Samudra Manthan: India’s $10bn Bet on Deepwater Oil Exploration

India spent roughly $137 billion importing crude oil in the last fiscal year alone. Its government has now approved a programme worth approximately $8.8-10 billion designed to structurally change that equation.

Cabinet approval for the Samudra Manthan National Offshore Exploration Scheme, granted in July 2026 and amplified by Prime Minister Narendra Modi’s Independence Day address on 15 August 2026, marks India’s most ambitious push into deepwater and ultra-deepwater hydrocarbon territory. The programme opens 99% of India’s sedimentary basins for exploration, spanning the full offshore value chain from seismic data acquisition through to domestic manufacturing zones.

What follows unpacks the scheme’s four budget pillars, its risk-sharing mechanics, the tiered investment opportunity set it creates, and the honest caveats investors need before committing capital.

A $10 billion answer to a $137 billion problem

India imports close to 90% of its total crude oil requirements. Approximately half of its natural gas consumption is met through imports. The annual cost of this dependency is staggering:

• Crude oil imports: approximately $137 billion (FY2024-25)
• Petroleum product imports: approximately $24 billion
• LNG imports: approximately $15 billion

Combined, these figures represent one of the largest energy import bills of any major economy. Samudra Manthan is the Indian government’s most direct attempt to alter that structural exposure.

India’s energy security strategy extends well beyond offshore hydrocarbons, encompassing solar gigawatt targets, domestic gas infrastructure expansion, and grid modernisation programmes that collectively frame Samudra Manthan as one pillar within a much larger structural build-out.

Modi’s Independence Day address at the Red Fort placed the programme squarely within the Atmanirbhar Bharat (self-reliance) doctrine. His framing was not limited to economics.

PM Modi warned that essential commodities such as fuel, medicines, and technology are increasingly being leveraged as instruments of geopolitical coercion, and that global conflicts have exposed vulnerabilities inherent in heavy reliance on external energy supply chains.

The scale of committed capital, ₹84,084 crore, is significant. Measured against a $137 billion annual crude import bill, it is a first step rather than a solution. But the political signal it carries, that India intends to build domestic offshore capability across an entire value chain, is the more durable feature for investors assessing policy longevity.

How the ₹84,084 crore is structured across four pillars

The total corpus resolves into four distinct programme components, each mapping to a different commercial opportunity along the offshore exploration value chain.

The drilling pillar is the largest single allocation, consuming more than half the total budget. Infrastructure and services zone funding, while smaller in absolute terms, serves a distinct purpose: making marginal discoveries commercially viable and anchoring domestic equipment manufacturing respectively.

The localisation signal in Pillar 4

The ₹2,000 crore allocated to Oil and Gas Manufacturing and Services Zones carries implications beyond its relatively modest size. This pillar is explicitly intended to integrate technology transfer, capacity building, and digitalisation into the programme. For foreign companies evaluating participation, it signals that joint venture structures and technology licensing are likely to be favoured over pure export-of-services models.

The risk-sharing design that makes Indian deepwater investable

The headline budget matters less than how the money is deployed. The scheme’s commercial logic rests on a deliberate reallocation of frontier risk from private operators to the state.

Under Pillar 2, the central government has offered to fund up to 50% of eligible drilling costs per deepwater well, subject to a per-well cap of approximately ₹650-675 crore (pending finalisation of scheme guidelines, according to Indian policy and financial sources).

The precise cap figure matters for individual project economics. The more commercially significant signal is the government’s willingness to absorb frontier exploration risk on its own balance sheet.

Per-well cost-sharing mechanics are the hinge on which individual project economics turn, and the government’s decision to absorb up to 50% of eligible drilling costs per well represents a structural shift in how deepwater frontier risk has historically been allocated between the Indian state and private operators.

Three mechanisms stack to shift the risk calculus:

• Cost sharing: up to 50% of eligible drilling costs covered by the government per well
• Per-well cap: approximately ₹650-675 crore, setting clear parameters for individual well economics
• Infrastructure pre-funding: Pillar 3’s ₹10,000 crore removes the infrastructure burden from operators on remote or marginal discoveries

The intent is to materially de-risk deepwater and ultra-deepwater exploration so that global energy companies and private operators are willing to commit capital to basins that were previously commercially marginal.

This combination directly addresses the historical barrier to international participation in Indian deepwater. The question was never whether the basins held geological promise; it was whether the economics justified the risk. The government has now placed a substantial portion of that risk on its own books.

What the Arabian Sea and Bay of Bengal offer geologically

India’s deepwater and ultra-deepwater basins in both the Arabian Sea and Bay of Bengal remain significantly under-explored relative to their geological prospectivity, as assessed by the Directorate General of Hydrocarbons (DGH). The scheme’s ambition to cover 99% of India’s sedimentary basins makes this a comprehensive rather than selective programme.

India’s deepwater and ultra-deepwater basins in both the Arabian Sea and Bay of Bengal remain significantly under-explored relative to their geological prospectivity, as assessed by the Directorate General of Hydrocarbons, the upstream regulator responsible for acreage classification, resource estimation, and licensing policy across India’s sedimentary basins.

The two key basin zones present distinct characteristics:

• Arabian Sea: deepwater and ultra-deepwater zones along India’s western continental margin, with multiple geological plays identified but insufficiently tested by drilling
• Bay of Bengal: eastern offshore zones where existing discoveries in shallower waters suggest potential for deeper prospects, with large swathes of acreage still lacking modern seismic coverage

Pillar 1’s ₹28,534 crore allocation functions as the first-stage intelligence-gathering exercise. Large-scale 2D and 3D seismic surveys, combined with reprocessing of existing data, are designed to sharpen understanding of resource distribution before the drilling campaign begins. Phase I runs through FY2030-31.

AI tools and the National Data Repository as force multipliers

AI-assisted seismic interpretation is integrated directly into Pillar 1, designed to accelerate identification of viable drill targets from the vast volumes of survey data the programme will generate. The National Data Repository consolidates both historical and new seismic data, making it available to government agencies and private operators alike, a practical measure that reduces duplication and lowers the entry barrier for new participants.

Three investment time horizons embedded in one scheme

The programme’s complexity resolves into a structured opportunity ladder. Different investor profiles can locate themselves without needing to engage with the full scheme at once.

The near-term layer, seismic survey vessels, data processing firms, and AI analytics providers, carries the lowest capital risk. These companies can enter now as Pillar 1 spending begins.

The medium-term layer activates as drilling campaigns commence. Deepwater drilling contractors, well services providers, subsea engineers, and EPC contractors for common infrastructure hubs represent the core commercial opportunity for specialised offshore operators.

The long-term layer depends entirely on what the wells find. Field development operators take the longest view with the highest potential upside, while the manufacturing and services zones create a localisation imperative that shapes how foreign entrants can participate.

The caveats investors must hold alongside the opportunity

Samudra Manthan is an exploration and appraisal programme, not a production programme. Deepwater field development timelines typically extend well beyond five to seven years from initial discovery to first production. Meaningful reduction in India’s crude import bill is unlikely before the mid-2030s at the earliest.

Three watchpoints require ongoing attention:

• Timeline: Phase I runs through FY2030-31, but production impact extends well beyond that horizon. The scheme builds option value on domestic offshore resources; it does not guarantee near-term supply.
• Regulatory clarity: Detailed licensing terms, fiscal regime specifics, and dispute resolution frameworks are still to be confirmed. India’s upstream regulatory track record has been mixed, and investors will want to benchmark these terms against competing frontier basins globally.
• Exploration versus production: The scheme subsidises exploration. It cannot guarantee commercial discoveries. The payoff depends entirely on what the seismic surveys and wells actually find.

Samudra Manthan is best understood as building option value for India’s energy future. Actual import reduction depends on commercial discoveries and will play out well after FY2030-31.

Investors who enter at the seismic and services layer carry materially less capital risk than those positioning for field development. This distinction should guide exposure calibration.

This article is for informational purposes only and should not be considered financial advice. Investors should conduct their own research and consult with financial professionals before making investment decisions.

India’s offshore ambition is a multi-decade structural play, not a near-term trade

The combination of political backing (Atmanirbhar Bharat, Independence Day framing), committed capital (₹84,084 crore), and a structural import problem ($137 billion annually) makes Samudra Manthan a durable programme rather than a transient incentive. Its alignment with India’s national security posture suggests it is likely to be defended politically across election cycles.

India’s domestic energy substitution track record includes the ethanol blending programme, which successfully displaced meaningful volumes of petroleum imports through mandated blending targets and supply-side incentives, providing a policy precedent that offshore advocates cite when arguing Samudra Manthan can follow a similarly structured execution path.

The tiered investor logic is clear. Seismic and services companies carry the least risk and can enter now. Drilling and EPC contractors follow as campaigns begin. Field development operators take the longest view with the highest upside.

India imports close to 90% of its crude oil. That single figure explains why this programme was approved, why it is unlikely to be reversed, and why the investors who position early in the services layer, then scale as discoveries validate basin potential, stand to benefit most from what is fundamentally a multi-decade structural play.