Somewhere beneath the Bay of Bengal, at depths where light does not reach and pressure crushes steel, lies what Indian petroleum geology has been pointing toward for two decades. The Union Cabinet approved the ₹84,000 crore Samudra Manthan scheme last week — five years, offshore deepwater blocks, and an ambition to structurally rebalance a country that imports nine barrels of crude oil for every ten it burns. The name is well chosen. In the ancient myth, gods and demons churn the cosmic ocean together to extract the nectar buried within. The economics of deepwater exploration carry a similar logic: enormous effort, uncertain yield, and the prize locked far below the surface.
The Declining Baseline
The case for urgency is straightforward. In FY26, India produced about 28 million tonnes of crude oil, down from 28.7 million tonnes the previous year. Natural gas output fell too — 34,776 million standard cubic meters in FY26, compared with 36,113 mscm in FY25. These are not rounding errors. They represent a production base in structural retreat even as consumption surges: India's petroleum product consumption hit a record 241.6 million tonnes in FY26. The gap between what India produces and what it consumes is not a cyclical problem to be managed quarter by quarter. It is a structural fact of the Indian economy.
Oil and gas fields decline by around 6–7% annually through natural depletion. Every year without new production coming online, the baseline slips further. India's onshore and shallow-water assets — the workhorses of domestic supply for decades — are ageing. The frontier, as the Ministry of Petroleum and Natural Gas has argued, lies in deepwater sedimentary basins: the Krishna-Godavari, Cauvery, Mahanadi, and the Andaman region.
What Deepwater Actually Costs
Deepwater exploration is not a matter of sending a rig to sea and hoping for the best. The technical definition alone signals the difficulty: hydrocarbon reservoirs in ocean depths generally exceeding 200 metres, with ultra-deepwater extending beyond 1,500 metres. A single exploratory well in these conditions costs approximately $125 million to $150 million. Not a producing well. An exploratory well — one drilled to determine whether a reservoir exists, before a single barrel has been extracted commercially.
That cost figure is clarifying in several ways. It explains why India's state-owned producers have been reluctant to move aggressively into deepwater without fiscal support. It explains why the ₹84,000 crore scheme exists — to de-risk the exploration phase enough to attract capital that would otherwise flow to shallower, cheaper prospects elsewhere. It immediately raises the central question the scheme must answer: who, exactly, will drill these wells?
ONGC has the mandate and the offshore experience. It does not have the deepwater operational record that the Krishna-Godavari basin's most demanding geology requires. The wells that will ultimately matter — ultra-deepwater, complex reservoir structures, subsea completions in harsh conditions — demand technology that Brazil's Petrobras developed over decades in the Santos Basin, that bp and TotalEnergies have refined in the Gulf of Mexico and West Africa. India can buy that technology through joint ventures and farm-in agreements. The question is whether the fiscal terms Samudra Manthan offers will make India's deepwater blocks genuinely competitive against Angola, Guyana, or the Brazilian pre-salt, all of which are competing for the same pool of supermajor capital and engineering bandwidth.
The Scale of the Ambition
The scheme's targets are specific enough to be held accountable. Domestic oil and gas production is to rise from around 62 million metric tonnes of oil equivalent annually to 80 MMTOE. India's hydrocarbon resource base is to expand from 1.6 billion tonnes of oil equivalent to 2.2 billion TOE. If deepwater production reaches the levels the scheme projects, the additional output has the potential to reduce crude oil imports by nearly ₹1 trillion annually.
A trillion rupees in avoided imports is current account relief, rupee support, and a reduction in fiscal exposure to every Middle East supply disruption, every OPEC+ production cut, every spike in Brent crude. Such swings impose costs on Indian households through fuel prices and imported inflation. The macroeconomic logic of Samudra Manthan is therefore not just an energy story. It is a currency story and a foreign policy story simultaneously.
Why the Comparison to Brazil Matters
India is not the first country to bet its energy future on deepwater. Brazil's decision in the mid-2000s to pursue pre-salt deepwater development at scale — politically risky, technically daunting, fiscally expensive — transformed the country from a significant oil importer into a major exporter over roughly fifteen years. Guyana, a country with no prior oil industry, discovered deep offshore reserves that are now reshaping its entire economic trajectory. Neither story was linear. Both required sustained regulatory commitment across multiple governments, competitive fiscal terms that attracted international operators, and a willingness to accept that deepwater investment operates on a fundamentally different time horizon than onshore development.
India's upstream sector has been chronically under-invested relative to the geological potential its Exclusive Economic Zone represents. The Hydrocarbon Exploration and Licensing Policy framework and the Open Acreage Licensing Policy already signal a liberalised approach. Samudra Manthan extends that liberalisation specifically into the deepwater domain, with revenue-sharing contracts designed to attract operators who need both technical confidence and fiscal predictability before committing capital measured in the hundreds of millions of dollars per well.
The tension the scheme exposes is institutional as much as geological. ONGC's balance sheet and technical bandwidth have been constraints on deepwater ambition before. Samudra Manthan's success likely requires either a genuine reform of how PSU operators approach deepwater risk, or a clear consortium model in which private and international operators carry a larger share of both capital and operational responsibility — with technology transfer obligations written into contracts so that India builds deepwater capability rather than simply leasing it indefinitely.
The Regulatory Continuity Problem
Deepwater exploration is a bet on the future made in the present. From the moment a block is licensed to the moment it produces commercially takes — at minimum — a decade, and often longer. That timeline spans multiple Union budgets, multiple petroleum ministers, potentially multiple governments. The fiscal terms that make a block attractive today must remain credible through election cycles and commodity price swings. International operators are pricing geological risk. They are also pricing regulatory continuity risk.
India's track record on this dimension is mixed. The HELP framework was a genuine improvement over the Production Sharing Contract regime that preceded it. But the upstream sector has seen enough mid-course policy changes — on gas pricing, on profit-petroleum splits, on cost recovery mechanisms — that international operators retain a residual wariness. Samudra Manthan's five-year frame is a start. The deeper assurance it needs to provide is that the terms written today will still be honoured when the first deepwater well in the Andaman basin actually encounters a reservoir worth developing.
None of this diminishes the strategic logic of the scheme. India consumes at a scale that its domestic production cannot come close to matching, and that gap grows every year that the economy expands and vehicle ownership rises. Renewables will displace some oil demand over time, but the transition runs on decades, not years. In the interim every barrel produced domestically is a barrel not imported. Samudra Manthan is the right instrument toward an unavoidable objective. The geology of the KG basin, the Mahanadi, and the Andaman region genuinely holds potential that onshore India cannot replicate. Whether that potential converts into production depends on execution — on the quality of the fiscal terms, the seriousness of the technology partnerships, and whether Indian regulators and PSU reformers can hold their nerve across the decade-long horizon that deepwater demands.
