On March 9, Brent crude jumped above $110 per barrel for the first time in more than three years. The trigger was the Iran conflict drawing in Hormuz transit routes, cutting off a chokepoint that carries roughly a fifth of the world’s seaborne oil. For most large oil-consuming economies, a price spike of this kind is an inconvenience.

For India, which sources over 88% of its crude through imports and produces very little domestically, it is a direct cost hit. Every additional dollar per barrel increases the trade deficit by roughly $243 million a year. There is no natural hedge.

The shock does not fall evenly across India’s oil industry. It hits upstream producers, midstream pipelines, downstream refiners, and the government budget in different ways and different directions.

Dollar-Oil Double Hit

India produces only about 28.6 million metric tonnes of crude domestically each year, less than 12% of what it consumes. When prices rise, the import bill rises almost in full. Some companies gain. Most lose. The arithmetic is most unkind to refiners.

The currency makes it worse. The rupee was at nearly Rs 92 to the dollar on 8 March 2026, against Rs 83 in April 2024. High oil prices pull dollars out of India; safe-haven flows pull them further.

The Reserve Bank of India intervened in spot and forward markets, but the direction of travel was set. When crude and the dollar both move against India at the same time, the import bill worsens in both currencies simultaneously.

For Indian Oil Corporation Limited (IOCL) alone, a 5% rupee fall hits standalone profit before tax by Rs 5,725 crore.

The government has a tool for controlling the upstream windfall. When prices spike, it levies the Special Additional Excise Duty (SAED) — a windfall tax on domestic crude production first applied in 2022.

For Oil India, SAED rose from $2.59 per barrel in Q1 FY 2023-24 to $10.27 per barrel in Q1 FY 2024-25 as prices climbed. Oil and Natural Gas Corporation (ONGC) reported a Rs 1,350 crore decrease in statutory levies in Q2 FY 2025-26 after SAED was abolished in December 2024. The mechanism smooths government revenues while introducing earnings volatility for upstream producers.

On the subsidy side, the picture is messier. The prices of liquefied petroleum gas (LPG), largely used for cooking in India, are controlled. When crude rises, IOCL, Bharat Petroleum Corporation Limited (BPCL), and Hindustan Petroleum Corporation Limited (HPCL) sell LPG below cost and wait for the government to cover the gap.

The Union Cabinet approved Rs 30,000 crore in August 2025 to cover LPG losses; this followed a prior Rs 22,000 crore subsidy against a Rs 28,000 crore negative buffer. IOCL’s management has noted that the lack of timely reimbursement has suppressed the market capitalisation of all three OMCs.

Upstream Earnings Sensitivity

For oil producers, higher prices mean higher revenues directly, though the government takes a bigger cut as prices rise, so not all of the upside reaches the bottom line.

For ONGC, on a standalone basis, a $1 per barrel change in crude moves revenue net of levies by nearly Rs 6,180 crore annually: roughly 20 million tonnes of standalone crude production (about 147 million barrels) multiplied by the rupee-dollar rate of nearly Rs 92, covering royalty, cess, and oil-linked condensate and natural liquid gas (NGL) streams that all reprice with crude.

The caveats are real: royalty and cess also rise with crude, so the government’s cut grows at the same time; if SAED is revived, more of the upside gets clawed back; and the Rs 92 assumption matters — change the exchange rate and the sensitivity number shifts with it.

ONGC Videsh adds Rs 107 crore on a consolidated basis. The gain is largely a translation effect: OVL’s dollar-denominated debt, at roughly $4–5 billion, inflates in rupee terms by far more when the currency weakens.

Midstream Pricing Lag

Midstream companies are affected less by price levels than by the behavioural responses those levels trigger. When gas prices rise alongside oil, refineries and heavy industry switch to cheaper liquid alternatives, reducing transmission volumes. State-owned GAIL, India’s leading natural gas company, reported a drop of 5 million metric standard cubic metres (MMSCMD) in Q4 FY25 transmission volumes as IOCL and BPCL switched to liquid fuels, despite maintaining FY26 guidance at 134 to 135 MMSCMD.

A structural pricing lag compounds this: GAIL sources roughly 10 to 11 MMSCMD of gas on a nine-month average crude-linked basis but sells at a three-month average price, creating a mismatch that hurts during rapid price moves in either direction. When crude falls, GAIL’s Liquid Hydrocarbon segment PBT also softens, removing a second source of earnings resilience.

Downstream Economics Turn Hostile

Downstream companies face the least comfortable equation. The gross refining margin compresses when crude rises faster than product prices, inventory swings arrive unrequested, and marketing margins erode if retail prices cannot track input costs.

The Singapore Complex GRM, the regional benchmark, peaked at approximately $35 per barrel in July 2022 before declining sharply as product cracks normalised. BPCL’s average GRM followed the same arc, falling from $14.14 per barrel in FY 2023-24 to $6.82 per barrel in FY 2024-25. IOCL’s Q3 FY25 reported GRM of $2.95 per barrel, normalised to $6.60, against $1.59 in the preceding quarter.

The relationship between crude prices and refining margins is not linear. Reliance Industries noted that in Q3 FY26, despite a 15% year-on-year fall in Brent to $63.70 per barrel at the time, Gasoil (what becomes diesel and jet fuel—the middle distillates) cracks rose 62% and Gasoline cracks rose 106% year-on-year as supply disruptions created acute regional tightness. The crack spread is simply the price difference between a refined product and the crude used to make it.

Disruption can expand cracks even as it raises feedstock costs. At $110 crude on 9 March, the question of which force dominates is open. Higher official selling prices from West Asia and elevated tanker freight rates are already raising feedstock costs for Indian refiners. Whether product cracks expand enough to compensate depends on whether the supply shock is sustained or resolved.

Marketing margins face a cleaner ceiling. BPCL management has identified the $65 to $70 per barrel range as the zone where margins remain healthy, with pressure intensifying above $70 to $75. At $110 per barrel, that threshold has been breached by $35 to $40.

A net retention margin of Rs 2.50 to Rs 3.00 per litre on petrol and diesel is considered acceptable — but only if retail prices can track input costs, which political economy rarely allows in an inflationary episode.

The hedging programmes that IOCL, BPCL, and GAIL maintain through swaps, options, and OTC derivatives provide partial insulation. But hedging reduces variance, not direction. When crude moves $40 per barrel against you, the hedge cushions. It does not reverse the impact.

Macro

Financial institutions had earlier projected the fiscal deficit narrowing from 4.8% of GDP in FY 2024-25 to 4.4% in FY 2025-26, with real GDP growth holding at 6.5% across both years. Those projections assumed oil in a manageable range.

At $110 per barrel, a sustained move of $35 above the $75 threshold tests all three numbers simultaneously: the trade deficit through import costs running at roughly $243 million per additional dollar per barrel, the fiscal deficit through accelerating subsidy obligations, and GDP growth through the consumption squeeze that follows retail price pass-through.

The rupee at nearly Rs 92 adds a currency multiplier to every barrel.

India has been here before — in 2008, 2012, and 2022. Each time, it managed through a mix of holding down retail prices, expanding subsidies, and consolidating fiscal accounts once oil retreated.

March 2026 has three features that were not all present at once in prior episodes: the price shock is coming from a military conflict with no visible resolution timeline; the rupee enters this cycle at a structurally weaker level than in previous ones; and the LPG subsidy buffer has just been refilled, meaning the government is already spending on that line before prices have been fully absorbed.

The question is not whether India can absorb a sustained $110 oil environment. It has done so before. The question is what the absorption costs are this time, and who in the oil chain bears them.