The European Union's Carbon Border Adjustment Mechanism, or CBAM, entered its definitive phase on 1 January 2026. Exporters of steel, cement, aluminium, fertilisers, hydrogen and electricity into the EU now face a carbon-linked charge for the embedded emissions in their goods. The first quarterly CBAM certificate price, set on 7 April 2026 at €75.36 per tonne of CO2 equivalent, will be paid by importers from February 2027 to cover 2026 imports. That prospective cost is already shaping commercial negotiations on contracts being signed today.

For an Indian steel producer shipping hot-rolled coil to Antwerp, this means a new line on the cost sheet. For a cement producer in the Gulf or an aluminium exporter in Southeast Asia, it means the same. The charge is separate from freight, insurance and customs duty, and it grows as free allowances under the EU Emissions Trading System are phased out. CBAM is not a future risk to be modelled in a strategy deck. It is a near-term financial impact reshaping margins, contracts and competitiveness now.

 

How CBAM works

CBAM requires importers to report the embedded emissions in covered goods, buy certificates to match those emissions, and pay a price linked to the EU Emissions Trading System, where allowances have traded between roughly €60 and €90 per tonne over the past year. For 2026, the certificate price is set quarterly. From 2027, it shifts to a weekly average tracking the EU carbon market in close to real time. Once the system is fully phased in by 2034, free allowances under the EU ETS will be gone and the full carbon cost will pass through to imports.

CBAM functions as a carbon tariff. The EU prefers the term "adjustment" because the design intent is to equalise carbon cost exposure between EU-produced and imported goods rather than to penalise trade. The practical experience for an exporter, however, is comparable to a tax. Higher emissions translate into higher landed cost.

💡In the first week of January 2026 alone, more than 4,100 EU operators secured CBAM authorised declarant status, and 10,483 customs declarations covering 1.65 million tonnes of CBAM-covered goods were validated through integrated customs systems. The compliance machinery is no longer being tested. It is running.

 

Exposure beyond the EU

CBAM is widely misread outside Europe as a European problem. The mechanism is a trade policy with climate intent, and the exposure sits squarely with exporters in India, Southeast Asia, the Middle East, North Africa and parts of Latin America. Producers selling into Europe face commercial pressure on multiple fronts when their buyers begin paying the CBAM bill. Buyers can negotiate price concessions to offset the carbon cost, demand verified emissions data to reduce the assessed exposure, switch to lower-carbon suppliers, or pursue some combination of all three. None of these outcomes favour high-emission exporters with thin margins.

For India, the implications are immediate. Roughly 90 percent of India's CBAM-exposed exports to the EU come from iron and steel, according to a recent CSEP analysis. Most of that steel is produced through the blast furnace and basic oxygen furnace route, which emits about 2.5 tonnes of CO2 per tonne of crude steel, well above the global average of around 1.85 tonnes. The Global Trade Research Initiative has estimated that Indian exporters may need to cut prices by 15 to 22 percent to absorb the carbon cost.

Southeast Asian aluminium and cement producers face a similar squeeze. Middle Eastern fertiliser exporters, long competitive on cheap natural gas feedstock, face a carbon adjustment that is indifferent to feedstock prices. CBAM is not a climate policy aimed at distant 2050 targets. It is a trade policy with near-term cost effects, and treating it as the former has been one of the most expensive misreadings of the past three years.

 

Sectors most exposed in the first phase

CBAM's initial scope covers six product categories. Each shares two characteristics: high emission intensity and thin global trade margins.

• Steel. Using default emission values, Indian blast-furnace-based hot-rolled coil faces a CBAM cost of roughly €254 per tonne, according to Argus and Fastmarkets calculations published in early 2026. Turkish steel, which leans heavily on electric arc furnaces and recycled scrap, faces about €100 per tonne. Vietnamese steel, around €94 per tonne. The same product carries very different carbon costs depending on the production route.
• Aluminium. Chinese unwrought aluminium, where production is heavily coal-powered, carries a default CBAM cost above €144 per tonne. Indian aluminium, around €50 per tonne. The price differentials that once defined competitiveness are being rewritten by carbon intensity.
• Cement. Process emissions from limestone calcination cannot be eliminated by switching fuels. Carbon capture is the primary route, and it is expensive.
• Fertilisers, hydrogen and imported electricity. These complete the first wave. By the time CBAM is fully phased in, it will cover more than half of the emissions in EU ETS-covered sectors.

Cost absorption varies by producer and buyer. High-emission producers with limited pricing power will see thinner margins. Producers able to pass costs to EU buyers will retain margin but risk losing volume to lower-carbon competitors over time.

 

Data quality drives CBAM costs

High-quality emissions data lets companies avoid conservative default values and reduce their CBAM liability. Importers can report verified actual emissions or fall back on default values published by the European Commission. The defaults are set above plant-level actuals to incentivise verified reporting and protect against carbon leakage, and they will be marked up by 10 percent in 2026, 20 percent in 2027 and 30 percent from 2028 onwards.

Many companies in India, Southeast Asia and the Gulf have never measured emissions at the installation level. Plant-level monitoring is patchy. Verification protocols aligned to the EU's methodology are rare. Documentation that can survive a third-party audit is rarer still. Where verified data are missing, default values apply, and they are higher than the actual emissions of most modern, reasonably efficient plants. The exporter ends up paying for emissions it did not produce.

💡Data quality is a direct line item on the cost sheet. A producer with verified, installation-level emissions data can quote a lower landed price into Europe than a competitor with identical real emissions but no audit trail. The carbon price is the same. The visibility is not.

 

Investment needs for decarbonising hard-to-abate sectors

CBAM is widely framed as a penalty. It is also creating pressure for investment in lower-carbon production. Reducing emissions in steel, cement and fertilisers requires capital, often very large amounts of it, in hydrogen-ready direct reduced iron plants, electric arc furnaces powered by renewables, carbon capture and storage, energy efficiency upgrades and process electrification. None of these investments are cheap, and almost none pay back in a quarter.

This is the territory of transition finance. Banks, development finance institutions and multilateral lenders have built frameworks, taxonomies and dedicated transition finance teams over the past three years to fund the journey from a coal-heavy steel mill today to a low-carbon plant in a decade. The numbers are large. Around 30 trillion US dollars of additional investment is needed across eight hard-to-abate sectors, including steel, cement, aluminium and primary chemicals, to reach net zero by 2050, according to the World Economic Forum's Net Zero Industry Tracker 2024. CBAM is doing what carbon prices are designed to do, which is making the investment case for decarbonisation harder to ignore.

 

Bottlenecks in transition finance

The frameworks exist. The capital exists. Deal flow remains constrained. Several factors explain the friction.

• Weak transition plans. Many companies in hard-to-abate sectors do not yet have credible plans, with board endorsement, capital expenditure aligned to interim milestones and verifiable targets.
• Scarce bankable assets. Banks have plans, but the bankable assets to fund are scarcer than the marketing suggests.
• Contested project eligibility. Eligibility criteria under various transition finance frameworks remain contested.
• Technology uncertainty. Particularly in green hydrogen and carbon capture, technology uncertainty makes long-term cost curves difficult to underwrite.

Hard-to-abate sectors do not fit cleanly into traditional green finance taxonomies. A steel mill cutting emissions from 2.5 tonnes to 1.8 tonnes of CO2 per tonne of crude steel is making real progress, but it is not "green" in the binary sense the early sustainable finance market preferred. Newer credibility ladders, distinguishing transition-ready issuers from those with weaker plans, are an attempt to bridge that gap. They are still maturing.

💡A joint ADB, ERIA and METI report flags that hard-to-abate sectors, primarily power, steel, cement, chemicals and transport, account for more than 70 percent of projected emissions in Southeast Asia in 2025. These are precisely the sectors where transition finance is most needed and where deal flow is slowest.

The result is a pipeline that looks healthy on paper and moves slowly in practice. Tailored sectoral pathways, rather than one-size-fits-all green labels, are likely to be the unlock.

 

Transition washing risks

As capital begins to move, a credibility risk is moving with it. Transition washing occurs when companies overstate decarbonisation plans to attract financing, banks finance projects with weak emissions logic to meet portfolio targets, targets are missed quietly, and plans are revised retroactively. The cumulative effect is an erosion of trust in the very mechanism designed to fund the transition.

The signals are visible. RepRisk's 2025 data flagged 19 percent more banking and financial services organisations for greenwashing risk than the previous year. Several large banks, including HSBC and most major US and Canadian institutions, have stepped back from the Net-Zero Banking Alliance under political and regulatory pressure. Regulators in the EU and UK are tightening rules on environmental claims, with the EU's Empowering Consumers for the Green Transition Directive applying from 27 September 2026.

The structural tension is between speed and credibility. CBAM and similar mechanisms create urgency, and urgency rewards speed. Credibility, the kind that can survive third-party verification and litigation, requires methodical work. Institutions that solve for both will define the next phase of transition finance.

 

Distributional effects: exporters that benefit and exporters that face higher costs

Exporters that benefit:

• Low-emission producers with renewable-powered electric arc furnaces, recycled feedstock or efficient process design.
• Companies with mature emissions data systems and audit-ready documentation.
• Early movers on transition planning, particularly those with bankable projects in the pipeline.
• Producers in jurisdictions with credible domestic carbon pricing, since carbon prices already paid can be deducted from CBAM liability.

Exporters that face higher costs:

• High-emission exporters reliant on coal-heavy production.
• Companies with poor transparency or no installation-level data.
• Late adopters who treated CBAM as a 2030 problem.
• Exporters in countries that have resisted domestic carbon pricing, who now find themselves paying carbon costs to the EU rather than to their own treasuries.

Early evidence indicates CBAM is reshaping global trade flows. Indian steel exporters are pivoting toward the Middle East and Africa. China has accelerated its own ETS expansion, with coverage extended to steel, cement and aluminium and a move toward absolute caps planned from 2027. Turkey, India, Vietnam, Brazil and Indonesia have all moved on domestic carbon pricing, partly in response to the trade pressure CBAM creates and partly to ensure that any carbon revenue is collected at home. The UK launches its own CBAM in January 2027. Australia's 2026 carbon-leakage review has recommended that a border carbon adjustment be considered.

 

Steps for exporters to manage CBAM exposure

• Measure emissions at the asset level. Installation-level data, calculated using EU-aligned methodologies and ready for third-party verification, often produces a lower CBAM cost than commercial negotiation can.
• Build internal data infrastructure. Spreadsheets and once-a-year sustainability reports will not survive the definitive phase. Continuous, verifiable emissions data integrated with production records is now a basic requirement.
• Engage with banks early. Transition finance does not arrive at the moment a project is shovel-ready. It typically requires months of structuring, plan validation and pathway alignment before a deal closes.
• Develop a credible transition plan with funded capex and interim milestones. Frameworks now distinguish transition-ready issuers from those with weaker plans. The difference is governance, board approval, milestone discipline and capital actually allocated.
• Engage policymakers on domestic carbon pricing. Because carbon prices paid in the country of origin can be deducted from CBAM liability, jurisdictions without domestic pricing transfer revenue to the EU that could otherwise fund local industrial transition.

 

CBAM as a trade cost

CBAM is the most consequential climate policy currently affecting global trade. The mechanism has been live since January 2026, the first certificate price has been published, and exposure is being measured in commercial negotiations rather than position papers. The UK follows in 2027. Australia is openly reviewing the same instrument. Other jurisdictions are watching closely.

CBAM costs are now embedded in commercial negotiations with EU buyers. Exporters that have built reliable emissions data and credible transition plans will retain market access and competitiveness. Those that have not will face higher costs, lost volume and reduced strategic optionality as similar mechanisms spread to other markets.