligence can support regulatory compliance, safeguard reputations, and improve operational efficiency. As methane regulations remain a focus worldwide, rapid detection and reliable reporting are becoming essential tools for energy companies to drive accountability and demonstrate responsible operations.
Novel/Additive Information
The novelty of GHGSat’s approach lies in its ability to remotely monitor assets around the globe at any time and deliver facility-level insights. With newer satellites scheduled for launch by the end of 2025, monitoring capacity will expand by 50%, improving revisit rates and global coverage. Beyond methane, new sensor capabilities are extending to CO₂ and offshore monitoring. These advancements demonstrate how satellite intelligence can deliver verified, actionable data to accelerate methane abatement across the energy sector.
Methane abatement has become a top priority for oil and gas operators striving to balance operational efficiency and compliance. This paper presents GHGSat’s satellite-based methane monitoring system, which integrates proprietary satellite tasking and automated data processing to accelerate plume detection and deliver emissions intelligence within hours. The objective is to demonstrate how these innovations have shortened the time between detection and action, enabling operators to reduce emissions, mitigate risks, and enhance accountability across complex operations.
Methods/Process
GHGSat’s methane detection workflow begins with proprietary AI-enhanced satellite tasking guided by a proprietary algorithm that accounts for environmental conditions, emission source persistence, and operator needs. Observations are automatically processed via a cloud computing infrastructure, where an AI plume detector is used to flag observations with potential emissions. Observations are then prioritized by plume rank for further manual processing by human operators. A source-rate retrieval algorithm quantifies emissions and select detections are assessed against historic datasets to refine models and identify trends. This approach has reduced turnaround time, enabling faster detection and timely mitigation in oil and gas operations.
Results/Observations/Conclusions
The integration of AI-driven satellite tasking and automated processing has transformed methane detection at scale. In 2024, GHGSat conducted more than 77,000 satellite observations, identifying over 20,000 plumes above 100 kg/hr. Oil and gas operations accounted for 54% of these detections, with average emission rates of 307 kg/hr and a persistence rate of 16%. Advanced tasking algorithms increased revisit frequency by up to 30%, allowing for more consistent monitoring of priority assets.
Operational impact has been significant. Automated workflows now deliver emissions data within 24 hours, which is a significant improvement from 2021, when data was delivered in 72 hours, enabling operators to act on leaks faster.
These advancements highlight how near-real-time emissions intelligence can support regulatory compliance, safeguard reputations, and improve operational efficiency. As methane regulations remain a focus worldwide, rapid detection and reliable reporting are becoming essential tools for energy companies to drive accountability and demonstrate responsible operations.
Novel/Additive Information
The novelty of GHGSat’s approach lies in its ability to remotely monitor assets around the globe at any time and deliver facility-level insights. With newer satellites scheduled for launch by the end of 2025, monitoring capacity will expand by 50%, improving revisit rates and global coverage. Beyond methane, new sensor capabilities are extending to CO₂ and offshore monitoring. These advancements demonstrate how satellite intelligence can deliver verified, actionable data to accelerate methane abatement across the energy sector.
Global warming, high energy consumption, resource depletion, and excessive waste generation are critical challenges facing our planet. Carbon Capture, Utilization, and Storage (CCUS) facilities are designed to mitigate these impacts. These facilities not only capture carbon and convert it into valuable products but also aim to minimize energy consumption and reduce carbon footprints worldwide. Key performance indicators of their effectiveness include reductions in energy consumption, efficient resource utilization, minimal waste generation, and the CO2 footprint per kilogram or ton of product. If multiple CCUS facilities are developed based on the same principles but exhibit high carbon and energy footprints, their overall effectiveness will not contribute positively to global sustainability end with either same or higher. We initiated with the same innovative approach. The existing CCUS plant processes raw CO2 by-products from glycol, converting them into food-grade CO2. The plant is designed to compress and purify approximately 1,500 tons per day of raw CO2 and is capable of producing both gaseous and liquid food-grade CO2. This significant innovation has presented numerous challenges, ranging from conceptual design to sustainable operation to minimize waste and energy. Issues such as design simulation, engineering challenges, design concepts, frequent shutdowns, leakages, equipment failures, unit damages, and prolonged plant outages have posed threats to process safety and EHSS. These challenges have resulted in substantial production losses, high repair costs, significant replacement and engineering expenses, and extended production interruptions. However, innovative solutions have resolved numerous engineering challenges, enabling the unit to operate with high efficiency, maximum resource utilization, and minimal waste generation. The facility was initially designed with a high carbon and energy footprint; however, after implementing these improvements, the footprint has been drastically reduced to a minimum. Our approach not only resolves all plant issues, but also enables further optimization and utilization, addresses potential problems, and reduces energy footprints. A smart solution is required to enhance CO2 liquid production, recycle and reuse waste with minimal energy use, and minimize sustainability impacts while simultaneously increasing production. Furthermore, this solution should not adversely affect the process or unit operations and should require minimal modifications. Positive impacts of CO2 production in sustainability efforts by United and Sabic. Reduction in GHG emissions by over 20%, an energy reduction exceeding 11%, a water usage reduction surpassing 11%, and an improvement in material efficiency of more than 59.1%. Through further innovative initiatives, waste recycling and water consumption have been reduced by over 97%, converting waste into useful water. Energy optimization has led to input reductions of more than 75%, and 99.9% of exhausted CO2 streams are recycled and reused. Reducing CO2 emissions is a key objective of SABIC's sustainability strategy. It is estimated that more than 500,000 tons of CO2 emissions will be saved annually, generating over 10 million dollars in revenue each year from the sale of CO2 as a valuable product.
Co-author/s:
Abdullah Al-tamimi, Process Manager, Sabic.
Co-author/s:
Abdullah Al-tamimi, Process Manager, Sabic.
This research project explores the potential of Late Oligocene basalts in southwestern Saudi Arabia for carbon capture and storage, with a focus on their suitability for CO₂ mineralization. The study builds on the promise of basaltic formations shown in Iceland, where the unique combination of reactive rocks and an active tectonic setting enables the permanent sequestration of CO₂. To investigate this potential, the research team used a combination of field observations, structural mapping, seismic data analysis, drilling data, satellite imagery analysis, and flow tests to characterize the regional faults, fracture networks, and fluid flow paths in the basalt formations. The results of this study identified NE-dipping faults as the primary target for future CO₂ injection and mineralization efforts, with drilling campaigns and injection tests demonstrating high flow rates and broad matrix permeability. Additionally, seismic surveys and potential field data provided valuable insights into the subsurface architecture and fault characteristics, which are consistent with worldwide examples of inner Seaward Dipping Reflectors found in magma-rich rifted margins. The study marks an important achievement as the first successful CO₂ injection into a non-tectonically active system, highlighting the vast potential of inner SDRs as targets for permanent CO₂ mineralization on a global scale. The findings of this research provide invaluable insights for geological and geophysical assessments necessary for accurate subsurface characterization for CO₂ sequestration initiatives, and have significant implications for the development of CCS technologies and the reduction of greenhouse gas emissions. Overall, the study contributes to the advancement of CCS research and identifies suitable locations for CO₂ storage and mineralization, with important implications for the future of CCS and the potential for basaltic formations to play a key role in mitigating climate change.
Co-author/s:
Syed Shah, Geological Specialist, Saudi Aramco.
Julio Almeida De Carvalho, Geophysical Consultant, Saudi Aramco.
Co-author/s:
Syed Shah, Geological Specialist, Saudi Aramco.
Julio Almeida De Carvalho, Geophysical Consultant, Saudi Aramco.
Milad Ghafoori
Speaker
Petroleum Engineer
National Iranian South Oil Company (NISOC), Ahwaz, Iran
CO2 capture, utilization, and storage (CCUS) integrated with enhanced oil recovery (EOR) is a strategic approach for large-scale carbon mitigation while optimizing hydrocarbon recovery. This study presents a comprehensive technical and economic assessment of CCUS-EOR potential in Iran, focusing on reservoir evaluation to identify sites suitable for industrial-scale deployment.
A detailed technical framework was developed to assess reservoir engineering parameters, including depth, thickness, dip angle, porosity, permeability, saturation, heterogeneity and lithology. Fluid properties, such as pressure, temperature, viscosity, API gravity, composition, compositional miscibility with CO2, and water cut, were considered to evaluate EOR potential. Finally, the framework incorporated storage capacity to ensure sustainable and efficient CCUS-EOR implementation.
In parallel, a comprehensive economic assessment framework was established, integrating operational feasibility and CO2 supply from industrial and power-generation sources, including both available volumes and the distance of these sources from the reservoirs. The analysis accounts for the costs of CO₂ injection and storage while emphasizing that the primary financial benefit arises from enhanced oil recovery, with additional potential value from carbon credits or emission trading where applicable. This framework allows a realistic evaluation of both the investment requirements and the expected returns of CCUS-EOR projects.
A structured Simultaneous Evaluation of Criteria and Alternatives (SECA)–Additive Ratio Assessment System (ARAS) methodology was applied to combine technical and economic indicators, generating a prioritized ranking of candidate reservoirs. This approach allows systematic identification of sites with maximum carbon mitigation potential while maintaining economic viability. The methodology also accommodates sensitivity analyses to evaluate the impact of key parameters, such as fluid & reservoir properties, CO2 supply fluctuations, and operational cost variations, enhancing the robustness of site selection and prioritization. Application of this framework highlights several Iranian basins, as particularly suitable for CCUS-EOR projects due to favorable geological and operational characteristics.
By integrating engineering, geological, and economic criteria within a unified evaluation framework, this study provides a practical tool for policymakers and industry stakeholders. The proposed approach supports sustainable development of Iran’s oil and gas sector, enabling large-scale carbon reduction initiatives while maximizing hydrocarbon recovery, and establishes a rigorous foundation for informed decision-making in future CCUS-EOR planning and implementation.
Keywords: CO2 Capture and Storage, Enhance Oil Recovery, Technical Assessment, Economic Analysis, SECA, ARAS.
Co-author/s:
Dr. Shahin Kord, Associate Professor, Petroleum University of Technology Ahwaz.
Dr. Nasser Faraz, Head of Process Projects, National Iranian South Oil Company (NISOC).
A detailed technical framework was developed to assess reservoir engineering parameters, including depth, thickness, dip angle, porosity, permeability, saturation, heterogeneity and lithology. Fluid properties, such as pressure, temperature, viscosity, API gravity, composition, compositional miscibility with CO2, and water cut, were considered to evaluate EOR potential. Finally, the framework incorporated storage capacity to ensure sustainable and efficient CCUS-EOR implementation.
In parallel, a comprehensive economic assessment framework was established, integrating operational feasibility and CO2 supply from industrial and power-generation sources, including both available volumes and the distance of these sources from the reservoirs. The analysis accounts for the costs of CO₂ injection and storage while emphasizing that the primary financial benefit arises from enhanced oil recovery, with additional potential value from carbon credits or emission trading where applicable. This framework allows a realistic evaluation of both the investment requirements and the expected returns of CCUS-EOR projects.
A structured Simultaneous Evaluation of Criteria and Alternatives (SECA)–Additive Ratio Assessment System (ARAS) methodology was applied to combine technical and economic indicators, generating a prioritized ranking of candidate reservoirs. This approach allows systematic identification of sites with maximum carbon mitigation potential while maintaining economic viability. The methodology also accommodates sensitivity analyses to evaluate the impact of key parameters, such as fluid & reservoir properties, CO2 supply fluctuations, and operational cost variations, enhancing the robustness of site selection and prioritization. Application of this framework highlights several Iranian basins, as particularly suitable for CCUS-EOR projects due to favorable geological and operational characteristics.
By integrating engineering, geological, and economic criteria within a unified evaluation framework, this study provides a practical tool for policymakers and industry stakeholders. The proposed approach supports sustainable development of Iran’s oil and gas sector, enabling large-scale carbon reduction initiatives while maximizing hydrocarbon recovery, and establishes a rigorous foundation for informed decision-making in future CCUS-EOR planning and implementation.
Keywords: CO2 Capture and Storage, Enhance Oil Recovery, Technical Assessment, Economic Analysis, SECA, ARAS.
Co-author/s:
Dr. Shahin Kord, Associate Professor, Petroleum University of Technology Ahwaz.
Dr. Nasser Faraz, Head of Process Projects, National Iranian South Oil Company (NISOC).
Madan Kumar Kumaravelan
Speaker
Chief Manager - R&D
Hindustan Petroleum Corporation Limited
Since emergence of the need for carbon capture, solvent based CO2 absorption processes encompassing conventional trayed columns have been dominating. However, these CO2 absorption columns have major limitations of tall size (20 to 30 meters) and huge weight. Main reason for such huge height is due to poor gas-liquid mass transfer efficiency which is governed by gravity.
Hindustan Petroleum Corporation Limited (HPCL), India has developed a novel HiGAS technology for overcoming these limitations. With this breakthrough technology, height of absorption columns can be reduced significantly by 10 times. HiGAS technology uses a Rotating Packed Bed (RPB) made of high surface area packing elements and induces centrifugal forces that are over 100 times of gravity. This reduces the Height Equivalent to Theoretical Plates (HETP) by 50-100 times, resulting in multitude level intensification of mass transfer efficiency and small unit size. First-of-its-kind commercial HP-HiGAS unit has been successfully implemented in HPCL Refinery, India for refinery fuel gas sweetening. This 2.5 meters HIGAS unit designed for removal of acid gas from 4 wt% to 100 ppm has replaced the existing 23 meters absorption column having 28 trays thus resulting in a significant size reduction of 10 times.
HPCL is now setting-up a commercial scale carbon capture unit for producing blue hydrogen based on HP-HiGAS technology. This unit with 24 KTPA CO2 capture capacity is being set-up at the Hydrogen Generation Unit (HGU) in HPCL refinery at an investment of 2 million USD.
HP-HiGAS technology, backed by its significant benefits of low size / foot print, low capital cost and improved safety, is the next generation revolution in carbon capture technologies as it perfectly suits all the CO2 capture requirements. Tapping the huge potential of HiGAS technology worldwide for carbon capture, would create a dramatic impact across the globe.
Hindustan Petroleum Corporation Limited (HPCL), India has developed a novel HiGAS technology for overcoming these limitations. With this breakthrough technology, height of absorption columns can be reduced significantly by 10 times. HiGAS technology uses a Rotating Packed Bed (RPB) made of high surface area packing elements and induces centrifugal forces that are over 100 times of gravity. This reduces the Height Equivalent to Theoretical Plates (HETP) by 50-100 times, resulting in multitude level intensification of mass transfer efficiency and small unit size. First-of-its-kind commercial HP-HiGAS unit has been successfully implemented in HPCL Refinery, India for refinery fuel gas sweetening. This 2.5 meters HIGAS unit designed for removal of acid gas from 4 wt% to 100 ppm has replaced the existing 23 meters absorption column having 28 trays thus resulting in a significant size reduction of 10 times.
HPCL is now setting-up a commercial scale carbon capture unit for producing blue hydrogen based on HP-HiGAS technology. This unit with 24 KTPA CO2 capture capacity is being set-up at the Hydrogen Generation Unit (HGU) in HPCL refinery at an investment of 2 million USD.
HP-HiGAS technology, backed by its significant benefits of low size / foot print, low capital cost and improved safety, is the next generation revolution in carbon capture technologies as it perfectly suits all the CO2 capture requirements. Tapping the huge potential of HiGAS technology worldwide for carbon capture, would create a dramatic impact across the globe.
Injecting CO₂ into geological formations offers a promising route to store large‑scale emissions, but monitoring CO₂ flooding in heterogeneous carbonate reservoirs remains difficult yet vital for ensuring storage security and preventing leakage. This study presents an integrated workflow that combines high‑resolution outcrop‑based reservoir modeling, multi‑scenario CO₂ flood simulations, and 4D seismic analysis to track the CO₂ saturation front and evaluate reservoir performance.
Carbonate outcrops serve as analogs for subsurface reservoirs. Detailed mapping of lithologic layers and facies enabled the construction of a 4 × 6 km three‑dimensional sector model equipped with flank injectors and crestal water producers. The model incorporates porosity, permeability, velocity, and density data collected from published literature and in‑house (KAUST) laboratory measurements. Supercritical CO₂ flood simulations were run under two end‑member boundary conditions: (1) closed boundaries representing an isolated system with no connected aquifer; and (2) open boundaries allowing fluid flow outside the model. Elastic properties were updated iteratively over a 50‑year injection period to generate inputs for time‐lapse (4D) seismic modeling. Seismic attribute analysis was then employed to monitor the advancing CO₂ front and detect zones of partial fluid saturation.
The outcrop exhibits meter‑scale lateral facies heterogeneity, with alternating limestone and dolomite beds. Inspired by these field observations, we generated the reservoir model and incorporated subsurface petrophysical data into it. In closed‑boundary scenarios, stromatoporoid‐rich and grainy facies dominate flow pathways, producing an uneven CO₂ front; open boundaries yield a more uniform advance. After 50 years of injection the CO₂ reaches producer wells faster under closed conditions due to stronger injector–producer pressure gradients. Temporal changes in CO₂ saturation alter P- and S-wave velocities, generating amplitude variations in the 4D seismic cubes. RMS amplitudes extracted from the top of the reservoir delineate saturation patterns even at low concentrations; however, small amplitude anomalies are highly susceptible to noise.
Overall this work delivers a realistic high‑resolution carbonate reservoir model together with a comprehensive workflow that illuminates supercritical CO₂ migration pathways. By integrating field analog observations, laboratory measurements, numerical modeling, and seismic simulation we capture multi‑scale heterogeneities critical for monitoring outcomes. The presented approach can serve as a predictive tool for calibrating field‐scale observations during CO₂ flooding projects and as an assurance framework for carbon sequestration initiatives.
Co-author/s:
Billal Aslam, Student, King Abdullah University of Science and Technology.
Gaurav Gairola, Geologist, King Abdullah University of Science and Technology.
Carbonate outcrops serve as analogs for subsurface reservoirs. Detailed mapping of lithologic layers and facies enabled the construction of a 4 × 6 km three‑dimensional sector model equipped with flank injectors and crestal water producers. The model incorporates porosity, permeability, velocity, and density data collected from published literature and in‑house (KAUST) laboratory measurements. Supercritical CO₂ flood simulations were run under two end‑member boundary conditions: (1) closed boundaries representing an isolated system with no connected aquifer; and (2) open boundaries allowing fluid flow outside the model. Elastic properties were updated iteratively over a 50‑year injection period to generate inputs for time‐lapse (4D) seismic modeling. Seismic attribute analysis was then employed to monitor the advancing CO₂ front and detect zones of partial fluid saturation.
The outcrop exhibits meter‑scale lateral facies heterogeneity, with alternating limestone and dolomite beds. Inspired by these field observations, we generated the reservoir model and incorporated subsurface petrophysical data into it. In closed‑boundary scenarios, stromatoporoid‐rich and grainy facies dominate flow pathways, producing an uneven CO₂ front; open boundaries yield a more uniform advance. After 50 years of injection the CO₂ reaches producer wells faster under closed conditions due to stronger injector–producer pressure gradients. Temporal changes in CO₂ saturation alter P- and S-wave velocities, generating amplitude variations in the 4D seismic cubes. RMS amplitudes extracted from the top of the reservoir delineate saturation patterns even at low concentrations; however, small amplitude anomalies are highly susceptible to noise.
Overall this work delivers a realistic high‑resolution carbonate reservoir model together with a comprehensive workflow that illuminates supercritical CO₂ migration pathways. By integrating field analog observations, laboratory measurements, numerical modeling, and seismic simulation we capture multi‑scale heterogeneities critical for monitoring outcomes. The presented approach can serve as a predictive tool for calibrating field‐scale observations during CO₂ flooding projects and as an assurance framework for carbon sequestration initiatives.
Co-author/s:
Billal Aslam, Student, King Abdullah University of Science and Technology.
Gaurav Gairola, Geologist, King Abdullah University of Science and Technology.
On December 11, 2024, Law No. 15.042/2024 was enacted, establishing the Brazilian Greenhouse Gas Emissions Trading Scheme (SBCE). This measure lays the foundation for a regulated carbon market in Brazil.
The law creates a cap-and-trade system, where the government sets emission limits for activities, sources, and facilities, distributes Emission Allowances (Cotas Brasileiras de Emissões – CBEs), and allows trading of these allowances among regulated operators. The SBCE primarily applies to the industrial and energy sectors.
CBEs will be allocated to regulated operators either free of charge or through paid mechanisms within the established emission Cap. If an operator exceeds its allowance, it must purchase additional CBEs from other companies or acquire carbon credits from the voluntary market, provided they are recognized as eligible by the Brazilian government. The allocation of CBEs among regulated sectors will be determined by the National Allocation Plan (NDCs), which aligns with Brazil’s climate commitments under the National Climate Plan (Plano Clima).
The approval of Law No. 15.042/2024 represents a significant step toward fulfilling Brazil’s commitments under the Paris Agreement while maintaining the country’s global market competitiveness. This is particularly relevant given the implementation of the Carbon Border Adjustment Mechanism (CBAM) by the European Union in 2023.
The law broadly defines key aspects of the SBCE, including:
• Principles and governance structure;
The National Allocation Plan will determine emission limits and the allocation of allowances across sectors and regulated entities. It will be developed by the SBCE’s managing authority (to be appointed by the federal government) with the support of the Permanent Technical Group, a consultative body including representatives from the government, industry, academia, and civil society. The plan must be approved by the Interministerial Committee on Climate Change (CIM).
The SBCE’s guiding principles include compatibility with Brazil’s Nationally Determined Contribution (NDC), transparency, predictability, economic competitiveness, and cost-effective emissions reduction. Allocation methodologies will consider technological advancements, historical efficiency gains, and marginal abatement costs.
The National Allocation Plan will follow a gradual approach across commitment periods, ensuring regulatory predictability. It must be approved at least 12 months before its implementation, with estimated emission limits projected for two subsequent periods.
The law creates a cap-and-trade system, where the government sets emission limits for activities, sources, and facilities, distributes Emission Allowances (Cotas Brasileiras de Emissões – CBEs), and allows trading of these allowances among regulated operators. The SBCE primarily applies to the industrial and energy sectors.
CBEs will be allocated to regulated operators either free of charge or through paid mechanisms within the established emission Cap. If an operator exceeds its allowance, it must purchase additional CBEs from other companies or acquire carbon credits from the voluntary market, provided they are recognized as eligible by the Brazilian government. The allocation of CBEs among regulated sectors will be determined by the National Allocation Plan (NDCs), which aligns with Brazil’s climate commitments under the National Climate Plan (Plano Clima).
The approval of Law No. 15.042/2024 represents a significant step toward fulfilling Brazil’s commitments under the Paris Agreement while maintaining the country’s global market competitiveness. This is particularly relevant given the implementation of the Carbon Border Adjustment Mechanism (CBAM) by the European Union in 2023.
The law broadly defines key aspects of the SBCE, including:
• Principles and governance structure;
- Legal and tax status of emission assets;
- Technology systems supporting the market;
- Obligations for regulated entities (measurement, reporting, verification, and compliance);
- Enforcement measures and penalties;
- Guidelines for integrating the SBCE with voluntary carbon markets.
The National Allocation Plan will determine emission limits and the allocation of allowances across sectors and regulated entities. It will be developed by the SBCE’s managing authority (to be appointed by the federal government) with the support of the Permanent Technical Group, a consultative body including representatives from the government, industry, academia, and civil society. The plan must be approved by the Interministerial Committee on Climate Change (CIM).
The SBCE’s guiding principles include compatibility with Brazil’s Nationally Determined Contribution (NDC), transparency, predictability, economic competitiveness, and cost-effective emissions reduction. Allocation methodologies will consider technological advancements, historical efficiency gains, and marginal abatement costs.
The National Allocation Plan will follow a gradual approach across commitment periods, ensuring regulatory predictability. It must be approved at least 12 months before its implementation, with estimated emission limits projected for two subsequent periods.
The Diesel Hydrotreater Unit (DHT) plays a crucial role in producing high-quality diesel by removing impurities and improving feedstock properties. As sustainability and cost-effectiveness become priorities, refineries are actively exploring strategies to enhance energy efficiency and minimize carbon emissions.
The DHT at HPCL (Hindustan Petroleum Corporation Limited) is uniquely complexed as an Integrated VGO & Diesel Hydrotreater Unit, processing both Vacuum Gas Oil (VGO) and diesel in separate reactors. There are two parallel trains of operation, one is having Vacuum Gas Oil as feed and the other one having Raw Diesel as feed. This integration increases operational intensity and energy consumption, making efficiency improvements particularly impactful.
This paper presents a set of impactful operational optimization initiatives undertaken in the Integrated Diesel Hydrotreater (DHT) unit, aimed at improving energy efficiency, reducing operating costs, and minimizing environmental impact. Key measures included hot feed maximization to reduce cold feed dependency, and the successful shutdown of one furnace through strategic operational adjustments without compromising throughput. Additional steps such as gas-to-oil ratio optimization, significant flare reduction, and stripping steam optimization were implemented to further enhance system efficiency. Export naphtha reduction was achieved by optimizing fractionator overhead conditions, while operational changes in the Sour Water Stripper (SWS) and Fractionator led to a substantial reduction in steam consumption—by nearly 80 tons per day.
Importantly, these improvements were realized without incurring any additional capital expenditure, making them highly cost-effective and immediately impactful. The absence of investment requirements enhances the attractiveness of these measures, especially from an operational sustainability standpoint. While this abstract highlights some of the most significant actions taken, it is important to note that several other optimizations were also implemented across the unit, each contributing cumulatively to the enhanced performance, energy conservation, and environmental responsibility of the DHT.
By implementing these changes—without any capital investment in new equipment or pipelines— savings of over 6,000 SRFT and CO2 reduction of around 19000 kg/hr were achieved annually. Beyond cost reduction, these initiatives align with broader sustainability goals by minimizing environmental impact while maintaining high operational performance.
In conclusion, optimizing energy usage in an Integrated DHT unit through strategic operational changes not only strengthens cost leadership but also advances sustainability in refining. These initiatives highlight the importance of continuous improvement and innovation in driving more efficient and environmentally responsible refinery operations.
The DHT at HPCL (Hindustan Petroleum Corporation Limited) is uniquely complexed as an Integrated VGO & Diesel Hydrotreater Unit, processing both Vacuum Gas Oil (VGO) and diesel in separate reactors. There are two parallel trains of operation, one is having Vacuum Gas Oil as feed and the other one having Raw Diesel as feed. This integration increases operational intensity and energy consumption, making efficiency improvements particularly impactful.
This paper presents a set of impactful operational optimization initiatives undertaken in the Integrated Diesel Hydrotreater (DHT) unit, aimed at improving energy efficiency, reducing operating costs, and minimizing environmental impact. Key measures included hot feed maximization to reduce cold feed dependency, and the successful shutdown of one furnace through strategic operational adjustments without compromising throughput. Additional steps such as gas-to-oil ratio optimization, significant flare reduction, and stripping steam optimization were implemented to further enhance system efficiency. Export naphtha reduction was achieved by optimizing fractionator overhead conditions, while operational changes in the Sour Water Stripper (SWS) and Fractionator led to a substantial reduction in steam consumption—by nearly 80 tons per day.
Importantly, these improvements were realized without incurring any additional capital expenditure, making them highly cost-effective and immediately impactful. The absence of investment requirements enhances the attractiveness of these measures, especially from an operational sustainability standpoint. While this abstract highlights some of the most significant actions taken, it is important to note that several other optimizations were also implemented across the unit, each contributing cumulatively to the enhanced performance, energy conservation, and environmental responsibility of the DHT.
By implementing these changes—without any capital investment in new equipment or pipelines— savings of over 6,000 SRFT and CO2 reduction of around 19000 kg/hr were achieved annually. Beyond cost reduction, these initiatives align with broader sustainability goals by minimizing environmental impact while maintaining high operational performance.
In conclusion, optimizing energy usage in an Integrated DHT unit through strategic operational changes not only strengthens cost leadership but also advances sustainability in refining. These initiatives highlight the importance of continuous improvement and innovation in driving more efficient and environmentally responsible refinery operations.
