State-run Oil and Natural Gas Corporation Ltd stumbled against consensus projections on Thursday. Standalone net profit dropped 9.1% quarter-on-quarter to ₹15,489 crore for the July-September period, down from ₹17,034 crore in the preceding quarter. Revenue slipped 5.6% sequentially to ₹43,875 crore from ₹46,461 crore. The operational bleed proved sharper: earnings before interest, tax, depreciation, and amortisation (EBITDA) contracted 12.3% to ₹24,860 crore, driving operating margins down 400 basis points to 57%. Market estimates had penciled in a net profit of ₹15,591 crore on revenue of ₹44,257 crore and an EBITDA margin of 60%. Shares of the Maharatna explorer ended at ₹230.10 on the BSE, down ₹4.45, or 1.90%.
The sequential cooling masked stronger annual comparisons. Standalone gross revenue advanced 32.8% year-on-year, while standalone net profit climbed 57.3% against the corresponding quarter of the previous fiscal year. Consolidated net profit rose 46.9% to ₹18,535 crore. Production remained broadly flat on a sequential basis. Yet annual volumes took a hit from reservoir complexities in the KG-98/2 deepwater block in the Eastern Offshore Basin, heavy monsoon disruptions, and lingering delays in the PRP-8 and PRP-9 subsea pipeline replacement projects. Onshore gas production suffered additional compression after equipment breakdowns at major consumer installations reduced industrial offtake.
| Financial Metric | Q2 FY27 (Reported) | Q1 FY27 (Preceding) | Market Estimate | QoQ Change |
|---|---|---|---|---|
| Standalone Net Profit | ₹15,489 crore | ₹17,034 crore | ₹15,591 crore | -9.1% |
| Gross Revenue | ₹43,875 crore | ₹46,461 crore | ₹44,257 crore | -5.6% |
| EBITDA | ₹24,860 crore | ₹28,355 crore | ₹26,574 crore | -12.3% |
| EBITDA Margin | 57% | 61% | 60% | -400 bps |
To arrest natural declines across aging reservoirs, ONGC widened the deployment of BP as its technical service partner across the Western Offshore under the TSP-1 and TSP-2 frameworks. BP mobilised field crews for TSP-2—which covers all Western Offshore tracts outside Mumbai High—in August 2026. Management backed that technical intervention with heavy capital allocations, awarding two major offshore development contracts spanning the MBOSN-2005-1, SD-4, BS-17 fields, alongside additional work on Ratna-1 and NLM-14. These contracts commit ₹11,800 crore in capital expenditure to tap an estimated 22 million tonnes of oil equivalent. The explorer also sanctioned the Pipeline Replacement Project-X, a ₹4,300 crore infrastructure overhaul aimed at replacing degraded subsea pipelines.
Fresh drilling produced initial gas strikes. Under its Samudra Manthan deepwater program, the company proved gas flow at its maiden exploratory well, MNDWO181HDB-1, situated in the Mahanadi basin block MN-DWHP-2018/1 off the Odisha coast. Onshore teams logged two additional discoveries: a gas find at the Amraghat-1 prospect within the Assam-Arakan Fold Belt, and a new oil pool at Vadatal-48 in Gujarat's Cambay Basin. Monetisation from recently tapped wells gained traction, with new-well gas generating ₹7,050 crore during the first half of the fiscal year—accounting for over 34% of ONGC's nomination portfolio receipts.
Capital distributions and balance sheet transfers rounded out the board's docket. Directors approved an interim dividend of ₹8 per equity share of face value ₹5, representing a 160% payout. Shareholders on record as of November 12, 2026, qualify for the disbursement, scheduled within 30 days. The board also sanctioned a five-year inter-corporate loan facility of up to ₹10,000 crore to foreign investment arm ONGC Videsh Ltd, while regulatory disclosures confirmed outstanding unsecured non-convertible debentures stood at ₹1,000 crore at the close of the quarter.
| Interim Dividend | ₹8 per share | — | — | 160% payout |