The EU Emissions Trading System (EU ETS) strengthens the business case for alternative fuels by making fossil fuel combustion progressively more expensive. Every tonne of CO₂ an industrial facility emits requires a purchased allowance, and as the carbon price rises, the operating cost gap between fossil fuels and low-carbon alternatives narrows, and can eventually close. For sustainability managers in energy-intensive industries, understanding how ETS carbon pricing works is no longer just a compliance exercise: it is a core input into investment decisions about decarbonized heat solutions.
How does the EU ETS carbon price actually get calculated?
The EU ETS carbon price is determined by supply and demand for emission allowances (EUAs) within a cap-and-trade system. The EU sets a total cap on emissions, issues a fixed number of allowances, and reduces that cap each year. Companies buy, sell, or receive allowances and must surrender one EUA for every tonne of CO₂ they emit. The price emerges from trading on exchanges like ICE and EEX.
Several factors push the price up or down in practice. Cold winters increase energy demand and drive up allowance purchases. Policy decisions, such as the Market Stability Reserve, which removes surplus allowances from circulation, tighten supply and support higher prices. Conversely, economic slowdowns reduce industrial output and can soften demand for allowances.
Since 2021, the ETS has been reformed significantly. The annual reduction rate of the cap was increased, free allowances for industry are being phased down, and the Carbon Border Adjustment Mechanism (CBAM) is expanding the system’s reach. These structural changes mean the carbon price trajectory is broadly upward over the long term, even if short-term volatility remains a factor in financial planning.
Which industrial sectors are covered by the EU ETS?
The EU ETS covers power generation, heavy industry, and aviation within the EU, plus maritime transport from 2024 onwards. On the industrial side, sectors such as steel, cement, glass, ceramics, chemicals, paper, and food processing are all included when their installations exceed defined emissions thresholds. This means the decarbonization of industrial heat is directly subject to ETS compliance costs.
For sustainability managers in food and beverage, specialty chemicals, and pulp and paper, three of the most heat-intensive manufacturing sectors, the ETS creates a direct financial incentive to reduce Scope 1 emissions. Each megawatt-hour of heat currently generated by natural gas carries an embedded carbon cost that grows as the carbon price rises.
It is also worth noting that the EU is expanding ETS coverage. ETS2, entering into force in 2027, will extend carbon pricing to buildings and road transport, signaling a broader political commitment to pricing carbon across the economy. Industrial operators who act early on fuel switching will be better positioned than those who wait for compliance pressure to peak.
How does a rising carbon price change the economics of fossil fuel heat?
A rising carbon price directly increases the effective cost of burning fossil fuels for heat. Natural gas combustion emits roughly 0.2 tonnes of CO₂ per megawatt-hour of thermal energy. At a carbon price of €60 per tonne, that adds €12 per MWh to your gas bill. At €100 per tonne, the carbon surcharge reaches €20 per MWh, a substantial addition to already volatile energy prices.
This is where the CAPEX versus OPEX calculation for alternative fuels begins to shift. A low-carbon heat technology may require higher upfront capital investment, but as the carbon price rises, the ongoing operational savings from avoided allowance purchases grow year on year. The higher the carbon price, the shorter the effective payback period for the switch.
Grid congestion and security of supply add further pressure to the fossil fuel status quo. For many industrial sites, full electrification is constrained by grid access limitations, making the replacement of natural gas with a non-electric alternative particularly attractive. The combination of rising carbon costs, volatile energy prices, and infrastructure bottlenecks creates a strong structural argument for fuel diversification, and for technologies that can deliver reliable industrial heat without grid dependency.
What are the main alternative fuels competing to replace fossil heat?
The main alternatives currently competing to replace natural gas and other fossil fuels in industrial heat generation are green hydrogen, biomass, electrification (via heat pumps or electric boilers), and emerging options such as iron fuel. Each has a different profile in terms of carbon intensity, infrastructure requirements, cost, and operational fit.
- Green hydrogen offers zero direct emissions but faces significant challenges: high production costs, limited pipeline infrastructure, safety requirements for storage, and energy losses in conversion make it a difficult near-term fit for many industrial sites.
- Biomass can deliver high-temperature heat and is compatible with existing boiler infrastructure, but sustainability certification requirements, feedstock availability, and air quality concerns are growing constraints.
- Electrification works well for low-temperature heat but struggles to reach the temperatures many industrial processes require. Grid congestion and high connection costs are additional barriers for many sites.
- Iron fuel is a newer option that burns iron powder to produce high-temperature heat with zero direct CO₂ emissions. The combustion leaves only iron oxide, which is regenerated using hydrogen in a closed loop. It is transportable in standard containers, does not require grid upgrades, and integrates with existing boiler infrastructure.
No single alternative is right for every application. The optimal choice depends on process temperature requirements, site infrastructure, available capital, and the carbon price trajectory assumed in financial modeling.
When does switching fuel become financially worthwhile under ETS pressure?
Switching fuel becomes financially worthwhile when the total cost of ownership of the alternative, including capital investment, fuel cost, and operational changes, falls below the projected cost of continuing to burn fossil fuels, including rising ETS compliance costs. The carbon price level at which this crossover happens is called the “break-even carbon price,” and it varies by technology and site.
Several variables determine when the economics tip in favor of switching:
- Current carbon price and trajectory: The higher the expected long-term carbon price, the sooner the payback period for a capital investment in alternative heat technology.
- Fossil fuel price volatility: Volatile energy prices increase the risk of staying with gas and strengthen the case for a more predictable alternative fuel cost structure.
- Available incentives: EU Innovation Fund grants, national subsidy schemes such as the Dutch VEKI program, and tax incentives like the EIA (Energie-investeringsaftrek) can significantly reduce the effective CAPEX burden and shorten payback periods.
- Carbon leakage protection: Some sectors still receive free ETS allowances, which reduces the immediate cost pressure. As free allocations are phased down, the financial urgency of switching increases.
- Infrastructure costs: Technologies that require major grid upgrades or new pipeline connections carry higher effective CAPEX, which delays break-even.
For many industrial operators in 2026, the combination of a structurally rising carbon price, reduced free allocations, and available grant funding means the window for financially attractive fuel switching is open, and narrowing for those who delay.
How should sustainability managers build the internal business case?
Sustainability managers should build the business case for fuel switching by framing it as a financial risk management decision, not just a climate commitment. The core argument is that continuing to rely on fossil fuels exposes the business to rising ETS compliance costs, volatile energy prices, and regulatory risk, all of which are quantifiable and growing. The alternative technology must then be evaluated on total cost of ownership, not just upfront CAPEX.
A strong internal business case typically includes the following elements:
- A carbon price sensitivity analysis showing the break-even point under conservative, central, and high price scenarios
- A comparison of CAPEX versus OPEX trade-offs between the fossil fuel baseline and the proposed alternative
- An assessment of available public funding, including EU Innovation Fund grants, VEKI subsidies, and EIA tax deductions
- A risk-adjusted view of security of supply, factoring in grid congestion and fossil fuel price volatility
- A clear timeline for regulatory changes, including the phase-down of free ETS allowances in the relevant sector
It also helps to connect the investment to board-level net-zero commitments and customer-facing sustainability targets, which are increasingly influencing procurement decisions. Framing the switch as both a cost-risk reduction and a competitive positioning move broadens the internal coalition of support beyond the sustainability function.
How Iron Fuel Technology helps with the decarbonization of industrial heat
We developed Iron Fuel Technology specifically for industrial companies facing exactly the pressures described in this article: rising ETS costs, grid congestion, volatile energy prices, and the practical limitations of hydrogen and electrification. Our Iron Fuel Boiler delivers a concrete, deployable answer to the challenge of replacing natural gas in high-temperature industrial heat processes.
Here is what makes it relevant to the business case:
- Zero direct CO₂ emissions during combustion – the only CO₂ output comes from a pilot safety flame, resulting in just 10 kg of CO₂ per MWhth, which directly reduces ETS allowance costs
- Up to 95% energy efficiency – outperforming many traditional fossil fuel boiler systems
- Grid-independent operation – iron fuel is transported in standard containers, with no need for grid upgrades or new pipeline infrastructure
- Drop-in compatibility – our boiler integrates with existing industrial setups, reducing the disruption and CAPEX associated with a full process overhaul
- Predictable fuel costs – iron fuel is priced at €140 per tonne, offering a stable cost structure compared to volatile fossil fuel markets
- Demonstrated at TRL7 – both the Iron Fuel Boiler and Iron Fuel Production system have been proven at megawatt-industrial scale in the Netherlands
We work with companies in food and beverage, specialty chemicals, and pulp and paper, sectors where the ETS compliance burden is real and the alternatives are often constrained. If you are building the internal business case for industrial heat decarbonization and want to understand how iron fuel fits your specific situation, get in touch with our team.
Frequently Asked Questions
How do I find out exactly how many ETS allowances our facility needs to surrender each year?
Your facility’s annual surrender obligation is based on its verified emissions report, which must be submitted to your national competent authority each year under the EU ETS Monitoring, Reporting and Verification (MRV) framework. You can cross-reference your historical verified emissions data with your current allocation statement to understand your net exposure — that is, the gap between free allowances received and total emissions generated. If you are new to ETS compliance, engaging an accredited verifier and reviewing your national registry account (such as EUTL) is the practical starting point.
What happens if we miss our ETS allowance surrender deadline or fall short?
Failing to surrender sufficient allowances by the April 30th annual deadline results in a penalty of €100 per tonne of excess emissions, plus the obligation to still surrender the missing allowances in the following year — so the shortfall does not disappear. The penalty is also publicly reported, which carries reputational risk. To avoid this, most compliance teams maintain a buffer of allowances and use forward purchasing strategies to hedge against price spikes in the run-up to the surrender deadline.
Our site still receives free ETS allowances — does that mean fuel switching isn't financially urgent for us yet?
Free allocations reduce your immediate cash cost, but they do not eliminate the financial logic of switching — they defer it. Under the EU ETS reform roadmap, free allocations for most industrial sectors are being progressively phased down through 2034, so the compliance cost exposure grows every year you remain on fossil fuels. It is also worth noting that free allocations are benchmarked against the most efficient installations in your sector, meaning less efficient sites already face a net cost even with partial free allocation. Modeling your break-even carbon price under the phase-down schedule now gives you the lead time to act before the financial pressure peaks.
How volatile is the EU ETS carbon price, and how should we account for that uncertainty in our investment models?
The EU ETS carbon price has historically shown significant short-term volatility — ranging from below €10 per tonne in the early 2010s to above €100 per tonne in 2023 — driven by policy changes, energy market conditions, and macroeconomic cycles. For investment modeling, the standard approach is to run sensitivity analyses across at least three carbon price scenarios: a conservative path (e.g., €60–80/tonne by 2030), a central path aligned with EU policy signals (e.g., €100–130/tonne), and a high path reflecting accelerated policy tightening. This range-based approach lets you identify the carbon price floor at which a fuel-switching investment still delivers a positive return, which is a far more defensible position in front of a CFO than a single-point estimate.
What EU or national funding sources should we explore before committing CAPEX to a fuel-switching project?
The EU Innovation Fund is the most significant source of grant funding for industrial decarbonization projects, with dedicated calls for large-scale and mid-scale projects that cover innovative low-carbon technologies including alternative fuels and heat solutions. At the national level, programs like the Dutch VEKI subsidy (for energy innovation in industry) and the EIA tax deduction scheme (Energie-investeringsaftrek) can materially reduce effective CAPEX. It is worth engaging a grant advisor early in the project development phase, as application windows are periodic and eligibility criteria often require early-stage project documentation that takes time to prepare.
How do we evaluate alternative heat technologies if our process requires temperatures above 500°C?
High-temperature process heat above 500°C is one of the most challenging segments of industrial decarbonization, and it is where several alternatives — particularly heat pumps and many electrification routes — fall short. When evaluating options for high-temperature applications, the key parameters to assess are: maximum achievable flame or steam temperature, compatibility with existing boiler or furnace infrastructure, fuel supply logistics, and the carbon intensity of the fuel on a lifecycle basis. Technologies like iron fuel and certain biomass configurations are specifically designed to reach the temperature ranges required by sectors such as ceramics, specialty chemicals, and food processing, making them more directly comparable to natural gas than electrification alternatives in these use cases.
What is the most common mistake companies make when building the internal business case for fuel switching?
The most common mistake is framing the investment purely as a sustainability cost rather than a financial risk management decision — which makes it easy for finance teams to deprioritize it against projects with clearer near-term returns. A stronger approach is to quantify the cost of inaction: model the rising ETS compliance burden under the phase-down schedule, stress-test your current fossil fuel cost exposure against price volatility scenarios, and show the narrowing payback period as carbon prices rise. Presenting fuel switching as a hedge against regulatory and energy price risk, with a defined break-even point, is typically far more persuasive to a CFO or investment committee than leading with carbon reduction targets alone.
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This content was generated with the help of AI and it may contain mistakes