FLEXIBLE, MODULAR CARBON CAPTURE GAS POWER PLANTS: THE FUTURE OF LOW-EMISSION ENERGY SUPPLY 

The EU Innovation Fund and collaborative efforts among the countries bordering the North Sea are driving new CO₂ storage projects, particularly through cooperation between industry and governments. Active developments include Northern Lights in Norway, which facilitates cross boarder CO₂ transports and storage, alongside initiatives in the Netherlands, the UK and Denmark.  

Several European countries launched new initiatives and expanded support for CCUS projects. The UK government has advanced its post-Brexit energy transition strategy, announcing the first CO₂ hubs and refined its business model for transportation and storage. Norway and the Netherlands have made firm political and regulatory commitments to promote CCS. Other EU member states are actively improving regulatory frameworks, removing barriers and providing political support. 

In the United States, the Inflation Reduction Act’s enhanced 45Q tax credits, offering up to $85 per tonne for industrial capture and storage, and $180 for direct air capture. These generous, bankable credits combined with the Department of Energy‘s funding for regional CO2 hubs have triggered a wave of project announcements across multiple sectors. [6] 

Canada has introduced a refundable CCUS Investment Tax Credit (covering up to 60% of eligible costs for DAC). This is paired with carbon price certainty via the Canada Growth Fund’s contracts for difference. Provinces like Alberta also allocate storage rights and regulate sequestration hubs, giving developers a clear pathway from design to injection. [7] 

China’s support is driven by regulatory momentum. The national emissions trading system is expanding beyond the power sector to include heavy industry. Carbon pricing and the inclusion of CCUS in five-year plans are creating an incentive to invest in capture technology. [8] 

In October 2024, Brazil enacted Federal Law 14,993/2024 (“Fuels of the Future”), its first legal framework for CCS. The law assigns oversight and licensing responsibilities to the Brazilian National Agency of Petroleum and Natural Gas (ANP) for capture, transport and geological storage (renewable 30-year permits). Policymakers are now developing funding mechanisms and Petrobras’ 2025–29 plan allocates significant capital to CCS hubs. A regulated carbon market is also in development. [9] 

Australia supports CCUS through its carbon crediting system. Projects can earn Australian Carbon Credit Units under a dedicated CCS methodology. The Safeguard Mechanism further creates demand for low-carbon compliance options. [10] 

Across these regions a clear trend is emerging: the world’s major economies are no longer debating if CCUS is necessary, but how fast they can scale it. 

The amount of recovered CO₂ will rise sharply as capture projects expand. Over 90% will need to be stored in suitable rock formations to prevent the CO2 from being released into the atmosphere. 

Europe is leading CCS development to meet its 2050 climate neutrality goal and reduce emissions by 55% by 2030 (vs. 1990). There are currently 191 large-scale CCS projects, with plans to store over 160 million tonnes of CO₂ by 2030, mainly in the North Sea. Important projects include: 

• The Dutch Porthos project reached its final investment decision (FID) in October 2023, construction began in early 2024, and the infrastructure is expected to be operational by 2026 
• The Danish Greensand project, First CO2 March 2023 
• The Ravenna hub off Italy, injecting 25,000 tonnes of CO₂ per year since September 2024. scaling to 4 million tonnes of CO₂ per year by 2030 

Projects in Croatia, Bulgaria, France and Greece are also under development. At the same time, licensing for CO₂ storage areas is progressing. The UK has issued 21 licenses, Denmark three, while Norway opened two storage areas for applications in March 2024. [13] 

To enable large-scale CCS implementation and ensure sufficient storage capacity, new political, legal and regulatory frameworks are being created. European governments and the EU are focusing on three main strategies: 

• Direct policy measures and financial incentives such as tax benefits and Carbon Contracts for Difference (CCfD) 
• Support programmes in the form of subsidies and strategic initiatives 
• Comprehensive legal frameworks for CO₂ transportation, storage and project approval  

Unlike in North America, where tax incentives dominate, Europe combines financial support with binding political requirements. Important regulatory progress was made in 2024. The Net-Zero Industry Act (NZIA) sets an EU-wide target of 50 million tonnes of CO₂ storage capacity per year by 2030. The revised directive contains new requirements for renewable and low-CO₂ hydrogen, particularly from CCS processes. In addition, the EU published its Industrial Carbon Management (ICM) strategy in February 2024 to accelerate the introduction of CCS technologies. The planned Carbon Removal Certification Framework (CRCF) is intended to strengthen CCS measures in the future. 

A reassessment is also taking place at a national level: Germany is reforming its CO₂ storage law, while Austria considered lifting its ban on geological CO₂ storage in July 2024 to reduce emissions from hard-to-abate industries.

Financial protection of CCS projects is also a key focus. More European countries are adopting CCfD to minimize financial risks and costs. A CCfD is a financial mechanism that guarantees a fixed carbon price to support low-carbon projects and reduce investment risk. Germany launched its first CCfD pilot programme in 2024, while France is preparing a similar initiative. The Netherlands continues to promote CCS through the SDE++ programme, which financially supports renewable energy and CO₂-reducing projects - including CCS - by bridging the cost-revenue gap; in the 2024 funding round, €11.5 billion was allocated, of which €1.039 billion supported 23 CCS/CCU projects. 

In parallel, more countries are developing their own industrial CCS strategies and roadmaps. The EU and six countries, Austria, Denmark, France, Norway, Switzerland as well as the UK, have already published national strategies, while Germany, Poland and Sweden are due to follow. 

Direct financial support remains central to the European CCS expansion. The EU is providing significant funding through the Innovation Fund and the Connecting Europe Facility for Energy, while countries such as the UK further increased their CCS budgets in early 2024. 

Interest in bioenergy with carbon capture and storage (BECCS) Is also growing. The UK updated its BECCS business model in 2023 to promote the use of this technology. In April 2024, Denmark awarded contracts to three companies for the storage of biogenic CO₂. The European Commission is actively supporting BECCS, for example by funding the Swedish bioenergy plant project in Värtan „BECCS Stockholm“ to the tune of almost SEK 20 trillion (~ €1.7 trillion). 

Another key issue is international cooperation on cross-border CO₂ transport. In 2024, efforts to ratify the 2009 amendment to the London Protocol gained momentum to enable smooth CO₂ transportation and storage across borders. Switzerland ratified the amendment back in November 2023, while Germany and France are planning similar steps. The countries bordering the North Sea are particularly active, concluding bilateral agreements on cross-border CO₂ storage. Cooperation between Norway and countries such as Belgium, Denmark, the Netherlands and Sweden aim to facilitate cross-border transportation even before the final implementation of the protocol. [11] 

With these developments, Europe is positioning itself as a leading region for CCS deployment (Figure 6). Clear political framework targeted financial incentives and growing international cooperation will further strengthen CCS as a key technology for the European climate strategy. 

While Europe is advancing through strong political frameworks and cross-border cooperation, momentum is equally visible across the Atlantic. The United States, though following a different policy and market-driven pathway, has emerged as one of the most dynamic regions for CCUS development, with projects advancing across power, industry and storage infrastructure. 

In the power sector, Petra Nova in Texas remains the only operating coal-CCUS facility in the country. It restarted in 2023, signalling renewed international interest. If completed, Project Tundra in North Dakota could become the second commercial coal capture project, supported by up to $350 million U.S. from federal infrastructure funding. 

Industrial projects are also moving quickly, often with lower costs and simpler transport solutions. Blue Flint Ethanol in North Dakota and Barnett Zero in Texas began operations in late 2023, while Wabash Valley Resources in Indiana received final federal well approvals for its gasification and fertiliser complex. 

Pipeline and hub development is another bright spot. Summit Carbon Solutions won approval for the Iowa leg of its system linking 57 ethanol plants to storage in North Dakota, and Tallgrass is converting its 640-km Trailblazer pipeline for CO₂ transport, with injection permits already secured in Wyoming. 

Storage capacity is expanding through acquisitions: ExxonMobil’s purchase of Denbury added 2,000 km of CO₂ pipelines and 15 storage sites, while TotalEnergies’ acquisition of Talos Low Carbon Solutions secured stakes in Gulf Coast storage projects. 

More projects in the US are on their way: 

• California Resources Corporation is developing its Carbon TerraVault hub 
• Louisiana holds primacy for Class VI permits with dozens of applications pending 
• Wyoming is advancing large hubs like Frontier’s Sweetwater and Tallgrass’s Eastern Wyoming projects [11] 
  

Table 1 highlights key carbon capture and storage hubs worldwide, showcasing their locations, storage capacities, and planned commercial operation dates (COD). Existing hubs like Quest in Alberta, Canada, and Gorgon in Western Australia have been operational since 2015 and 2019, respectively, with annual storage capacities of around 1 to 4 million tonnes of CO₂.

Several large-scale projects are set to come online between 2024 and 2030, including Ravenna in Italy and Northern Lights off Norway’s west coast, offering multi-million-ton storage capacities. Emerging hubs such as Kasawari in Malaysia and Project Greensand off Denmark’s coast will expand CCS capacity further. Ambitious projects in the Middle East and Europe, like Jubail Industrial City in Saudi Arabia and the East Coast Cluster and HyNet in England, promise to store between 4.5 and 44 million tonnes of CO₂ annually, reflecting growing global efforts to scale CCS infrastructure as a critical component of climate mitigation. 

CCUS is becoming increasingly important as a key technology for a low-emission energy future. While turbine solutions have dominated the CCUS power generation sector to date - especially for large-scale projects of 800 MW or more, promising opportunities are emerging in the engine power plant segment. 

According to our forecasts, the annual installed capacity in this segment, which remains in the double-digit MW range in 2025, is expected to rise to several hundred MW per year by 2030. This could lead to an overall installed capacity in the low GW range. 

Why engine-based solutions? 
Engine solutions, especially high-speed variants, offer decisive advantages here. Standardised and compact CCUS products, such as those developed by suppliers like ASCO, enable faster operational readiness and are less complex than customised large-scale systems. In addition, synergies with on-road carbon capture systems allow these technologies to be adapted to smaller power generation systems.

As industrialisation progresses, engine solutions are likely to become even more efficient, compact and user-friendly - a clear advantage for small to medium-sized plants that want to focus on CO₂ reduction in a flexible and cost-efficient manner. A study by Independent Project Analysis (IPA) also estimates the costs of a typical CCUS project at around $500 million U.S. per 1 million tonnes of CO₂/year, which underlines the ecological challenges of large-scale CCUS solutions and puts additional emphasis on the economic efficiency of engine solutions. [14] 

The integration of CCUS in gas-fired power plants offers an effective way to significantly reduce CO₂ emissions while ensuring security of supply. Gas-fired power plants play a central role in the energy supply, as they are flexible and controllable, independent of geographical conditions, and can cope with fluctuations in the feed-in of renewable energies. Gas-fired power plants come into play to ensure grid stability, especially during prolonged dark doldrums when wind and solar energy are not sufficiently available. [15]

In the current discussion about decarbonization, governments are focusing on green hydrogen; however, the widespread availability and affordability of green hydrogen is not yet feasible, which extends the timeline for a complete transition. 

Biomethane is an already available but limited option, as the share in the overall gas grid is currently only in the low single digits for many countries. On top of that, there is not enough capacity to meet all gas-fired power plant demand. This is where CCUS comes into play. This technology makes it possible to separate CO₂ from the exhaust gases of gas-fired power plants and store it or use it for industrial applications.

Compared to other solutions, CCUS is already commercially available today and offers a direct option for CO₂ reduction. In addition, CO₂ can be used as a commodity for industry, for beverage carbonation, the production of synthetic fuels or as a raw material in the chemical industry. Despite the initial investment costs, CCUS systems offer economic incentives, as they not only reduce emissions but also open up new sources of income. 

In the debate on decarbonising energy production, hydrogen is frequently portrayed as a competing technology to CCUS. A common concern is that a large-scale shift to hydrogen in the 2030s could undermine the business case for CCUS, potentially delaying investment and deployment. However, this view overlooks the distinct roles and complementary strengths of both technologies. 

Hydrogen is increasingly recognised as a flexible solution for short-term demand spikes, particularly in so-called „peaker“ power plants, which typically operate fewer than 2,000 hours per year and potentially even less in future energy systems. 

While CCUS could theoretically be applied to peaker plants, the approach is still under development and not yet widely commercialised for such flexible use cases. In contrast, CCUS is particularly well-suited for base load power plants, which operate more than 4,000 full-load hours per year and play a critical role in ensuring grid stability. In these settings, CCUS significantly enhances both the climate performance and the economic viability of fossil-based generation by enabling low-carbon operations and aligning with emissions regulations and carbon pricing mechanisms. [16]  

Rather than being competing solutions, hydrogen and CCUS address different needs within the energy and industrial sectors. Hydrogen is ideal for flexible power generation and certain industrial applications, while CCUS is essential for decarbonising high-load, continuous operations in both power generation and heavy industry. They serve complementary roles and both are essential to achieve net-zero. [17]

Key Success Factors for Gas Engine Solutions with CCUS Gas engine solutions combined with CCUS offer a pathway to low-carbon, dispatchable power. While deploying these systems presents unique considerations, each can be leveraged as a success factor to unlock economic and operational viability: 

• Capital Investment as a Growth Lever: Small-scale carbon capture power plants require higher upfront investment— up to three times that of conventional gas engine systems (Figure 7). This investment builds state-of-the-art, future-proof infrastructure and positions companies as leaders in low-carbon energy. 
• Optimising Operating Costs through Revenue Mechanisms: Higher energy consumption and additional maintenance needs can be offset by establishing stable, long-term CO₂ revenue streams. Mechanisms such as offtake agreements and participation in carbon credit markets help improve investment security and economic sustainability, even amid regulatory and technological uncertainties. 
• Strategic Space Management: CCUS systems may require more physical space than conventional gas engines, but careful planning, modular design, and decentralised layouts allow efficient use of available areas, turning spatial requirements into a competitive advantage. 

When these key success factors are achieved, gas engine solutions with CCUS create significant economic opportunities: 

• First-Mover Advantage: Early adopters can secure market leadership and strengthen sustainability credentials. 
• Revenue Diversification: Captured CO₂ opens new revenue streams and helps organisations prepare for tightening emissions regulations. 
• Regulatory Compliance: CCUS enables companies to mitigate rising carbon costs under schemes such as the EU Emissions Trading System (EU ETS). 
• Strategic Partnerships: Collaborating with experienced technology providers and industrial gas companies reduces risk and accelerates deployment. 

By framing challenges as opportunities, gas engine solutions with CCUS emerge as scalable, economically viable, and future-proof pathways for low-carbon power generation, with strategic partnerships and modular, scalable designs key to reducing costs and ensuring long-term viability. 

From the customer’s perspective, the additional costs, particularly the increased energy demand, which reduces revenues from electricity and heat generation, must be offset by stable and predictable CO₂ revenues. Locationspecific factors, such as the availability of existing infrastructure, play a decisive role, as transport and logistics costs significantly affect overall profitability. 

Even after an investment decision, a key question remains: What happens to the captured CO₂? 

The economic viability of CCUS in gas engine systems depends on a well-balanced interplay between capital and operating costs, the regulatory and technological framework, and the ability to secure reliable long-term revenue streams. 

A diversified approach underpins the most promising CCUS business models, as confirmed by current studies and market data. Major revenue streams include: 

• Sale of purified CO₂ to sectors with strong demand, such as the chemical, food, and beverage industries. 
• Avoidance of carbon costs, including CO₂ taxes or the purchase of emissions certificates under schemes like the EU ETS. 
• Participation in carbon credit markets to monetise emission reductions. 

Figure 8 illustrates CO₂ prices across various markets. The continued rise in carbon prices, which are expected to persist, further reinforces the economic rationale for CCUS adoption. Operators that integrate CCUS into gas engine systems can not only reduce regulatory compliance costs but also benefit from direct savings, helping to offset the high initial investments and improve the long-term financial outlook. [18], [19] 

In addition, the use of existing sequestration infrastructures offers an attractive business model. In regions such as the North Sea and parts of the Netherlands, there are geological storage facilities that have been successfully tested in current pilot projects (e.g., from the European CCS Demonstration Project Network). Long-term offtake agreements based on this infrastructure can ensure stable revenue streams and support the economic viability of CCUS plants in gas engine systems. [20] 

Government subsidies and incentive systems are also of central importance. While countries such as Norway, USA, Canada, and Australia already have targeted funding programmes for CCUS, in Central Europe the funding landscape is more limited and less mature. Although European instruments such as the European Innovation Fund provide a basis, dedicated national programmes specifically addressing the challenges of CCUS in gas engine systems are still underdeveloped or lacking. A targeted focus on pilot projects and demonstration projects could pave the way to scaling and underline technological maturity. [20], [21] 

Market-based mechanisms are also being discussed, such as capacity payments or subsidies for low-emission electricity from CCUS systems. In the UK, for example, the extent to which operators can receive higher remuneration for the use of CCUS in power plants is being examined, a concept that should also be considered in Central Europe. 

Overall, the business model for CCUS in gas engine systems is based on several pillars: 

• the sale of CO₂ as an industrial raw material 
• ETS or carbon tax savings 
• use of existing sequestration infrastructures 
• targeted government subsidies and market-based incentives 

A combination of these approaches, supported by current scientific data and pilot projects, forms the basis for viable business models that can contribute to the decarbonisation of energy generation in Central Europe in the mid- and long term. 

Table 2 summarises once again all essential and potential business models for CCUS. 

The long-term success of CCUS in gas engine systems depends on innovative business models and their practical implementation. The Worksop pilot project in the UK demonstrates that CO₂ capture is more than a theoretical concept (Figure 9). 

Developed by Landmark Power Holdings (LMPH) in collaboration with Victory Hill, Rolls-Royce Power Systems with its brand mtu, and ASCO Carbon Dioxide, the plant is the first real-world application of the FLEXPOWER PLUS® concept. It combines modular power generation with integrated carbon capture, delivering 10 MW of clean, flexible dependable electricity and supporting the energy transition. 

Key features of the Worksop plant: 

• efficient, flexible and dependable power generation Modular design improves efficiency and grid priority. Proven technologies from Rolls-Royce (mtu gas gensets), Turboden Mitsubishi (high-temperature ORC turbine) and Climeon (low-temperature ORC turbine ensure high overall electrical efficiency and grid stability. 
• Carbon Capture Utilisation (CCU): ASCO’s CCU modules capture CO₂ and convert it into food-grade quality, turning emissions into a revenue stream while reducing environmental impact. 

One of the biggest challenges in CO₂ capture is cost. Worksop addresses this through a circular economy approach, selling captured CO₂ under a long-term offtake agreement with Buse Gase Ltd, guaranteeing stable income and demonstrating a scalable business model. 

By integrating CCU with flexible power generation, the plant delivers low-carbon, adaptable electricity and supports grid stability, critical for managing intermittent renewables. Long-term purchase agreements for CO₂ and electricity further strengthen its economics. The FLEXPOWER PLUS^® solution is transferable to other regions and industries, offering a replicable and scalable model for decarbonising sectors that are hard to electrify. 

Looking ahead, Landmark Power Holdings, in collaboration with Rolls-Royce mtu and ASCO, is progressing a modular, containerised solution based on FLEXPOWER PLUS^® technology. This next-generation system is conceived as a standardised, rapidly deployable plant that provides clean and cost-effective power generation. Its modular design facilitates swift market entry and adaptation to varied site conditions and production requirements. 

Furthermore, the containerised version presents potential as a “behind-the-meter” solution, enabling industries such as data centres, food and beverage manufacturers, and large-scale production facilities to generate low-carbon electricity on site. This reduces dependence on the national grid and lowers operational costs. This ongoing development aligns with the focus on scalable, flexible CO₂ capture solutions 

Establishing a strategic trajectory for CCUS is essential to build on existing momentum, particularly in the UK, where schemes like the Net Zero Innovation Portfolio and Cluster Sequencing Model have proven economic viability for CCUS projects, and recent government investments in clusters like HyNet and the East Coast cluster further confirm commitment. [27] However, this progress is only the beginning. Continued advancement requires sustained policy support, technological innovation, and cooperation among industry, research institutions, and government.  

Public awareness has surged across Europe, especially in Germany, with prominent advocates such as BDI, DGB, NABU, and WWF supporting CCUS as a critical climate solution. [17] This is reflected in Germany’s May 2024 national CCUS strategy targeting unavoidable CO₂ emissions [28] and parliamentary discussions in September 2024 on amending the Carbon Dioxide Storage Act (KSpG) to enhance regulatory clarity [29], despite these advances, further action is needed to fully embed CCUS within national energy strategies. 

At the EU level, mechanisms such as the Green Deal and Innovation Fund finance large-scale decarbonization projects [30], yet bespoke support for CCUS in gas engine systems is still missing. [31] Filling this gap will require dedicated grants, tax breaks, and infrastructure incentives. In the UK, funding is expanding: the Net Zero Innovation Portfolio was updated in April 2024 to support CO₂ transport and storage infrastructure [32], and the government plans four fully operational CCUS clusters by 2030, bolstered by recent spending review commitments. [33]

In the US, the Inflation Reduction Act (2022) revamped the 45Q tax credit to provide up to $85 per ton for permanently stored CO₂ [34], though its value is being debated in 2025 for adjustments amid inflation pressures. [35] Additionally, the US Department of Energy’s Title 17 Clean Energy Financing Program continues to offer loan guarantees for CCUS infrastructure under new interim funding rules established in 2023. [35] Ultimately, CCUS can meet global mitigation goals only if regulatory certainty, innovation, industrial participation, and social acceptance move forward together. 

Carbon capture is a critical technology for industries seeking to reduce emissions while maintaining energy security. As renewable energy continues to grow, gas-powered solutions with integrated carbon capture offer a practical and low-emission bridge, particularly for operations that require stable and dispatchable power. With the emergence of modular and decentralised systems, carbon capture is now viable not only for large-scale utilities but also for industrial sites requiring localised, low-carbon power.  

For companies facing rising carbon costs and tightening regulatory standards, carbon capture ensures long-term compliance and unlocks new economic opportunities. Captured CO₂ can be monetised in various sectors such as food and beverage, chemicals, or construction materials, creating additional value beyond electricity or heat generation. When paired with engine-based gas power generation applications, carbon capture enhances overall efficiency and makes business models more resilient. Rolls-Royce has already demonstrated this potential in practice. 

The Worksop project, a 10 MW gas engine power plant with integrated carbon capture located in Nottinghamshire, UK, was developed in collaboration with ASCO CO₂ and Landmark Power Holdings. It delivers low-carbon, flexible power to the grid and stands as a replicable model for industries with high energy demands and decarbonisation goals. For industrial companies requiring dependable, low-emission power with a clear path to regulatory and economic sustainability, carbon capture represents a scalable, future-proof solution. 

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