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Oil & Natural Gas Corporation — Q4 FY25
ONGC's Q4 FY25 standalone PAT declined 12.1% YoY to INR 35,610 crore, primarily due to a INR 4,257 crore increase in exploration write-offs.
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ONGC's Q4 FY25 standalone PAT declined 12.1% YoY to INR 35,610 crore, primarily due to a INR 4,257 crore increase in exploration write-offs. Revenue was flat at INR 137,361 crore. Crude oil production rose 0.9% to 18.558 MMT, while gas production fell 1.6% to 19.654 BCM. Management highlighted a record 578 wells drilled and INR 62,000 crore CapEx, the highest ever. Key growth drivers include the KG 98/2 field (oil at 33-34 kbpd, targeting 45 kbpd), new well gas pricing adding INR 700 crore in FY25, and OPaL's turnaround post-SEZ denotification. Guidance points to standalone crude production of ~21.5 MMT and gas of ~21 BCM in FY26, with 5 MSCMD incremental gas from DUDP by Q4 FY26. Risks include continued dry well write-offs and delayed KG 98/2 gas ramp-up due to living quarters installation.
ONGC की चौथी तिमाही (Q4 FY25) में शुद्ध मुनाफा 12.1% घटकर 35,610 करोड़ रुपये रहा। इसकी मुख्य वजह तेल और गैस की खोज में 4,257 करोड़ रुपये का अतिरिक्त खर्च (जिसे 'एक्सप्लोरेशन राइट-ऑफ' कहते हैं) था। कंपनी की कमाई (रेवेन्यू) 1,37,361 करोड़ रुपये पर स्थिर रही। कच्चे तेल का उत्पादन 0.9% बढ़कर 18.558 मिलियन टन हुआ, जबकि गैस का उत्पादन 1.6% घटकर 19.654 बिलियन क्यूबिक मीटर रहा। कंपनी ने रिकॉर्ड 578 कुएं खोदे और 62,000 करोड़ रुपये का सबसे बड़ा निवेश (कैपेक्स) किया। भविष्य में KG 98/2 क्षेत्र से तेल उत्पादन बढ़ाने और नई गैस कीमतों से 700 करोड़ रुपये अतिरिक्त कमाई की उम्मीद है। अगले साल कच्चे तेल का उत्पादन 21.5 मिलियन टन और गैस का 21 बिलियन क्यूबिक मीटर रहने का अनुमान है। जोखिमों में सूखे कुओं पर खर्च और KG 98/2 में गैस उत्पादन में देरी शामिल है।
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Dry well write-offs may persist
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Crude Oil Production (Standalone)
18.558 MMT
+0.9% YoY
First increase in years; driven by well interventions and new drilling.
Natural Gas Production (Standalone)
19.654 BCM
-1.6% YoY
Decline due to mature fields; expected to reverse with new projects.
Wells Drilled
578
+35-year high
Highest in 35 years; 109 exploratory and 469 development wells.
Reserve Replacement Ratio
1.35x
19th consecutive year >1
Domestic fields excluding JV; ensures long-term production sustainability.
What Changed vs Last Quarter
NEW
Standalone crude oil production target of ~21.5 MMT for FY26
Management expects crude production to rise to 21.5 million metric tons in FY26, driven by TSP initiatives and new wells.
NEW
Standalone gas production target of ~21 BCM for FY26
Gas production expected to reach 21 BCM in FY26, with 5 MSCMD incremental from DUDP by Q4 FY26.
NEW
CapEx guidance of INR 30,000-35,000 crore for FY26
Total CapEx including E&P and renewables expected to be INR 30,000-35,000 crore, lower than FY25 due to falling service costs.
NEW
New well gas to add INR 1,500-2,000 crore revenue in FY26
Revenue from new well gas pricing expected to double from INR 700 crore in FY25 to INR 1,500-2,000 crore in FY26.
DROPPED
Production growth target of 44.5 MMTOE for FY25-27
Management guided for standalone production of 44.5 MMTOE (crude oil 21.96 MMTOE, gas 22.63 MMTOE) for the period, excluding BP upside.
DROPPED
KG-DWN-98/2 peak oil at 45,000 bpd by Q1 FY26
Oil production from KG-DWN-98/2 expected to reach peak of 45,000 bpd by end of FY25 or Q1 FY26.
DROPPED
10 GW renewable capacity by 2030
ONGC targets 10 GW of renewable energy capacity by 2030, with ~40% expected by end of FY25.
DROPPED
OPaL to get full 3.2 MMSCMD gas from April 2025
OPaL will receive full contracted gas volume of 3.2 MMSCMD from ONGC's new finds starting April 2025, improving margins.
NEW RISK
Dry well write-offs may persist
Exploration write-offs surged to INR 4,257 crore in FY25; management noted unpredictability in dry well incidence, which could pressure earnings.
NEW RISK
KG 98/2 gas ramp-up delayed by living quarters installation
Gas production currently at 2.75 MSCMD; target of 6-7 MSCMD hinges on installing a living quarters platform, delayed due to weather.
NEW RISK
OPaL ethane sourcing timeline uncertainty
OPaL's ethane import from US is targeted for 2028; any delay could prolong reliance on costlier naphtha (60% of feedstock).
RISK GONE
KG-DWN-98/2 gas ramp-up delays
Gas production ramp-up from KG-DWN-98/2 may be delayed due to weather conditions in the East Coast and installation timelines for remaining structures.
RISK GONE
Petrochemical downcycle impacting OPaL
OPaL's margins remain under pressure from the petrochemical downcycle, with ethylene-naphtha spreads at $300-350/ton, though gas allocation and SEZ exit may help.
RISK GONE
Russian dividend repatriation stuck
About $250 million of dividends from Russian projects are stuck in Russian banks due to sanctions, with no clear timeline for repatriation.
RISK GONE
Renewable energy execution risk
ONGC's late entry into renewables may face execution challenges; management acknowledged being a 'second mover' and targets 10 GW by 2030, which is ambitious given current capacity of 193 MW.
🤫 Topics management stopped discussing
Mentioned in Q1 FY25, Q2 FY24, Q4 FY24
Analyst raised concern about windfall tax on KG Basin oil; management stated they do not anticipate it currently, but uncertainty remains.
Mentioned in Q2 FY24, Q3 FY25
Gas production ramp-up from KG-DWN-98/2 may be delayed due to weather conditions in the East Coast and installation timelines for remaining structures.
Mentioned in Q1 FY25, Q2 FY24
OPaL reported PAT loss of INR 983 crore in Q1 FY25; restructuring awaits government clearance, posing downside risk.
Mentioned in Q2 FY25, Q4 FY24
OPaL reported a PAT loss of ₹637 crore in Q2 FY25; management declined to provide near-term profitability guidance, citing dependence on product and feedstock prices.
Mentioned in Q2 FY24, Q2 FY25
Management expects OPaL to improve significantly from next year due to lower interest costs and cheaper feedstock from new well gas allocation.
Fast read
Guidance and risk preview
Management expects crude production to rise to 21.5 million metric tons in FY26, driven by TSP initiatives and new wells.
Exploration write-offs surged to INR 4,257 crore in FY25; management noted unpredictability in dry well incidence, which could pressure earnings.
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