CCS in Power Generation Market by Technology Type (Post Combustion, Pre Combustion), Capture Method (Chemical Absorption, Cryogenic Separation, Membrane Separation), Plant Type, Deployment Model - Global Forecast 2025-2032
Description
The CCS in Power Generation Market was valued at USD 17.09 billion in 2024 and is projected to grow to USD 18.58 billion in 2025, with a CAGR of 10.28%, reaching USD 37.40 billion by 2032.
A strategic introduction to how carbon capture integration reshapes power generation portfolios, balancing emissions objectives with operational and financial complexity
Carbon capture and storage (CCS) in power generation has moved from experimental pilot programs to an operational imperative in many jurisdictions seeking deep decarbonization. Increasingly stringent emissions regulations, corporate net-zero commitments, and the need to balance reliability with renewable integration are elevating CCS as a strategic option for legacy thermal assets and new-build plants alike. While capture technologies and project delivery models have matured, implementation complexity remains high because CCS sits at the intersection of proven engineering, evolving regulation, and multi-stakeholder finance.
Consequently, power sector decision-makers are evaluating CCS not only as an emissions control technology, but as a portfolio element that can preserve dispatchable capacity, unlock hydrogen production pathways, and provide negative-emission opportunities when paired with bioenergy. At the same time, the lifecycle of CCS projects requires rigorous attention to supply chain resilience, permitting timelines, and long-term monitoring obligations. Therefore, executives and investors must weigh near-term capital intensity against long-term strategic value, using cross-functional analysis that integrates technical feasibility, regulatory trajectories, and stakeholder acceptance.
How accelerating technology advances, regulatory shifts, and evolving financing mechanisms are collectively transforming the deployment and strategic value of CCS in power systems
The CCS landscape in power generation is undergoing transformative shifts driven by technological innovation, policy recalibration, and evolving market structures. Advances in solvent chemistry, modular membrane design, and cryogenic processes are reducing energy penalties and improving integration options for a wider range of plant types. Meanwhile, digitalization and monitoring technologies are increasing the reliability and transparency of capture operations, enabling predictive maintenance and improved performance benchmarking.
On the policy front, tighter emissions standards, revised permitting frameworks, and nascent carbon removal credits are changing incentives and redistributing project risk between developers, utilities, and offtakers. Financing models are also shifting: blended public-private instruments, contractual structures tying revenues to confirmed transport and storage capacities, and outcome-based subsidies are emerging as practical responses to early-stage project risk. As a result, deployment decisions are now influenced as much by contract design and regulatory clarity as by raw technology performance. The cumulative effect is a landscape where integrated solutions-combining capture, transport, storage, and value-added offtakes-are increasingly the default approach for successful, scalable projects.
Assessment of the strategic and operational consequences of newly enacted tariffs on CCS equipment imports and how they influence supply chain localization and project delivery dynamics
The introduction of tariffs on imported components in 2025 has had multifaceted implications for CCS project planning, procurement strategies, and risk allocation across the value chain. In the near term, tariffs can elevate capital costs for projects dependent on specialized equipment sourced from international suppliers, prompting developers to re-evaluate vendor selection, buffer contingencies in procurement schedules, and prioritize local content where feasible. Over time, these measures can incentivize the establishment of regional supply chains and domestic manufacturing capacity for critical components such as capture modules, specialized membranes, and cryogenic equipment.
However, the reshaping of procurement patterns also introduces trade-offs. Localization efforts can reduce exposure to cross-border tariffs but may increase unit costs and extend lead times during the scale-up phase. For multinational technology providers, tariffs encourage strategic realignment, including joint ventures, licensing agreements, or staged investments in manufacturing footprints closer to major demand centers. For project financiers and owners, the tariffs increase the importance of contractual protections, such as price adjustment mechanisms and supplier performance guarantees. Importantly, regulatory clarity and predictable tariff regimes reduce uncertainty and allow developers to design procurement strategies that balance cost, schedule, and technical performance without compromising long-term operational objectives.
Comprehensive segmentation-driven insights that connect technology choices, capture methods, plant configurations, project scales, and deployment models to practical implementation outcomes
Insight into market segmentation reveals how technology attributes and deployment contexts shape technical selection and project pathways. When evaluated by technology type, operators must decide between post-combustion and pre-combustion approaches, with unit-level constraints, retrofit feasibility, and integration with existing steam cycles governing the choice. Capture method selection further differentiates projects: chemical absorption strategies are implemented using alkaline or amine-based solvents and are often selected for retrofit scenarios because of established performance profiles; cryogenic separation can rely on liquefaction or refrigeration-cycle architectures when low-temperature processing aligns with downstream transport or liquefied product requirements; membrane separation options bifurcate into inorganic and polymeric membrane solutions that trade off robustness against cost and scalability; and physical adsorption pathways, using activated carbon or zeolite media, are attractive where cyclic operation and sorbent regeneration fit plant duty schedules.
Plant type significantly conditions technology and project design: biomass-fired facilities, integrated gasification combined cycle units with entrained flow or fluidized bed gasifiers, natural gas combined cycle plants, pulverized coal stations, and waste-to-energy plants each impose unique flue gas compositions, pressure regimes, and thermal integration constraints that influence capture selection. Project scale decisions between large-scale and small-scale deployments determine the relative importance of modularity, financing complexity, and economies of scope, while deployment model choices between brownfield and greenfield projects influence permitting pathways, grid interconnection considerations, and the potential for co-location with transport and storage infrastructure. Together, these segmentation dimensions provide a structured lens for comparing technical fit, risk profiles, and implementation timelines across CCS projects in power generation.
Critical regional dynamics and infrastructure realities that determine where carbon capture projects progress fastest and how regional policies shape deployment pathways
Regional dynamics shape where and how CCS projects in power generation gain traction, driven by differences in regulatory regimes, infrastructure readiness, and stakeholder priorities. In the Americas, strong policy signals in select jurisdictions, coupled with extensive industrial CO2 transport corridors and geological storage options, create an environment conducive to large-scale integrated projects and clustered storage hubs. In contrast, Europe, Middle East & Africa reflects a diverse picture: some European markets emphasize rapid emissions reductions and tightly regulated permitting, while parts of the Middle East prioritize CO2 use and storage linked to industrial clusters, and African markets focus on capacity building and pilot deployments supported by international partnerships.
Across Asia-Pacific, demand for dispatchable low-carbon generation and industrial decarbonization pathways is heightening interest in CCS solutions, with particular attention to adapting technologies for a range of plant types from coal-fired baseload units to emerging gas fleets. Each region’s trajectory is mediated by local supply chain capabilities, availability of long-duration storage sites, and the evolution of incentive structures that blend public funding with private capital. Consequently, strategic entrants prioritize regional policy engagement and infrastructure partnerships to align project design with the specific regulatory, geological, and market realities of each geography.
Profiles of how technology providers, engineering firms, utilities, and service specialists are aligning capabilities and partnerships to commercialize carbon capture projects efficiently
Competitive behaviors among industry participants reflect a mix of specialization, strategic partnership, and vertical integration. Equipment manufacturers and technology licensors are concentrating R&D on lowering parasitic loads and improving modularity to broaden applicability across plant types. Engineering, procurement, and construction firms are expanding capabilities to manage the unique co-ordination challenges of capture, transport, and storage interfaces, while utilities and asset owners are developing internal competencies to operate integrated chains and to negotiate long-term storage rights.
Market entrants and incumbent players alike are forming consortiums to de-risk early-stage projects and to secure offtake agreements for captured CO2 where utilization opportunities exist. Meanwhile, service providers offering project financing, long-term monitoring, and regulatory navigation are gaining prominence as critical enablers of project viability. The aggregate effect is a more collaborative ecosystem in which strategic alliances, targeted investments in manufacturing capacity, and capability-building among operators determine who leads in delivering repeatable CCS projects at scale.
Practical and prioritized actions executives should implement to de-risk projects, optimize procurement, and ensure integrated delivery of CCS solutions in power generation
Industry leaders should pursue a coordinated set of actions to convert strategic intent into reliable delivery. First, prioritize integrated project planning that aligns capture design with transport and storage capacity from the outset, thereby reducing late-stage design changes and permitting risk. Next, adopt procurement frameworks that emphasize supplier diversity, modular specifications, and staged deliveries to mitigate tariff and lead-time exposures. Simultaneously, invest in pilot deployments that validate system integration at representative scales; these pilots should be designed to provide operational learning loops and to reduce technology execution risk before full-scale commitment.
In parallel, secure early engagement with regulators and community stakeholders to expedite permitting and to build social license, while negotiating contractual structures that allocate long-tail storage and monitoring liabilities in ways that do not stall project finance. Finally, develop financing strategies that leverage blended instruments, contractual revenue guarantees, and where available, public co-investment to manage capital intensity. Executives who implement these actions will increase the probability of on-time, on-budget delivery while preserving optionality to adapt to evolving policy and technology conditions.
Transparent research methodology combining primary interviews, technical literature, policy records, and multi-method analysis to validate findings and insights
The research underpinning this report synthesizes a multi-source evidence base combining primary interviews, technical literature, regulatory documents, and public infrastructure data to ensure robust findings. Primary inputs include structured interviews with project developers, utility engineers, equipment suppliers, financing partners, and regulatory officials to capture first-hand perspectives on operational challenges, contractual innovation, and procurement responses. Secondary sources encompass peer-reviewed engineering studies, government policy releases, permitting records, and technical standards that inform the assessment of technology readiness and compliance requirements.
Analytical methods include cross-case comparison to identify recurring implementation patterns, technology performance benchmarking based on documented operational data where available, and qualitative scenario analysis to map plausible pathways under differing policy and supply chain conditions. Findings were validated through iterative peer review with subject-matter experts and triangulation across independent data points. Throughout the methodology, care was taken to avoid double-counting of project attributes and to transparently document assumptions underlying comparative evaluations.
Concluding synthesis of how coordinated planning, procurement resilience, and stakeholder engagement determine the long-term success of CCS initiatives in power generation
In conclusion, carbon capture and storage in power generation is transitioning from niche demonstrations to an operationally relevant component of decarbonization strategies. The convergence of improved capture technologies, evolving financing structures, and clearer policy signals is making CCS a viable option for retaining dispatchable capacity and for enabling low-carbon fuel pathways. Nevertheless, successful delivery hinges on integrated planning that synchronizes capture systems with transport and storage, resilient procurement strategies that mitigate tariff-driven disruptions, and stakeholder engagement that secures regulatory and social acceptance.
The path forward for project sponsors involves deliberate trade-offs: choosing technologies and deployment scales aligned to plant characteristics; balancing localization and cost considerations in procurement; and structuring contracts to manage long-term storage liabilities. Firms that act decisively to build cross-functional capabilities, form strategic partnerships, and validate designs through pilots will be best positioned to translate strategic commitments into repeatable, bankable projects that meet both performance and sustainability objectives.
Please Note: PDF & Excel + Online Access - 1 Year
A strategic introduction to how carbon capture integration reshapes power generation portfolios, balancing emissions objectives with operational and financial complexity
Carbon capture and storage (CCS) in power generation has moved from experimental pilot programs to an operational imperative in many jurisdictions seeking deep decarbonization. Increasingly stringent emissions regulations, corporate net-zero commitments, and the need to balance reliability with renewable integration are elevating CCS as a strategic option for legacy thermal assets and new-build plants alike. While capture technologies and project delivery models have matured, implementation complexity remains high because CCS sits at the intersection of proven engineering, evolving regulation, and multi-stakeholder finance.
Consequently, power sector decision-makers are evaluating CCS not only as an emissions control technology, but as a portfolio element that can preserve dispatchable capacity, unlock hydrogen production pathways, and provide negative-emission opportunities when paired with bioenergy. At the same time, the lifecycle of CCS projects requires rigorous attention to supply chain resilience, permitting timelines, and long-term monitoring obligations. Therefore, executives and investors must weigh near-term capital intensity against long-term strategic value, using cross-functional analysis that integrates technical feasibility, regulatory trajectories, and stakeholder acceptance.
How accelerating technology advances, regulatory shifts, and evolving financing mechanisms are collectively transforming the deployment and strategic value of CCS in power systems
The CCS landscape in power generation is undergoing transformative shifts driven by technological innovation, policy recalibration, and evolving market structures. Advances in solvent chemistry, modular membrane design, and cryogenic processes are reducing energy penalties and improving integration options for a wider range of plant types. Meanwhile, digitalization and monitoring technologies are increasing the reliability and transparency of capture operations, enabling predictive maintenance and improved performance benchmarking.
On the policy front, tighter emissions standards, revised permitting frameworks, and nascent carbon removal credits are changing incentives and redistributing project risk between developers, utilities, and offtakers. Financing models are also shifting: blended public-private instruments, contractual structures tying revenues to confirmed transport and storage capacities, and outcome-based subsidies are emerging as practical responses to early-stage project risk. As a result, deployment decisions are now influenced as much by contract design and regulatory clarity as by raw technology performance. The cumulative effect is a landscape where integrated solutions-combining capture, transport, storage, and value-added offtakes-are increasingly the default approach for successful, scalable projects.
Assessment of the strategic and operational consequences of newly enacted tariffs on CCS equipment imports and how they influence supply chain localization and project delivery dynamics
The introduction of tariffs on imported components in 2025 has had multifaceted implications for CCS project planning, procurement strategies, and risk allocation across the value chain. In the near term, tariffs can elevate capital costs for projects dependent on specialized equipment sourced from international suppliers, prompting developers to re-evaluate vendor selection, buffer contingencies in procurement schedules, and prioritize local content where feasible. Over time, these measures can incentivize the establishment of regional supply chains and domestic manufacturing capacity for critical components such as capture modules, specialized membranes, and cryogenic equipment.
However, the reshaping of procurement patterns also introduces trade-offs. Localization efforts can reduce exposure to cross-border tariffs but may increase unit costs and extend lead times during the scale-up phase. For multinational technology providers, tariffs encourage strategic realignment, including joint ventures, licensing agreements, or staged investments in manufacturing footprints closer to major demand centers. For project financiers and owners, the tariffs increase the importance of contractual protections, such as price adjustment mechanisms and supplier performance guarantees. Importantly, regulatory clarity and predictable tariff regimes reduce uncertainty and allow developers to design procurement strategies that balance cost, schedule, and technical performance without compromising long-term operational objectives.
Comprehensive segmentation-driven insights that connect technology choices, capture methods, plant configurations, project scales, and deployment models to practical implementation outcomes
Insight into market segmentation reveals how technology attributes and deployment contexts shape technical selection and project pathways. When evaluated by technology type, operators must decide between post-combustion and pre-combustion approaches, with unit-level constraints, retrofit feasibility, and integration with existing steam cycles governing the choice. Capture method selection further differentiates projects: chemical absorption strategies are implemented using alkaline or amine-based solvents and are often selected for retrofit scenarios because of established performance profiles; cryogenic separation can rely on liquefaction or refrigeration-cycle architectures when low-temperature processing aligns with downstream transport or liquefied product requirements; membrane separation options bifurcate into inorganic and polymeric membrane solutions that trade off robustness against cost and scalability; and physical adsorption pathways, using activated carbon or zeolite media, are attractive where cyclic operation and sorbent regeneration fit plant duty schedules.
Plant type significantly conditions technology and project design: biomass-fired facilities, integrated gasification combined cycle units with entrained flow or fluidized bed gasifiers, natural gas combined cycle plants, pulverized coal stations, and waste-to-energy plants each impose unique flue gas compositions, pressure regimes, and thermal integration constraints that influence capture selection. Project scale decisions between large-scale and small-scale deployments determine the relative importance of modularity, financing complexity, and economies of scope, while deployment model choices between brownfield and greenfield projects influence permitting pathways, grid interconnection considerations, and the potential for co-location with transport and storage infrastructure. Together, these segmentation dimensions provide a structured lens for comparing technical fit, risk profiles, and implementation timelines across CCS projects in power generation.
Critical regional dynamics and infrastructure realities that determine where carbon capture projects progress fastest and how regional policies shape deployment pathways
Regional dynamics shape where and how CCS projects in power generation gain traction, driven by differences in regulatory regimes, infrastructure readiness, and stakeholder priorities. In the Americas, strong policy signals in select jurisdictions, coupled with extensive industrial CO2 transport corridors and geological storage options, create an environment conducive to large-scale integrated projects and clustered storage hubs. In contrast, Europe, Middle East & Africa reflects a diverse picture: some European markets emphasize rapid emissions reductions and tightly regulated permitting, while parts of the Middle East prioritize CO2 use and storage linked to industrial clusters, and African markets focus on capacity building and pilot deployments supported by international partnerships.
Across Asia-Pacific, demand for dispatchable low-carbon generation and industrial decarbonization pathways is heightening interest in CCS solutions, with particular attention to adapting technologies for a range of plant types from coal-fired baseload units to emerging gas fleets. Each region’s trajectory is mediated by local supply chain capabilities, availability of long-duration storage sites, and the evolution of incentive structures that blend public funding with private capital. Consequently, strategic entrants prioritize regional policy engagement and infrastructure partnerships to align project design with the specific regulatory, geological, and market realities of each geography.
Profiles of how technology providers, engineering firms, utilities, and service specialists are aligning capabilities and partnerships to commercialize carbon capture projects efficiently
Competitive behaviors among industry participants reflect a mix of specialization, strategic partnership, and vertical integration. Equipment manufacturers and technology licensors are concentrating R&D on lowering parasitic loads and improving modularity to broaden applicability across plant types. Engineering, procurement, and construction firms are expanding capabilities to manage the unique co-ordination challenges of capture, transport, and storage interfaces, while utilities and asset owners are developing internal competencies to operate integrated chains and to negotiate long-term storage rights.
Market entrants and incumbent players alike are forming consortiums to de-risk early-stage projects and to secure offtake agreements for captured CO2 where utilization opportunities exist. Meanwhile, service providers offering project financing, long-term monitoring, and regulatory navigation are gaining prominence as critical enablers of project viability. The aggregate effect is a more collaborative ecosystem in which strategic alliances, targeted investments in manufacturing capacity, and capability-building among operators determine who leads in delivering repeatable CCS projects at scale.
Practical and prioritized actions executives should implement to de-risk projects, optimize procurement, and ensure integrated delivery of CCS solutions in power generation
Industry leaders should pursue a coordinated set of actions to convert strategic intent into reliable delivery. First, prioritize integrated project planning that aligns capture design with transport and storage capacity from the outset, thereby reducing late-stage design changes and permitting risk. Next, adopt procurement frameworks that emphasize supplier diversity, modular specifications, and staged deliveries to mitigate tariff and lead-time exposures. Simultaneously, invest in pilot deployments that validate system integration at representative scales; these pilots should be designed to provide operational learning loops and to reduce technology execution risk before full-scale commitment.
In parallel, secure early engagement with regulators and community stakeholders to expedite permitting and to build social license, while negotiating contractual structures that allocate long-tail storage and monitoring liabilities in ways that do not stall project finance. Finally, develop financing strategies that leverage blended instruments, contractual revenue guarantees, and where available, public co-investment to manage capital intensity. Executives who implement these actions will increase the probability of on-time, on-budget delivery while preserving optionality to adapt to evolving policy and technology conditions.
Transparent research methodology combining primary interviews, technical literature, policy records, and multi-method analysis to validate findings and insights
The research underpinning this report synthesizes a multi-source evidence base combining primary interviews, technical literature, regulatory documents, and public infrastructure data to ensure robust findings. Primary inputs include structured interviews with project developers, utility engineers, equipment suppliers, financing partners, and regulatory officials to capture first-hand perspectives on operational challenges, contractual innovation, and procurement responses. Secondary sources encompass peer-reviewed engineering studies, government policy releases, permitting records, and technical standards that inform the assessment of technology readiness and compliance requirements.
Analytical methods include cross-case comparison to identify recurring implementation patterns, technology performance benchmarking based on documented operational data where available, and qualitative scenario analysis to map plausible pathways under differing policy and supply chain conditions. Findings were validated through iterative peer review with subject-matter experts and triangulation across independent data points. Throughout the methodology, care was taken to avoid double-counting of project attributes and to transparently document assumptions underlying comparative evaluations.
Concluding synthesis of how coordinated planning, procurement resilience, and stakeholder engagement determine the long-term success of CCS initiatives in power generation
In conclusion, carbon capture and storage in power generation is transitioning from niche demonstrations to an operationally relevant component of decarbonization strategies. The convergence of improved capture technologies, evolving financing structures, and clearer policy signals is making CCS a viable option for retaining dispatchable capacity and for enabling low-carbon fuel pathways. Nevertheless, successful delivery hinges on integrated planning that synchronizes capture systems with transport and storage, resilient procurement strategies that mitigate tariff-driven disruptions, and stakeholder engagement that secures regulatory and social acceptance.
The path forward for project sponsors involves deliberate trade-offs: choosing technologies and deployment scales aligned to plant characteristics; balancing localization and cost considerations in procurement; and structuring contracts to manage long-term storage liabilities. Firms that act decisively to build cross-functional capabilities, form strategic partnerships, and validate designs through pilots will be best positioned to translate strategic commitments into repeatable, bankable projects that meet both performance and sustainability objectives.
Please Note: PDF & Excel + Online Access - 1 Year
Table of Contents
182 Pages
- 1. Preface
- 1.1. Objectives of the Study
- 1.2. Market Segmentation & Coverage
- 1.3. Years Considered for the Study
- 1.4. Currency
- 1.5. Language
- 1.6. Stakeholders
- 2. Research Methodology
- 3. Executive Summary
- 4. Market Overview
- 5. Market Insights
- 5.1. Integration of carbon capture technology in existing coal and gas plants to meet net-zero targets
- 5.2. Expansion of large-scale carbon capture and storage clusters across industrial and power hubs to drive economies of scale
- 5.3. Deployment of modular carbon capture units for flexible retrofit on peak power generators during high demand periods
- 5.4. Advances in solvent and sorbent materials improving capture efficiency and reducing energy requirements of power plant CCS
- 5.5. Innovative financing models and public-private partnerships accelerating project finance for utility-scale CCS facilities in the power sector
- 5.6. Development of offshore CO2 transport and storage infrastructure enabling coastal power plants to utilize distant geological reservoirs
- 5.7. Regulatory and tax incentive frameworks evolving to support investment in carbon capture projects for the power industry
- 6. Cumulative Impact of United States Tariffs 2025
- 7. Cumulative Impact of Artificial Intelligence 2025
- 8. CCS in Power Generation Market, by Technology Type
- 8.1. Post Combustion
- 8.2. Pre Combustion
- 9. CCS in Power Generation Market, by Capture Method
- 9.1. Chemical Absorption
- 9.1.1. Alkaline
- 9.1.2. Amine Based
- 9.2. Cryogenic Separation
- 9.2.1. Liquefaction
- 9.2.2. Refrigeration Cycle
- 9.3. Membrane Separation
- 9.3.1. Inorganic
- 9.3.2. Polymeric
- 9.4. Physical Adsorption
- 9.4.1. Activated Carbon
- 9.4.2. Zeolite
- 10. CCS in Power Generation Market, by Plant Type
- 10.1. Biomass
- 10.2. Integrated Gasification Combined Cycle
- 10.2.1. Entrained Flow
- 10.2.2. Fluidized Bed
- 10.3. Natural Gas Combined Cycle
- 10.4. Pulverized Coal
- 10.5. Waste To Energy
- 11. CCS in Power Generation Market, by Deployment Model
- 11.1. Brownfield
- 11.2. Greenfield
- 12. CCS in Power Generation Market, by Region
- 12.1. Americas
- 12.1.1. North America
- 12.1.2. Latin America
- 12.2. Europe, Middle East & Africa
- 12.2.1. Europe
- 12.2.2. Middle East
- 12.2.3. Africa
- 12.3. Asia-Pacific
- 13. CCS in Power Generation Market, by Group
- 13.1. ASEAN
- 13.2. GCC
- 13.3. European Union
- 13.4. BRICS
- 13.5. G7
- 13.6. NATO
- 14. CCS in Power Generation Market, by Country
- 14.1. United States
- 14.2. Canada
- 14.3. Mexico
- 14.4. Brazil
- 14.5. United Kingdom
- 14.6. Germany
- 14.7. France
- 14.8. Russia
- 14.9. Italy
- 14.10. Spain
- 14.11. China
- 14.12. India
- 14.13. Japan
- 14.14. Australia
- 14.15. South Korea
- 15. Competitive Landscape
- 15.1. Market Share Analysis, 2024
- 15.2. FPNV Positioning Matrix, 2024
- 15.3. Competitive Analysis
- 15.3.1. Exxon Mobil Corporation
- 15.3.2. Shell plc
- 15.3.3. Chevron Corporation
- 15.3.4. TotalEnergies SE
- 15.3.5. Equinor ASA
- 15.3.6. Mitsubishi Heavy Industries, Ltd.
- 15.3.7. Siemens AG
- 15.3.8. General Electric Company
- 15.3.9. Linde plc
- 15.3.10. Honeywell International Inc.
- 15.3.11. Fluor Corporation
- 15.3.12. Aker Solutions ASA
- 15.3.13. Schlumberger Limited
- 15.3.14. Hitachi, Ltd.
- 15.3.15. Babcock & Wilcox Enterprises, Inc.
- 15.3.16. Air Products and Chemicals, Inc.
- 15.3.17. Carbon Clean Solutions Limited
- 15.3.18. Climeworks AG
- 15.3.19. NET Power LLC
- 15.3.20. Dakota Gasification Company
- 15.3.21. JGC Holdings Corporation
- 15.3.22. Sulzer Ltd
- 15.3.23. Alstom SA
- 15.3.24. Ameresco, Inc.
- 15.3.25. Halliburton Company
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