Green, Grey and Blue Hydrogen in India — What the Colours Actually Mean for a Car Buyer

The colour codes are informal but well-understood across the Indian hydrogen industry and the MNRE, MoP&NG and NITI Aayog policy community. There are six common colours plus one experimental one. Each is defined entirely by the production route, not by the gas itself.

In the Indian context today, grey and brown together dominate production at roughly 5-6 Million Tonnes per year of hydrogen, almost all of it consumed inside refineries and fertiliser plants without ever entering a public distribution network. Green is under half a Million Tonnes a year as of 2026 and growing. Blue is present at a handful of captive sites where CCS has been retrofitted. Turquoise is experimental. Pink is notional — India's fuel-cycle regulator has not yet cleared large-scale nuclear-powered electrolysis for hydrogen as a routine business.

Green hydrogen is produced by feeding renewable electricity — solar, wind or hydro — into an electrolyser that splits water (H2O) into hydrogen (H2) and oxygen (O2). If the electricity is 100 percent renewable and the water is treated but not desalinated seawater, the lifecycle CO2 per kilogram of hydrogen is essentially zero — the small emissions come from electrolyser manufacturing amortised over its 25-year life.

Two electrolyser families dominate. Alkaline electrolysers are the mature, low-cost workhorse — used by L&T, Ohmium, Reliance and most Indian PLI-scheme manufacturing lines. Capital cost is roughly ₹4-6 Crore per MW installed. Proton Exchange Membrane (PEM) electrolysers are more expensive at ₹7-10 Crore per MW but start up faster, handle variable solar/wind input better and produce higher-purity hydrogen suitable for fuel-cell vehicles. A third family, Solid Oxide Electrolyser Cells (SOEC), is in pilot stage with IIT Madras and BHEL.

Indian green-hydrogen cost in 2026 is dominated by three components. Electricity is roughly 55-60 percent of the output cost — at a 3.5-4.0 rupees per kWh solar PPA, hydrogen needs about 50-55 kWh per kg, which works out to ₹175-220 per kg from electricity alone. Electrolyser capex amortisation is another ₹80-120 per kg. Water, compression, purification, storage and margin add the rest. The total today sits in the ₹350-450 per kilogram band for most commissioned Indian green-hydrogen projects.

The NGHM target is to drive this figure below ₹200 per kilogram by 2030 through three levers. Cheaper renewable electricity (sub-2.5 rupees per kWh is already being contracted at large solar parks in Rajasthan and Gujarat), domestic electrolyser manufacturing scale through the PLI-Electrolyser programme worth ₹4440 Crore, and larger project scale from pilot single-MW plants to 100-500 MW gigawatt-class facilities of the kind Reliance is building at Jamnagar.

Grey hydrogen is produced from natural gas (predominantly methane) via Steam Methane Reforming (SMR). At around 700-1000 degrees Celsius and 15-25 bar, methane reacts with steam over a nickel catalyst to produce hydrogen and carbon monoxide. A second water-gas-shift reaction converts the carbon monoxide into additional hydrogen plus CO2. Every kilogram of grey hydrogen produced emits approximately 9-11 kilograms of CO2 into the atmosphere.

In India almost all the hydrogen produced in 2026 is grey. It is made on-site at refineries — Reliance Jamnagar, IOCL Mathura, HPCL Vizag, BPCL Kochi — to hydrotreat diesel and naphtha and reduce their sulphur content to BS6 Phase 2 specification. It is also made at fertiliser plants — RCF, GSFC, NFL, IFFCO — where hydrogen is the feedstock for ammonia, which in turn is the feedstock for urea. Very little grey hydrogen leaves the factory gate; it is consumed where it is made.

Indian cost of grey hydrogen tracks the price of imported LNG and domestic APM gas. At 2026 natural-gas prices in the 9-13 US dollars per MMBtu band, grey hydrogen in India costs roughly ₹180-250 per kilogram. That is meaningfully cheaper than today's green hydrogen, and it is why the substitution programme has to be pushed through policy — mandatory green-hydrogen purchase quotas on refineries and fertiliser plants — rather than price alone.

The MoP&NG's Green Hydrogen Purchase Obligation (GHPO) is being phased in to require refineries to source a rising percentage of their hydrogen from green sources — starting at around 1 percent in 2024-25 and rising to 10 percent by 2029-30. This policy lever, not market economics, drives most of the first-wave Indian green-hydrogen projects. Without GHPO, grey would remain cheaper on pure rupee-per-kilogram for at least the next four to five years.

Blue hydrogen uses the same SMR process as grey hydrogen, with Carbon Capture and Storage (CCS) attached to the reformer flue. The CCS unit captures 85-95 percent of the CO2 emitted during production and pipes it to a geological storage site — a depleted gas field, a deep saline aquifer, or a mineralisation reactor. The captured CO2 does not reach the atmosphere, so the lifecycle footprint of blue hydrogen is roughly 1-3 kilograms of CO2 per kilogram of H2 versus 9-11 for grey.

Blue hydrogen is more expensive than grey because of the CCS capex and operating cost — at Indian scales, adding 70-90 rupees per kilogram. So a ₹200 per kg grey production becomes ₹270-300 per kg blue. Blue is cheaper than current green but dearer than grey.

India's blue-hydrogen landscape in 2026 is small. ONGC is piloting CCS at its Ankleshwar fields in Gujarat. IOCL is studying blue hydrogen at its Gujarat Refinery. The only active blue-hydrogen-at-scale project is at Reliance Jamnagar where CCS has been retrofitted to a portion of the SMR output in the last 18 months. The rest is announcements and studies.

Blue's role in India's transition mix is debated. Critics argue that CCS infrastructure ties refineries to continued natural-gas consumption and that green hydrogen is the only truly zero-emissions end state. Supporters argue that blue is a pragmatic bridge — cheaper to deploy than green in the 2025-2030 window, and it at least addresses the 10 kg-per-kg CO2 footprint of current grey production immediately rather than waiting for green to scale.

Turquoise hydrogen is produced by methane pyrolysis — natural gas is heated to 900-1200 degrees Celsius in the absence of oxygen, which splits it into hydrogen gas and solid carbon. The solid carbon is a marketable product (used in tyres, construction and battery anodes), and no CO2 is emitted. If the pyrolysis heat itself comes from clean electricity, turquoise approaches green on carbon but uses far less water and draws on India's existing gas pipeline network. BASF, Monolith Materials and a handful of Indian start-ups are piloting the technology. No large Indian commercial turquoise plant exists in 2026.

Pink hydrogen (also called purple or red by different sources) is electrolysis-based hydrogen powered by electricity from nuclear plants. In countries with large nuclear fleets — France, the US, Canada — pink is a real option. India has operating nuclear plants (NPCIL's PHWR fleet and the upcoming PFBR) but has not yet commissioned any large-scale pink-hydrogen project. The Atomic Energy Regulatory Board, the Department of Atomic Energy and the MNRE would need to coordinate a specific regulatory pathway, and it is not yet a priority.

White hydrogen is naturally occurring hydrogen found in some geological formations — most famously in Mali where a well drilled for water accidentally released commercial-quantity hydrogen. India's Geological Survey has a small exploration budget for natural hydrogen but no confirmed commercial reserves. For now, white remains a research curiosity rather than a mainstream option.

Brown and black hydrogen — from coal gasification — still exist in India, particularly at older ammonia plants based on coal rather than natural gas. CIL and GAIL have piloted coal-gasification-plus-CCS plants that would technically produce a blue-like product from coal, but these are rare. Brown production is the most carbon-intensive (18-22 kg CO2 per kg H2) and is actively being phased out.

Reliance Industries has announced a 20 GW renewable-energy plus 5-7 GW electrolyser cluster at Jamnagar, Gujarat with a green-hydrogen production target of around 1 Million Tonne per annum by 2030. This is the single largest Indian green-hydrogen play. Some SMR capacity at Jamnagar is being retrofitted with CCS — the blue-hydrogen layer.

Adani Green is developing the Khavda renewable complex in the Rann of Kutch with a 20 GW+ renewable-energy base, a portion of which is tied to green-hydrogen electrolysis through Adani's New Industries vertical.

L&T, through its L&T Energy Green Tech arm, is building electrolyser manufacturing capacity and has committed to green-hydrogen engineering-procurement-construction projects across IOCL, GAIL and ONGC pilots.

IOCL has 12 separate green-hydrogen projects at different Indian refineries, the marquee ones being a 10000-tonne-per-annum facility at Panipat and the Faridabad pilot that fuels the Toyota Mirai. IOCL is also studying blue-hydrogen retrofits at its Gujarat Refinery.

NTPC, India's largest power producer, is developing green-hydrogen at Leh (using surplus hydro), Kawas, Vindhyachal and Ramagundam — with off-take by hydrogen-fuelled buses and trucks in pilot fleets.

GAIL and Bharat Petroleum have announced smaller regional green-hydrogen plants with a bias toward blending into existing natural-gas pipelines (the City Gas Distribution H2-blending pilot currently permits 1-5 percent H2 by volume in CNG pipelines).

JSW Steel and Tata Steel have announced green-hydrogen programmes aimed at direct-reduced-iron (DRI) steel-making — a different end-use than vehicles but consuming the same green molecule.

For how these industrial build-outs eventually flow back into the fuel options available to car buyers across conventional and low-carbon paths, our petrol vs diesel vs CNG guide maps today's choices while hydrogen remains a 2030-onward option.

India's Paris Agreement pledge at COP26 (Glasgow 2021) includes achieving net-zero greenhouse gas emissions by 2070 and a 45 percent reduction in emissions intensity of GDP by 2030 versus 2005 levels. Switching refineries and fertilisers from grey to green hydrogen is one of the largest single levers in the Nationally Determined Contributions scorecard — potentially 125-150 Million Tonnes per annum of CO2 avoided at full 5 MT green-H2 deployment.

Look at the maths per kilogram. One kilogram of grey hydrogen emits 9-11 kg of CO2. One kilogram of blue emits 1-3 kg. One kilogram of green emits near zero. Displacing 5 MT of grey hydrogen with green saves approximately 45-55 MT of CO2 per year — roughly one and a half times the annual CO2 emissions of Delhi.

For an Indian car buyer, the lifecycle CO2 comparison also matters. A Tata Nexon EV charged from the 2026 Indian grid (about 60 percent thermal) emits lifecycle CO2 of roughly 80 grams per kilometre. A Toyota Mirai running on today's IOCL-green hydrogen emits essentially zero tailpipe CO2 and near-zero upstream — probably under 20 grams per km lifecycle. The same Mirai running on grey hydrogen (hypothetically) would emit around 200 grams per km lifecycle — worse than a petrol sedan. Colour matters.

The carbon intensity of a hydrogen car is only ever as clean as the hydrogen it consumes. That is why colour certification matters for the MoRTH's proposed CAFE-like fuel-cell fleet-emissions framework and for any future FAME or PM E-Drive equivalent that might subsidise hydrogen cars.

The National Green Hydrogen Mission (NGHM) announced January 2023 has a total outlay of ₹19744 Crore through 2029-30. It has three primary sub-programmes.

SIGHT (Strategic Interventions for Green Hydrogen Transition) — ₹17490 Crore — funds two sub-schemes. Mode 1 supports domestic manufacturing of electrolysers. Mode 2 supports production of green hydrogen itself via a reverse-auction mechanism where bidders compete to supply green hydrogen at the lowest rupee-per-kilogram to government-procurement end users.

GHPO (Green Hydrogen Purchase Obligation) — a regulatory mandate on oil refineries and fertiliser plants to replace a rising percentage of their grey-hydrogen consumption with green. Starts at ~1 percent in FY2025-26, rises to ~10 percent by FY2029-30.

PLI Electrolyser — ₹4440 Crore within NGHM — drives domestic manufacturing of alkaline and PEM electrolysers. Awarded to L&T, Reliance, Ohmium and others in the first and second tranches. Target is 1.5 GW cumulative manufacturing capacity by 2030.

Hydrogen Hubs — designated clusters at Kandla, Paradip, Jamnagar, Chennai and Visakhapatnam that concentrate production, storage, blending and export infrastructure. These are also the sites that will likely see the first retail hydrogen dispensers for heavy trucks and buses.

The MoP&NG Hydrogen Roadmap published in 2024 plots the refuelling-station build-out through 2030 and is covered in detail in our companion guide hydrogen refuelling stations in India 2030.

If you are shopping for a new car in 2026, the hydrogen colour chart does not affect your choice yet — because no retail hydrogen car is sold in India (the Toyota Mirai in Delhi is a loan pilot, not a retail product).

If you are looking 5-7 years ahead and trying to understand whether hydrogen should shape your long-horizon planning, the colour chart is the single most important concept to grasp. A 2030 Indian hydrogen car will be useful only if it refuels on green or blue hydrogen at a price that meaningfully beats petrol and approaches EV running costs. Green at sub-₹200 per kg is the threshold. Blue at sub-₹250 per kg helps.

If you are comparing a hydrogen-excitement headline against an actual 2026 car decision, the practical ranking remains: battery EV for zero-emissions commuters with home charging; strong hybrid for fast-refuel long-distance users; diesel for high-mileage highway and fleet users; CNG for metro-city commuters with an existing CNG network. Hydrogen sits outside this decision for now.

If you are a fleet manager looking at buses or heavy trucks, the conversation is different. Hydrogen fuel-cell heavy commercial vehicles have a real near-term case because (a) depots can host a single-point filler avoiding the retail-network problem, (b) refuel time matters more than for cars, and (c) range and payload benefits over battery-electric trucks are significant. Pilot programmes through NTPC, Tata Motors, Ashok Leyland and Reliance are already running.

For context on the total-cost-of-ownership maths that eventually determines what an Indian buyer chooses, our petrol vs diesel break-even in India piece lays out the framework you will apply to hydrogen the moment retail prices become available.

Every hydrogen announcement you see between now and 2030 can be decoded with four questions.

First, what colour is the hydrogen? If the release says 'green hydrogen from a 500 MW electrolyser on a 2 GW solar park' — that is a real NGHM-aligned green project. If it only says 'hydrogen' with no colour, suspect it is grey by default.

Second, what is the rupee-per-kilogram target and by when? Any serious project states a landing cost — '₹180 per kg by 2028' or 'USD 1.5 per kg by 2030'. Without a price target, it is a public-relations statement.

Third, who is the off-taker? Industrial off-takers (refineries, fertilisers, steel) indicate a credible 2025-2028 project. Heavy-transport off-takers (bus fleets, truck consortiums) indicate a 2027-2030 story. Retail passenger-car references without a named fleet partner are 2030-plus aspirations.

Fourth, what is the infrastructure spine? Is there a pipeline, a dispenser network plan, a pilot station being commissioned? If a press release announces hydrogen but silent on distribution, the gas will sit at the factory gate.

Apply those four tests and most 2026 hydrogen headlines become clearer. Green, priced, off-taker-named, infrastructure-detailed equals real. Anything else is a future promise that may or may not deliver.