This stands in stark contrast to July 2022, when authorities imposed a windfall tax of ₹23,250 per tonne (~$40 per barrel) to capture extraordinary profits from the Russia-Ukraine war-driven price surge. The tax was abolished in December 2024 as global crude prices normalized and industry concerns mounted that the levy discouraged higher production levels.
The policy reversal signals a strategic shift from revenue capture to production incentivization. With India importing 85% of its crude oil requirements and domestic production declining at a CAGR of -2.67% over 2014-2023, the government is trading near-term royalty revenue for long-term energy security.
The royalty reduction creates fundamentally different cost structures for Oil India and ONGC based on their production profiles. Oil India, with its 100% onshore portfolio, sees its effective royalty rate drop from 16.66% to 10%—a reduction of 6.66 percentage points. ONGC, with approximately 70% of production from offshore fields, experiences a more modest effective rate decline from 9.09% to 8%—just 1.09 percentage points.
The expense deduction methodology change further amplifies this divergence. Previously, companies could deduct $3-6 per barrel based on actual post-production costs. The new framework allows a deduction of 15-20% of realization or up to $16 per barrel (assuming $80/barrel oil). For Oil India's onshore operations with lower post-wellhead costs, the 20% ad-valorem deduction provides substantial benefit. ONGC's offshore operations, with higher infrastructure and transportation costs, benefit less proportionally despite the higher absolute deduction.
This 6.2x differential advantage directly impacts earnings sensitivity to crude price movements.
Oil India's Q4FY26 results vividly demonstrate the superior leverage of onshore production to higher oil prices. Crude realization jumped 24% sequentially from $62.8 to $77.9 per barrel, driving EBITDA up 39.1% to ₹1,820 crore. EBITDA margins expanded 390 basis points to 30.5%, while net profit surged 121.4% to ₹1,790 crore. This creates a leverage ratio of 1.63x—EBITDA growth outpaced price growth by 63%.
The operational performance was equally impressive. Oil India achieved its highest daily crude production in a decade at 10,566 metric tonnes, drilled a record 74 wells during FY26, and completed 307 workover jobs—another company record. This aggressive field activity helped achieve a reserve replacement ratio exceeding one, indicating sustainable production capacity.
ONGC's offshore-heavy portfolio inherently shows lower operating leverage due to higher fixed costs, longer development timelines, and greater capital intensity. While ONGC benefits from scale advantages (4.5x larger market cap) and integrated operations through refining and marketing, the near-term earnings sensitivity to price changes remains constrained by offshore operational realities.
The market has quickly priced in these differential advantages.
This 87% stronger reaction reflects investor recognition of Oil India's superior near-term earnings accretion potential.
ICICI Securities' EPS estimate revisions tell a similar story. The brokerage upgraded Oil India's FY27 and FY28 EPS estimates by 16% and 7% respectively, compared to 12% and 10% for ONGC. The larger FY27 revision for Oil India reflects the immediate impact of royalty benefits on onshore operations, while ONGC's relatively larger FY28 upgrade accounts for phased benefits as offshore projects come online.
JM Financial has set a target price of ₹585 for Oil India and ₹340 for ONGC, explicitly preferring Oil India as a "15% earnings-compounding story" driven by strong 20-25% cumulative output growth over FY27-29 and NRL refinery expansion from 3MMTPA to 9MMTPA by end-FY27.
Given current West Asia tensions affecting the Strait of Hormuz—which handles 25% of global seaborne oil shipments—sustained elevated prices could significantly boost earnings.
Every $5 per barrel rise in oil prices can lift upstream company EPS by 8-10%. If prices sustain at $90-95 per barrel rather than the assumed $80-85 range, Oil India could see cumulative EPS growth of 40-50% versus 30-37% for ONGC. The differential leverage means Oil India's earnings would benefit approximately 6.2x more per barrel than ONGC's under sustained high-price scenarios.
The current earnings momentum faces meaningful downside risks from two primary sources: easing of geopolitical tensions and government subsidy sharing decisions. If West Asia tensions de-escalate and crude prices normalize to $70-75 per barrel, Oil India's EPS could decline 15-20% with corresponding stock price corrections of 20-25%.
The government could also require upstream companies to share OMC subsidy burdens, as occurred historically when under-recoveries peaked at ₹1.6 lakh crore in 2012-13. Current OMC marketing margins have already turned negative due to West Asia war-induced crude price spikes. Moderate subsidy sharing of ₹3,000 crore quarterly could reduce Oil India's EPS by 8-10%.
However, sustained higher crude prices could create a virtuous feedback loop. Improved project economics (higher IRR, lower payback periods) drive increased capex allocation, accelerating development timelines. Onshore projects (2-4 years) respond faster than offshore (5-8 years), enabling quicker production growth and earnings expansion. This reinvestment cycle could drive cumulative EPS growth of 40-50% for Oil India and 30-37% for ONGC over the full cycle.
The royalty reduction also alters competitive dynamics between state-owned and private sector players. Private sector Cairn Oil & Gas (Vedanta), with approximately 85% onshore production, sees royalty rates for its Rajasthan fields decline from 16.67% to 10.6%. However, Cairn faces near-term execution challenges due to its ongoing demerger process, limiting its ability to immediately capitalize on royalty benefits compared to PSUs.
Oil India's pure onshore portfolio provides maximum benefit from the royalty reduction, while ONGC's mixed asset base offers moderate benefits with scale advantages. Cairn's demerger creates transition uncertainty, delaying benefit realization until H2 FY27. Post-demerger, Cairn could emerge as a focused pure-play E&P entity with ambitious growth targets (4x output to 1 million bpd), but execution risk remains elevated.
The near-term competitive advantage clearly favors Oil India, with maximum royalty benefit, immediate earnings uplift, and strong operational momentum. ONGC offers sustainable long-term positioning with scale and offshore expertise. Cairn presents high-risk, high-reward potential contingent on successful demerger completion and execution of ambitious expansion plans.
