Oil and Natural · risk themes across the available quarters.
Bear-case history
Deep water oil production faces reservoir interconnection complexity being studied with world-renowned geological experts. Each re-entry costs ₹500+ crore. Developmental strategy expected shortly but timeline and cost implications remain uncertain.
HPCL reported ₹2,012.65 crore net loss due to under-recoveries on petroleum products from the West Asia crisis-driven crude price spike. This substantially offset ONGC standalone strength and will continue to weigh on consolidated performance.
OPAL reported negative EBITDA of ₹57 crore vs positive ₹120.7 crore in Q1 FY26 due to Nafta price spike from $600 to $1,000/ton while gaseous feed was unavailable. Management expects normalization as gaseous feed resumes and ethane sourcing from international markets via MoU with Mitsubishi begins.
Analyst questioned whether ONGC's decision not to participate in the JV arbitration (following government directive) may result in loss of benefit if arbitration award applies only to participating parties. Management stated JV outcome will be applicable to all parties but did not address the specific legal risk of non-participation.
Crude oil guidance trimmed to ~20 MMT from 21 MMT target; gas guidance slightly below 21.5 BCM. Production deferment to Q1 FY27 from delayed KG 98X2 living quarters installation (Dec-Jan monsoon period impact).
Force majeure still not formally lifted pending partner ballot (expected within days); project cost may exceed approved $18.2 billion requiring additional DACF approval. OVL's total exposure ~$8.8 billion including $6.6 billion equity already invested.
Production ceased from July 1, 2025 as uneconomical; awaiting Vietnam government to develop PC area for potential resumption.
Oil production at KG 98X2 declined to 28,000 bbl/day from 30,000 bbl/day last quarter due to well activity issues; recovery dependent on intervention results, not guaranteed.
Despite installation completion, any further delays in hook-up and commissioning could push first gas beyond Q1 FY27, impacting production targets.
Crude oil prices declined 12% YoY to $61.63/bbl in Q3; sustained low prices could pressure revenue and profitability despite cost measures.
The GST on oil services was raised from 12% to 18%, with no input tax credit relief expected, adding to cost pressures.
OPaL still carries net debt of ₹23,000-24,000 crore; while profitability is improving, any downturn in petrochemical margins could strain cash flows.
KG basin Block 98/2 experienced unexpected geological surprises causing oil production to drop significantly. Management has identified solutions but recovery will take ~12 months and involves drilling additional wells.
DUDP project monetization commenced late (March vs. earlier target) with only 4 of 15 wells opened by quarter-end. Full opening pushed to September-October with peak production 1-2 years away.
OPAL operated at less than 60% capacity in March Q4 due to gas allocation diversion for LPG production. Full recovery expected within 4-5 days but represents operational vulnerability.
Management explicitly refused to disclose exploration capex breakdown citing competitive sensitivity, making it difficult to independently verify forward production guidance from disclosed well counts.