Steel emissions come from two sources that are easy to confuse: the energy needed to heat and melt materials, and the chemistry used to remove oxygen from iron ore. The conventional blast-furnace/basic-oxygen-furnace (BF-BOF) route uses coal-derived coke for both jobs, while scrap-based electric arc furnaces (EAFs), hydrogen direct reduction, carbon capture and storage, and iron electrolysis change different parts of that system. None is automatically low-carbon everywhere: electricity and hydrogen supplies, scrap quality, infrastructure, costs and the emissions boundary used for comparison determine the result.
Why making steel produces so much carbon dioxide
Most steel begins as iron ore. Ore is largely iron oxide, so an ironmaking process must remove oxygen before the iron can be converted into steel. That reduction step is the central chemical source of emissions in conventional production.
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The BF-BOF route combines fuel and chemical emissions
In a blast furnace, coal is processed into coke. Coke supplies high-temperature heat and reacts with oxygen in the ore, producing carbon monoxide and then carbon dioxide as the ore is reduced to iron. The hot iron is sent to a basic oxygen furnace, where oxygen removes excess carbon and other impurities to make steel. Emissions therefore come from the coke and other fuels as well as from the reduction chemistry itself.
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Energy is only part of the footprint
Electricity, fuel extraction and transport, ore preparation, fluxes, auxiliary gases and the treatment of by-products can all affect a steel product’s lifecycle result. A plant that reports only direct emissions at its fence line may look different from one that includes electricity generation, hydrogen production, mining and transport. Comparisons are meaningful only when the boundary and allocation rules match.
Why a single “emissions per tonne” number can mislead
There is no single intensity that describes all steel. Ask whether a figure covers:
- direct process and combustion emissions at the plant;
- emissions from generating electricity or producing hydrogen;
- mining, ore preparation and material transport;
- the way emissions are allocated between primary steel and recycled scrap; and
- the grade, product form and amount of finishing included.
The available sources do not provide a directly comparable, route-by-route intensity table with one common boundary. Any ranking that omits these choices can give a false impression of precision.
How the main steelmaking routes differ
| Route | Metallic input | What supplies energy or reducing power | Main emissions questions |
|---|---|---|---|
| BF-BOF | Iron ore converted to hot metal, plus some scrap | Coke, coal and other fuels; oxygen in the converter | Carbon in coke performs chemical reduction and produces process CO2; fuel use adds more. |
| Scrap-based EAF | Mostly recycled steel scrap | Electricity melts the charge | Results depend heavily on the electricity mix, scrap preparation and the quality of steel that can be made. |
| Direct-reduced iron (DRI)-EAF | Iron ore converted to solid direct-reduced iron, then melted | Natural gas or hydrogen for reduction, electricity in the EAF | Gas operation still emits carbon; deep reductions require low-emissions hydrogen and power. |
| CCUS-equipped iron or steelmaking | Can be integrated with ore-based or other existing routes | Existing fuels and electricity, plus capture equipment | Capture rate, energy penalty and dependable CO2 transport and storage or use determine the outcome. |
| Iron electrolysis | Iron ore | Electricity drives an electrochemical reduction | Electricity carbon intensity, scale-up and commercial performance remain decisive. |
Lower-carbon pathways and what they require
Scrap-based electric arc furnaces
An EAF melts metallic feedstock with an electric arc. When the charge is predominantly scrap, the furnace avoids the ore-reduction step for that recycled portion. This can remove a major source of primary ironmaking emissions, especially where electricity is low-emissions.
Scrap is not an unlimited substitute for ore. Steel products accumulate coatings, copper and other residual elements during use and collection. Sorting and processing can improve quality, but some applications require purity that available scrap cannot consistently provide. The European Commission’s Joint Research Centre notes that scrap-based production cannot supply every value-chain application, so primary iron remains necessary for some grades and for balancing the material cycle.
Three checks are essential before treating an EAF as a low-carbon choice:
- Electricity: determine the actual grid or contracted supply mix, including whether claimed renewable power is additional and available when the furnace operates.
- Scrap: verify quantity, contamination, preparation and the proportion of the charge that is genuinely recycled steel.
- Grade: confirm that the resulting chemistry and cleanliness meet the required product specification.
Hydrogen DRI followed by an EAF
In a hydrogen-DRI plant, hydrogen removes oxygen from iron ore and leaves solid direct-reduced iron. An EAF then melts that iron, often with some scrap, into steel. Water is the direct by-product of hydrogen reduction rather than carbon dioxide from the reduction reaction.
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The climate result depends on how the hydrogen and electricity are made. Hydrogen produced with unabated fossil energy can carry substantial upstream emissions, and an EAF powered by a carbon-intensive grid can erode the benefit of changing the reductant. Ore quality, transport, storage, transmission capacity and regional energy prices also affect feasibility.
Early commercial plants using 100% hydrogen blends are estimated by the IEA to carry a 50% to 140% cost premium over BF-BOF plants operating today, with the range varying by region. This is a plant-cost comparison, not a universal change in the retail price of steel. Falling renewable-power and electrolyser costs, policy support, financing and reliable offtake could change the economics, but the premium shows why projects need more than a technical demonstration.
Natural-gas DRI as an intermediate step
Natural-gas DRI replaces the blast furnace with a direct-reduction shaft and an EAF. The configuration can be designed to use more hydrogen later, making it a potential transition route where hydrogen supply is not yet ready.
Gas-based operation is not automatically near-zero. Methane production and combustion create emissions, and the transition to hydrogen requires compatible equipment, affordable fuel and contracts for supply. The IEA reports that many announced projects described as capable of near-zero production plan to start with natural gas, while their timing for a full transition to hydrogen is unclear. A project’s “hydrogen-ready” label therefore says less than its initial operating fuel, conversion plan and procurement commitments.
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Capture equipment can remove CO2 from blast-furnace gases, reformers, direct-reduction units or other concentrated streams. Captured carbon may be transported for permanent geological storage or used in another process. CCUS can address emissions from existing assets and from process gases that are difficult to eliminate through electrification alone.
It is not a universal solution. Capture consumes energy, does not necessarily remove every source of emissions, and requires a verified capture rate. A plant also needs pipelines, shipping or other transport, a permitted storage site or credible use, monitoring and long-term liability arrangements. Regional geology, infrastructure and policy can make CCUS practical in one location and uneconomic in another.
Iron electrolysis
Iron electrolysis reduces iron ore through an electrochemical reaction instead of using carbon or hydrogen as the chemical reductant. If supplied with low-emissions electricity, it could avoid much of the conventional reduction chemistry.
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It remains an option rather than a proven universal replacement. The cited sector analysis does not establish a common commercial-readiness level, comparable cost, operating record or project performance for iron electrolysis. Treat claims about future capacity as development prospects unless a project discloses its process, power supply, scale and operating results.
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Efficiency, material efficiency and circularity
Using less steel for the same structural or functional service, extending product life, designing for reuse, improving yield and recovering more scrap reduce the amount of primary ironmaking required. These measures can cut energy and material demand across the system.
They complement route changes rather than eliminate them. A more efficient product design does not make the remaining primary production near-zero, and recycling cannot supply all future steel grades by itself.
How to compare alternatives without overstating their benefits
Use the following sequence when evaluating a plant, procurement claim or policy proposal.
- Set the boundary. State whether the comparison covers direct plant emissions, cradle-to-gate lifecycle emissions, or another boundary. Include the same stages for every route.
- Trace electricity and hydrogen. Record the generation source, location, time matching, contracts and upstream emissions. “Electric” or “hydrogen” is not a carbon intensity.
- Identify the metallic feedstock. Separate scrap, hot-briquetted iron, direct-reduced iron and ore. Record scrap share, quality and allocation rules.
- Check the steel grade. A lower-emissions route is not a substitute if it cannot meet cleanliness, alloy, strength or formability requirements.
- Include supporting infrastructure. Look for firm arrangements for power transmission, hydrogen production and delivery, CO2 transport and storage, water, rail and ports.
- Separate current operation from future capability. Ask what fuel the plant will use on its first day, what equipment must be added for conversion, who pays for it and when the change is contractually required.
- Test regional economics. Compare delivered energy, ore, scrap, carbon, transport and financing costs in the project’s location rather than applying a global average.
- Verify performance evidence. Prefer measured operating data, independently verified inventories and clear assumptions over an announced nameplate capacity.
| Question | Why it changes the answer |
|---|---|
| Is the figure direct or lifecycle? | Electricity, hydrogen, mining and transport can move a route’s result substantially. |
| What powers the furnace or electrolyser? | The same equipment can have very different emissions on different grids or fuel supplies. |
| How much suitable scrap is available? | Insufficient or contaminated scrap limits EAF substitution for primary iron. |
| What infrastructure is secured? | Hydrogen, power and CO2 networks determine whether a designed pathway can operate as advertised. |
| What is operating now? | Announced “capable” capacity may begin on natural gas and lack a firm conversion schedule. |
Costs, resources and infrastructure determine deployment
Lower-carbon steel is not one technology with one price. A hydrogen route may be attractive in a region with abundant low-cost renewable electricity, water, suitable ore and export infrastructure, but difficult where power is scarce or hydrogen must travel long distances. Scrap EAFs can be competitive where collection and sorting systems are mature, yet constrained by local scrap supply and grade requirements. CCUS depends on nearby storage and shared transport, while electrolysis depends on reliable low-carbon electricity and successful scale-up.
The IEA’s 50%–140% estimate for early plants using 100% hydrogen blends illustrates the scale of the commercial challenge. It varies by region and compares plant costs with BF-BOF plants today; it should not be read as a fixed premium for every tonne of steel or every future project.
Public policy can reduce risk through infrastructure planning, contracts for difference, carbon accounting rules, grants, loans and standards. Private buyers can provide demand certainty through multiyear offtake agreements that specify an emissions boundary and verification method.
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What announced capacity numbers really mean
Global and regional figures describe different things and should not be added together. In its 2025 steel assessment, the IEA identifies about 10 million tonnes of near-zero-emissions iron capacity planned for 2030 and just over 80 million tonnes of capacity described as capable of near-zero production. The latter category includes projects whose initial natural-gas operation and eventual hydrogen transition are not clearly scheduled.
For the European Union, the 2026 INCITE frontloading report from the European Commission’s Joint Research Centre describes approximately 17 million tonnes per year of planned DRI capacity across eight plants and about 35 million tonnes per year of planned EAF capacity across 16 installations for 2026–2030. These are EU deployment figures, not a global forecast, and planned capacity is not the same as operating low-emissions output.
When reading a project announcement, look for the final investment decision, construction status, startup date, initial fuel, power and hydrogen contracts, product qualification, emissions accounting and a funded conversion schedule. Without those details, “near-zero capable” is a design attribute rather than evidence of delivered steel.
Independent reader supportYour contribution helps us test, update, and keep practical guides available for everyone.Why demand commitments and procurement matter
New furnaces, electrolysers, pipelines and storage sites require large capital commitments before low-emissions steel has an established market. The IEA finds that current demand commitments for near-zero and low-emissions steel have not been sufficient to increase production at the pace and scale required.
Aggregated buyer commitments can create a lead market. Public procurement can specify verified emissions limits, common accounting rules and staged volumes for infrastructure, vehicles and other projects. These tools do not replace technology development, but they improve the chance that a first plant can sell its output and finance later expansion.
Policy also has to coordinate enabling systems. The IEA highlights low-emissions electricity and hydrogen, as well as CO2 transport and storage, as infrastructure priorities. Building a furnace without these connections can leave a technically capable plant operating on higher-emissions inputs.
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A region with abundant, clean electricity and accessible scrap
Prioritise a scrap-based EAF when local collection, sorting and quality controls can supply the required grades. Measure the actual electricity supply and retain a primary-iron option for products that cannot be made from available scrap.
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An ore-producing region with new renewable power and hydrogen
Hydrogen DRI-EAF can provide primary iron without coal-based reduction if hydrogen and electricity are genuinely low-emissions and available at the required scale. Confirm ore suitability, water, storage, transmission, transport and long-term offtake before committing.
An existing integrated plant near CO2 storage
CCUS may preserve parts of an operating asset while reducing emissions from concentrated streams. Evaluate capture energy use, residual emissions, pipeline capacity, storage monitoring and liability alongside the capture equipment itself.
A market that needs immediate capacity but lacks hydrogen
Natural-gas DRI-EAF can be an intermediate configuration, but only with a credible, financed route to lower-emissions hydrogen or another low-carbon reductant. Treat the initial gas period as an emissions phase, not as near-zero production.
Common mistakes and how to avoid them
- Calling every EAF low-carbon: check its electricity and scrap, not just the furnace label.
- Counting “hydrogen-ready” capacity as hydrogen production: identify the startup fuel and conversion date.
- Comparing unmatched boundaries: put direct and lifecycle figures in separate columns or recalculate them consistently.
- Assuming recycling can replace all ore: test grade, purity and regional scrap availability.
- Ignoring infrastructure: secure power, hydrogen or CO2 transport and storage before relying on the pathway.
- Using a global cost claim locally: model regional energy, feedstock, financing and logistics.
- Equating announced capacity with output: verify construction, commissioning, operating data and product qualification.
The practical bottom line for lower-emissions steel
There is no single replacement for the blast furnace. Scrap EAFs can avoid ore reduction where suitable scrap and low-emissions electricity exist. Hydrogen DRI-EAF offers a primary-steel route when clean hydrogen, power, ore and infrastructure are secured, but early projects face a substantial regional cost premium. Natural-gas DRI can bridge a transition only if its eventual conversion is credible. CCUS can reduce emissions where capture and storage networks are available, while iron electrolysis remains an option whose commercial performance is not yet established by the cited evidence. Efficiency, longer product life and circularity reduce the amount of new ironmaking needed across every pathway.
The most reliable comparison is therefore conditional: define the emissions boundary, trace the energy and feedstock, verify the grade, inspect infrastructure and distinguish operating performance from future capability. Those checks reveal whether an alternative is genuinely lower-emissions in its location rather than merely lower-carbon in name.
Further technical and policy detail is available from the IEA Breakthrough Agenda Report 2025 steel assessment, its steel and cement demand-and-supply measures report, the European Commission JRC INCITE report, the European Parliament briefing on zero-emission steel, the Energy Transitions Commission steel overview and the IEA’s Iron and Steel Technology Roadmap.
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