HPCL Delivered, ONGC Didn’t: What India’s Energy Risk Record Shows

A single deepwater well in Indian waters costs roughly 1,000 crore rupees. ONGC plans to drill 87 of them by March 2031. This is not a hypothetical risk environment; it is a live one, with tens of thousands of crores committed to projects that can fail expensively long before the first barrel flows.

At the ET Energy Leadership Summit 2026, senior executives from HPCL, ONGC, and Bharat PetroResources Ltd (BPRL) spoke candidly about how Indian state energy companies manage capital exposure in high-risk environments, not in theory but in practice. India’s energy build-out is simultaneously one of the largest infrastructure programmes in the world and one of the most geographically and operationally exposed.

The result is a portfolio of outcomes that ranges from disciplined delivery through a global pandemic to an offshore project that lost more than 18,000 crore rupees in foreign exchange savings to avoidable delay. What follows separates the strategies that have actually absorbed disruption from those that have not, and what the pattern tells investors about the structural resilience of NOC-led projects.

The four-plank framework India is using to insulate its energy supply

Before judging any single company, it helps to see the architecture all three operate inside. India’s energy security strategy rests on four deliberate planks:

• Diversification of energy supply sources across geographies and operators
• Expansion of the domestic exploration and production (E&P) footprint
• Development of alternate energy sources
• Transition toward a gas-based economy, including green hydrogen and electric vehicles

Each plank is designed to absorb a different kind of shock, which is why single-project failures need to be read against the whole rather than in isolation.

The supply diversification plank is the clearest geopolitical hedge. India has more than doubled its liquefied natural gas (LNG) source countries from 6 to 15, spreading its import dependence so that no single supplier or shipping route can hold the country hostage.

Supply chain diversification at the import level reinforces this architecture, with India’s expansion from 6 to 15 LNG source countries reflecting the same redundancy logic that HPCL applied at the project execution level in Rajasthan.

LNG source countries: from 6 to 15 More than doubling supplier geographies is not a commercial convenience. It is structural insurance against the next supply shock, backed by destination-flexible contracts that let cargoes be rerouted when a crisis hits one region.

Destination-flexible contracts matter to that logic because they turn a fixed supply arrangement into a movable one. If a geopolitical event disrupts a planned delivery, the buyer can redirect the cargo rather than absorb the loss.

The redundancy extends to physical storage. A proposed mandatory 10% extra LNG buffer at import terminals would create government-accessible emergency reserves without the cost and delay of building new underground gas storage.

Overseas equity gas positions add a further layer. Indian NOCs hold foreign assets as a hedge against domestic shortfalls, with ONGC Videsh alone maintaining a portfolio of 35 projects across 15 countries.

The breadth of this framework tells investors something important. Indian NOCs are not managing risk project by project; they are operating inside a government-designed redundancy architecture. A deepwater well that underperforms sits inside a portfolio of dozens of overseas projects and a policy structure built to absorb shocks at multiple levels, which is exactly why individual failures should not be over-weighted in isolation.

HPCL’s Rajasthan refinery shows what successful disruption-proofing looks like

If the framework sets the stage, HPCL’s Rajasthan complex is the positive control that shows the theory working under stress.

The HPCL Rajasthan Refinery Limited (HRRL) complex at Pachpadra in Balotra district carried a revised project cost of 79,459 crore rupees, with HPCL’s equity investment rising to 19,600 crore rupees. That is the scale of capital that was at risk before any risk management approach was tested.

The facility is a 9 MMTPA (million metric tonnes per annum) greenfield refinery with 2.4 MMTPA of petrochemical production capacity. It carries a Nelson Complexity Index of 17.0, a measure of a refinery’s ability to process cheaper, heavier crude into higher-value products, and a petrochemical yield of more than 26%.

That petrochemical yield is a deliberate hedge, not a technical footnote. By producing plastics and chemical feedstocks alongside fuel, HPCL insulates itself against fuel margin compression, the risk that refining diesel and petrol alone becomes less profitable as electric vehicles erode demand.

Commercial operations commenced around 22 June 2026, and the complex was officially inaugurated on 4 July 2026.

How multi-contract execution absorbed the COVID shock

The delivery is where the risk management story earns its keep. HPCL split project execution into multiple contracts and pre-built backup strategies into the development plan.

Multi-contract execution structures of the kind HPCL deployed at Pachpadra carry their own interface risks: the same parallel-stream design that insulates against single-point failure creates contractual boundaries that must be actively managed to prevent the fragmentation outcome ONGC experienced in the KG basin.

The logic is simple in structure and powerful in effect. When one contract stream stalled during the COVID-19 period, whether from workforce disruption or a supply chain constraint, the others kept moving, preventing a single bottleneck from cascading into project-wide delay.

That is what “embedded contingency planning” means in practice: not a document, but a contracting structure that kept the project advancing when a global pandemic hit its most labour-intensive construction phase.

For investors assessing HPCL’s capital discipline, the outcome is a concrete reference point. A company that structured its contracts to absorb disruption and delivered a 79,000-plus crore rupee project through COVID-era conditions is demonstrating a different level of project governance than a peer that simply hoped conditions would hold.

The mindset extends beyond the current cycle. HPCL is already moving into green hydrogen and energy hubs, evidence that the same forward planning is being applied to the next transition rather than treated as a one-off achievement.

Where the model breaks: ONGC’s deepwater programme and the cost of fragmentation

Here the analysis turns. The same multi-contract logic that delivered HRRL has, in ONGC’s deepwater context, produced the opposite result, which is precisely why the strategy cannot be assumed to transfer cleanly across execution environments.

ONGC’s deepwater ambition is enormous. Under the government-approved Samudra Manthan scheme, with an outlay of 84,084 crore rupees, the company plans to invest roughly 1 lakh crore over five years and drill 87 deepwater and ultra-deepwater wells by March 2031.

The Samudra Manthan cabinet approval confirmed an outlay of 84,084 crore rupees and established the scheme’s dual mandate of accelerating domestic E&P and building deepwater technological capability, setting the formal policy baseline against which ONGC’s execution will ultimately be measured.

The ramp-up is steep:

1. FY27: 8 wells
2. FY28: 10 wells
3. FY29: 20 wells
4. FY30: 22 wells
5. FY31: 27 wells

At roughly 1,000 crore rupees per subsea production well, the financial exposure is immense, and precise well selection and project oversight become non-negotiable.

The track record complicates the ambition. ONGC’s flagship KG-DWN-98/2 deepwater project suffered major delays attributed to fragmented work packages and the use of multiple consultants, which created complex interface mismatches where one contractor’s work did not align cleanly with another’s.

This is the analytical distinction that matters. HPCL’s multi-contract model was well coordinated, so streams reinforced each other. ONGC’s fragmentation lacked that integration, so the same structural approach produced friction instead of resilience.

The cost was quantifiable. The deferred output from the KG-D5 block during a period of high global energy prices is estimated to have cost the nation more than 18,000 crore rupees in lost foreign exchange savings.

More than 18,000 crore rupees in lost foreign exchange savings That is the price of coordination failure on a single offshore block, and it lands in the same programme now scaling to 87 wells.

Worse, ONGC ultimately cut peak production estimates for the KG basin project by 35-40%, raising the concern that even a completed project may underperform its original design.

Digital monitoring as a partial answer to a structural problem

ONGC’s response includes genuine operational improvement. Roughly 4,000 wells are now connected through digital monitoring systems, giving the company real-time visibility over asset performance.

That visibility is real, but it addresses operational efficiency rather than the upstream governance and coordination failures that caused the KG basin delays. A well you can monitor in real time is not the same as a work package that was integrated correctly from the start.

The subsea tie-back strategy for aging offshore platforms is a smarter incremental play. By connecting new wells back to existing infrastructure rather than building greenfield facilities, ONGC reduces capital risk on modernisation.

The gap between deepwater ambition and KG basin execution is the single most important variable investors need to hold. The 84,084 crore rupee outlay is real, offshore accounts for roughly 70% of FY2026-27 E&P capex guidance of 30,000-32,000 crore rupees, and so is the 35-40% production cut from the last major offshore project.

Mozambique LNG: four and a half years of force majeure and what BPRL learned

If the KG basin tested coordination, Mozambique tested survival. The disruption here was not a pandemic or a regulatory delay but an active security crisis, which makes it the most extreme stress test in the analysis.

TotalEnergies declared force majeure on the Mozambique LNG project on 26 April 2021, halting the greenfield development after insurgent attacks in Cabo Delgado and freezing substantial Indian equity stakes. The suspension lifted on 7 November 2025, and a full restart was announced on 29 January 2026, a suspension of roughly 4.5 years.

Political disruption to LNG timelines is not unique to Mozambique, and the geopolitical variables that extended the force majeure period in Cabo Delgado continue to shape how export credit agencies and commercial lenders price sovereign risk in frontier energy provinces.

At restart, project progress sat at approximately 40%, with more than 4,000 workers mobilised, including more than 3,000 Mozambican nationals.

The financial scale of the disruption is best seen in the budget. The revised project budget now stands at USD 20-20.5 billion, against an original financing package of USD 15.4 billion.

USD 20-20.5 billion, up from USD 15.4 billion The delay added billions to the cost base, and the consortium had to restructure its entire financing to bridge the gap.

The restructuring is where BPRL’s resilience becomes visible. In the amended agreements, the partners proceeded without UK Export Finance and Atradius after those export credit agencies did not reconfirm their commitments, and the consortium unanimously injected additional equity representing an increase of about 10% of external financing to replace them.

The specific resilience decision matters most. Rather than standing down entirely during the 4.5-year freeze, the partners maintained progress on amended financing and long-lead procurement items, so that construction could accelerate rapidly once security conditions allowed.

That choice is what separates resilience as a stated value from resilience as a demonstrated capability. BPRL leadership frames it as an operating philosophy: not predicting every scenario, but keeping the organisational capacity to respond swiftly when circumstances shift.

To govern future risk, the consortium implemented a joint task force bound by the Voluntary Principles on Security and Human Rights, with grievance mechanisms and removal procedures built in.

For investors, Mozambique gives a precise definition of NOC resilience under maximum stress. It is not the absence of disruption, but the discipline to maintain readiness during it, with a quantifiable payoff when that discipline holds: a restart at 40% completion rather than from a cold stop.

Where the structural ceiling on NOC resilience actually sits

Step back from the individual cases and a systemic point emerges that no single story can deliver on its own. The limits on NOC resilience are not primarily operational; they are structural, sitting in regulatory friction, technology dependency, and governance frameworks that no project team can resolve alone.

The government’s own Kelkar Committee recognised the problem at the highest level. Its recommendations included:

• Greater NOC autonomy in resource allocation and farm-in/farm-out decisions
• A “positive list” of countries to expedite overseas investment approvals
• Government risk-sharing for strategically important but economically marginal projects

That these recommendations exist tells you the structural friction is acknowledged in policy. That they are not yet fully implemented tells you it has not been solved.

Regulatory disruption is a recurring drag on timelines. Changes including GST implementation, mandatory domestic steel sourcing, and local purchase preference rules have all disrupted project schedules. In one instance, ONGC reportedly attributed a KG basin delay to the refusal to approve technical partnerships with foreign operators such as Statoil and Petrobras, though this account is unverified in the available research.

Technology dependency as the binding constraint on deepwater ambition

Deepwater development in the KG basin and advanced offshore work in Mozambique both rely heavily on international EPC (Engineering, Procurement, and Construction) contractors and foreign technical expertise. This dependence caps the pace at which Indian NOCs can autonomously execute in frontier environments.

This is not a failure so much as a known gap, and the Samudra Manthan programme’s 87-well target will test it more severely than any previous Indian upstream effort. Building autonomous deepwater capability takes years of joint venture experience, so investors should factor a genuine technology learning curve into their timeline expectations for the FY31 drilling targets.

There is a longer-term capital constraint too. A fossil-centric model faces tightening access to finance as global climate norms harden, which makes HPCL’s green hydrogen pivot and ONGC’s emerging interest in diversification, including potential crude-to-chemicals projects (noted as unverified in research), strategically significant well beyond their immediate commercial rationale.

The structural ceiling matters because it means every project-level strategy operates inside a governance environment that can override even excellent execution. No amount of multi-contract planning eliminates regulatory or policy-induced delay, which is why investors should apply a two-level view: project-level execution risk, where HPCL and BPRL have shown genuine competence, and structural-level risk, where the evidence is far more mixed.

What the pattern across HPCL, ONGC, and BPRL tells investors to watch

The three cases resolve into a single, usable pattern. Project-level resilience is demonstrable when a company structures for disruption in advance, as HPCL did through COVID and BPRL did through a 4.5-year security freeze. It breaks down when structural coordination fails, as in ONGC’s KG basin, or when governance constraints override project competence, as in regulatory-induced delays.

The takeaway is not that Indian NOCs are resilient or fragile. They demonstrate both within the same organisation and the same strategy, and the variable that predicts which outcome dominates is coordination quality and regulatory environment, not the size of the capital commitment.

That reframes how these projects should be assessed. Three forward-looking variables deserve close monitoring:

• Execution coordination on the Samudra Manthan ramp-up, peaking at 27 wells in FY31, where offshore is roughly 70% of ONGC’s 30,000-32,000 crore rupee FY2026-27 E&P capex
• Progress on Kelkar Committee implementation, the clearest signal of whether structural friction is easing
• The pace of green transition investment, including HPCL’s green hydrogen and energy hub build-out, which will shape long-term capital access

The nearest test is Mozambique’s 2029 first-LNG target, the point at which BPRL’s resilience philosophy either delivers on its most demanding case or does not.

Investors who apply a single-lens view will systematically mis-price both the upside and the downside. The pattern across these three companies supports a more granular, project-specific and governance-specific framework instead.

For investors seeking a wider framework for sizing capital exposure across the entire NOC programme, our dedicated guide to India’s $100B energy investment landscape maps the allocation split between upstream E&P, refining, and clean energy that contextualises the individual project commitments discussed here.

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.

Past performance does not guarantee future results. Financial projections are subject to market conditions and various risk factors, and forward-looking targets such as the 2029 Mozambique first-LNG date and the FY31 drilling schedule remain subject to change based on operational and policy developments.