Why hydrogen colour depends on accounting, not chemistry
Hydrogen is hydrogen once it comes off the electrolyzer. What makes it "green" is entirely a function of how the electricity that split the water molecule was generated and how that pathway is measured, verified, and reported. There is no physical test that separates green hydrogen from grey or blue hydrogen at the point of delivery. The distinction lives entirely in the emissions accounting attached to it. For a country positioning itself as a major exporter of green hydrogen and its derivatives — ammonia, methanol, direct reduced iron — that accounting becomes the actual product being sold, not a compliance afterthought.
This is where the logic of the EU's Carbon Border Adjustment Mechanism becomes directly relevant, even for producers who never thought of themselves as CBAM-covered entities.
CBAM already treats hydrogen as an embedded-emissions product
CBAM's scope covers iron and steel, aluminium, cement, fertilisers, hydrogen, and electricity. Importers of these goods into the EU must report the embedded emissions of what they're bringing in, calculated on the actual production route where possible. Where actual production data isn't available or verifiable, the regime falls back to conservative default reference values — numbers set deliberately high enough that no exporter wants to rely on them long-term. CBAM is also moving toward a definitive regime with formal verification requirements, which means the bar for what counts as credible embedded-emissions data will keep rising, not staying static.
The implication for hydrogen exporters is direct: if you cannot produce verifiable, production-route-specific emissions data, your buyer inherits the default value, and that default value erases whatever premium your electrolysis pathway was supposed to justify. A green hydrogen cargo priced on the assumption of near-zero embedded carbon becomes commercially indistinguishable from a conventional pathway the moment the accounting can't back up the claim.
Where this shows up in Scope 3 terms
For the buyer of hydrogen or hydrogen derivatives — a European steelmaker, a fertiliser importer, a shipping fuel supplier — the embedded emissions of that hydrogen typically land in their Category 1 (Purchased Goods and Services) inventory. If the hydrogen is used as a fuel or feedstock further down their own value chain, it can also touch Category 3 (Fuel- and Energy-Related Activities not already counted in Scope 1 or 2). Buyers under CSRD or similar disclosure regimes need that upstream emissions figure to be defensible, not estimated, because it feeds their own reported inventory and their own double-materiality disclosures.
This is precisely where the GHG Protocol's data quality hierarchy becomes the operational bridge between an Indian producer's plant-level data and a European buyer's disclosure obligations. Spend-based estimates — inferring emissions from what was paid — are useless here; they tell a buyer nothing about whether the electrolyzer ran on solar power or grid electricity with a coal-heavy mix. Average-data approaches, using generic sector emission factors, run into the same problem CBAM's default values create: they flatten the difference between a genuinely renewable-powered producer and a marginal one. The only tier that actually supports a green hydrogen claim is supplier-specific primary data — metered renewable input, verified production-route calculations, ideally with third-party assurance behind them.
The domestic side: India's renewable build-out meets carbon market infrastructure
India's push to scale renewable generation capacity is the physical precondition for a credible green hydrogen export sector — you cannot sell embedded-emissions credibility on electrolysis powered by an unreliable or carbon-heavy grid. But the renewable capacity is only half the story. The other half is the measurement and verification infrastructure that turns renewable electrons into a documented, auditable emissions factor for a specific batch of hydrogen or ammonia.
India's own compliance carbon market, the Carbon Credit Trading Scheme, is relevant background here even though it's structured around emissions-intensity targets rather than an absolute cap, and even though it currently applies to obligated entities in energy-intensive sectors under BEE administration, building on the PAT scheme's existing infrastructure. The institutional muscle being built for CCTS — intensity measurement, reporting protocols, phased assurance — is the same kind of muscle green hydrogen exporters will need to satisfy CBAM-style embedded-emissions requests from overseas buyers. A producer that has already had to measure and report emissions intensity for a domestic compliance obligation is better positioned to generate the production-route-specific data an EU buyer's inventory demands than one starting from zero.
What exporters should be building now
Three things matter more than marketing claims about green credentials:
- Metering and traceability at the electrolyzer level. Buyers and regulators will eventually want to see the actual power input mix for a specific production run, not an annual average.
- Documentation aligned to actual-production-route methodology, not generic sector defaults, since defaults are built to be unattractive.
- Third-party verification readiness, anticipating that CBAM's definitive regime and any downstream buyer disclosure requirements will keep tightening assurance expectations rather than relaxing them.
Exporters who treat embedded-emissions accounting as core infrastructure — not a certificate purchased after the fact — will be the ones whose green hydrogen actually commands a green price. Everyone else will be selling into the default value.
Scope 3 Emissions supports embedded-emissions readiness for exporters navigating CBAM and works with organisations on India Carbon Market (CCTS) advisory. Questions on where your inventory currently stands: carbon@digi.ai.in.