Prologue: The Barrel Nobody Can Agree On
On 31 July 2026, Indian Oil Corporation told the stock exchanges it had lost ₹2,661 crore in a single quarter.
And yet, in the same quarter:
- Revenue was up 26% year-on-year, to ₹2.76 lakh crore
- Refinery throughput hit 19.165 million tonnes , the highest first-quarter figure in the company’s history
- Refineries ran at 109.4% of rated capacity
- Petrol and diesel sales both hit records
- Domestic market share climbed to 43.1%, the highest of India’s three state refiners
Record operations. A net loss. Same twelve weeks.
That single contradiction is close to the most honest one-line description of what Indian Oil actually is. It isn’t really a company that just sells fuel. Seen through one lens, it’s a shock absorber the Indian state built to sit between whatever crude costs on a given morning and whatever a scooter owner in Nashik can afford to pay for petrol that afternoon.
Refining, petrochemicals, pipelines, retail - none of them were built only for that purpose. But taken together, they’ve progressively given Indian Oil more scale and more room to absorb exactly that kind of shock.
Three months before that quarterly loss, Indian Oil was threading a much sharper needle: buying Russian crude from the non-sanctioned cousins of newly sanctioned counterparties, after Washington blacklisted Rosneft and Lukoil in October 2025. Its own finance director told investors on a call:
“We are absolutely not going to discontinue as long as we are complying with the sanctions.”
Three weeks after the quarterly loss, the company announced it would spend roughly ₹1 lakh crore over the next five to six years , on petrochemicals alone , on top of a renewables push targeting 18 gigawatts, and a Net Zero roadmap already committed at ₹2.5 lakh crore.
So that’s Indian Oil in 2026, in one sentence: reporting a loss because it can’t pass on a crude price spike, financing a multi-lakh-crore industrial pivot in the same breath, and operating in a market where roughly a third of India’s crude imports had come from a country the United States is actively trying to cut off.
None of that is new. It’s just the current version of a tension the company has been managing, one way or another, since before it had the name Indian Oil at all.
Indian Oil’s ancestry, like Bharat Petroleum’s, runs back through Burmah Oil , but through a colder, more remote door: Digboi, in the far northeastern corner of Assam.
- 1889 : Italian engineers laying a railway line for the Assam Railway & Trading Company hit oil by accident, cutting track between Dibrugarh and Margherita
- Legend credits a Canadian engineer, W. L. Lake, with the line “dig, boy, dig” , almost certainly not the real etymology, which more likely traces to Dibois Nullah, the local name for the stream running through the site
- 1901 : the Assam Oil Company, under Burmah Oil, commissions a refinery at Digboi
Digboi is, to this day, the oldest continuously operating refinery in Asia , 125 years old in 2026, still producing LPG, motor spirit, diesel, furnace oil, and the paraffin wax it has always been known for.
For the first half of the twentieth century, it was the only refinery in India.
Independent India’s relationship with that inheritance was, for its first decade, mostly a fight to break it.
By the late 1950s, the government had decided a market run by three multinational majors , Burmah Shell, Esso, and Caltex , importing and refining crude on their own terms was untenable for a country trying to industrialise on a shoestring of foreign exchange.
The trigger was almost bureaucratic: the majors refused to refine crude the government had secured from the Soviet Union on favourable barter terms, and balked at expanding domestic refining capacity fast enough. Jawaharlal Nehru’s government responded by building its own capacity from scratch.
Two companies, five years apart, both entirely state-owned, both built to reduce India’s dependence on the companies that had run its fuel market until then.
August 1958 : Indian Refineries Limited incorporated, wholly government-owned, to build refineries and lay pipelines. With Soviet and Romanian technical assistance, since the Western majors weren’t offering any.
30 June 1959 : the Indian Oil Company Limited incorporated in Bombay as a government-owned public limited company under the Companies Act, 1956, to market petroleum products , initially just to state enterprises.
The timeline from there moves fast:
- 1 January 1962 : Indian Refineries commissions India’s first public-sector refinery, at Guwahati (Noonmati), built with Romanian assistance, inaugurated by Nehru himself. The same year, Indian Oil opens its first fuel station, at Anjar in Gujarat, and starts exporting cargo to Bhutan
- 1964 : Barauni refinery, Bihar, commissioned
- 1 September 1964 : Indian Refineries Ltd and the Indian Oil Company merge into a single entity: Indian Oil Corporation Limited, the name it still carries
- 1966 : Gujarat Refinery at Koyali dedicated
- 1969 : Madras Refineries Limited commissioned, later renamed Chennai Petroleum Corporation Limited, and folded in as a subsidiary
Within that same decade, the merged Indian Oil Corporation entered the aviation-fuel business, supplying the Indian Air Force, and laid the pipeline that would define its next sixty years.
By the time it turned ten, it wasn’t a scrappy import-substitution project anymore. It was the backbone.
Most people who’ve heard of Indian Oil have never heard of its pipelines. That’s rather the point , a pipeline’s entire job is to be invisible, underground, and never in the news. But it’s one of the company’s oldest and largest engineering identities, and it deserves its own chapter.
1964: 435 km. The Guwahati–Siliguri Pipeline , designed by Bechtel of the USA, built by Snam Progetti of Italy , was Indian Oil’s first cross-country pipeline, and one of the first product pipelines built anywhere east of the Suez Canal. It ran from the new Guwahati refinery, through what would later become Bongaigaon, to delivery points at Betkuchi and Siliguri, moving 1.4 MMTPA of fuel.
2026: 20,000+ km. Six decades of expansion later, Indian Oil’s pipeline network , crude oil, refined products, and natural gas combined , spans more than 20,000 km, one of the largest such networks in the world, independently benchmarked by Solomon Associates of the USA. In 2025–26 alone, it moved 102.5 million tonnes through its liquid lines and 3,991 million standard cubic metres through its gas lines , an installed capacity of roughly 130 MMTPA of liquid and 49 MMSCMD of gas.
Still growing. Active projects include the New Mundra–Panipat crude oil pipeline, an augmentation of the Salaya–Mathura crude system, and a transnational product pipeline into Nepal under a bilateral agreement between Indian Oil and Nepal Oil Corporation , the same cross-border instinct that first sent Indian Oil cargo to Bhutan in 1962.
Between 1964 and 2026, one 435-km line east of the Guwahati refinery grew into a network that quietly moves more fuel than most countries consume.
The politically untenable position of foreign-owned majors sitting atop India’s fuel supply came to a head in the mid-1970s , the same moment it did for what would become BPCL.
- 1974 : Esso’s Indian assets nationalised, forming the basis of what is now Hindustan Petroleum
- 24 January 1976 : Burmah Shell nationalised, becoming Bharat Refineries and then Bharat Petroleum
- 1977 : Caltex’s operations absorbed into HPCL
Indian Oil’s own biggest nationalisation moment came later, and more quietly, in the same corner of the country where the whole story started.
14 October 1981 : under an Act of Parliament, the Assam Oil Company’s refining and marketing assets, including the 1901 Digboi refinery, are vested in Indian Oil, becoming the Assam Oil Division.
The company that began by breaking a colonial trading monopoly ended up, two decades later, absorbing the actual refinery where Indian oil refining had begun.
Digboi’s modernisation followed in phases:
- 1996 : new Vacuum Distillation Unit and captive power plant, under the Digboi Refinery Modernisation Project
- 1997–2001 : Catalytic Reformer Unit, new Delayed Coking Unit, Wax Hydrofinishing Unit
- 2026 (targeted) : expansion to 1.0 MMTPA
A refinery originally built for 500 barrels a day is still being invested in, a century and a quarter later.
Digboi and Guwahati aren’t the end of Assam’s refinery story. There’s a third chapter, and it completes an unusually clean arc: Digboi → Guwahati → Bongaigaon , India’s first petroleum province evolving, refinery by refinery, into a genuine multi-site industrial system.
- 1974 : Bongaigaon Refinery & Petrochemicals Limited (BRPL) incorporated as a separate government company, sited in the Chirang district, about 200 km west of Guwahati
- 1979 : first crude distillation unit commissioned, at 1.0 MMTPA
- 1981 : a Delayed Coking Unit added
- 1985 : a Catalytic Reformer Unit added; capacity de-bottlenecked to 1.35 MMTPA the following year
- 1995–96 : a Refinery Expansion Project adds a second CDU and DCU, lifting capacity to 2.35 MMTPA
- 2010–2012 : an MSQU unit, DHDT/HGU, and Sulphur Recovery Unit added, to meet Auto Fuel Policy environmental norms
- 2009 : BRPL formally amalgamated into Indian Oil Corporation, becoming the Bongaigaon Refinery
- Today : capacity stands at roughly 2.70 MMTPA, following an INDMAX/BS-VI upgrade project, with a further expansion toward 5 MMTPA under conceptualisation
Bongaigaon still feeds into the same Guwahati–Siliguri Pipeline that Indian Oil built in 1964 , three refineries, six decades apart, sharing one artery.
A Second, Smaller Echo
There’s one more rhyme in the family tree.
IBP : the Indo-Burma Petroleum Company , was incorporated in Rangoon in 1909, shifted its corporate office to India in 1942, and spent most of the twentieth century as a separate marketing and retail company, eventually majority-owned by Indian Oil.
2 May 2007 : IBP formally merges into its parent.
A company born in Rangoon under a name that quite literally contained “Burma” folded into Indian Oil ninety-eight years after it was founded , a small, almost coincidental echo of Digboi’s own Burmah Oil ancestry, absorbed into the same parent decades apart.
If Kochi is BPCL’s clearest expression of ambition, Indian Oil’s is Paradip, on the Odisha coast.
The build:
- Sanctioned capacity: 15 MMTPA
- Original cost estimate (2014): ~₹34,162 crore
- Final cost by inauguration: ~₹34,555 crore
- Inaugurated by PM Narendra Modi: 7 February 2016 , years behind an original 2013 target
- Built specifically to process heavier, more difficult Latin American crude grades that lighter Indian refineries couldn’t handle
- Reached 100% capacity utilisation within 15 months, by May 2017
Then, like Kochi, Paradip stopped being just a refinery.
The stated logic is explicit in Indian Oil’s own numbers: PTA and MEG together were projected to lift Paradip’s “Petrochemical Intensity Index” from 4.5 to 14.7 , a refinery deliberately re-engineering itself to sell polyester feedstock, not just diesel.
FY 2025–26 results at Paradip:
- Record crude processing: 16.35 million tonnes , above nameplate capacity
- Contribution to central and state exchequers: over ₹30,392 crore, in that year alone
- Cumulative investment at the site: past ₹43,000 crore
Paradip isn’t Indian Oil’s only integrated refining-and-petrochemical bet , arguably not even its largest one. That distinction belongs to Panipat, in Haryana.
Indian Oil itself describes Panipat as the largest integrated refinery-and-petrochemical hub in India, and the third-largest in Southeast Asia.
Capacity growth:
- Commissioned: July 1998, at 6 MMTPA
- Expanded: 2006, to 12 MMTPA
- Expanded again: 2010, to 15 MMTPA
- Under feasibility study (2026): push to 25 MMTPA
Petrochemical layer:
- Aromatics complex (PX/PTA) commissioned 2006; revamped to 460 KTPA PX and 700 KTPA PTA
- Naphtha cracker, ethylene capacity grown through successive expansions from ~850,000 tpa toward 1.2 million tpa
- A ₹1,527 crore olefin recovery, naphtha cracker expansion, MEG revamp and benzene unit modification approved 2016, alongside a separate ₹8,287 crore Barauni expansion approved the same year
Between Panipat, Paradip, and smaller expansions at Barauni, Koyali, and Mathura, Indian Oil’s 2018-era plan called for lifting group refining capacity from ~80.7 MMTPA toward 116.55 MMTPA by 2030, at an investment north of ₹70,000 crore.
Some of that timeline has visibly slipped. Group capacity in 2026 stands at 80.75 MMTPA across 10 group refineries , nine operated directly by Indian Oil (70.25 MMTPA) plus subsidiary Chennai Petroleum’s Manali refinery (10.50 MMTPA) , still the largest single refining footprint in India, at close to a third of the country’s total.
What hasn’t slipped is the direction: more petrochemicals, layered onto the same crude the refineries already process, rather than simply more diesel.
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Two More Refineries Worth Knowing
Two further refineries round out the picture, each with their own long modernisation arc.
- Haldia (West Bengal) - commissioned 1975 at 2.5 MMTPA with French and Romanian technical collaboration; expanded in stages to 8 MMTPA today. Home to India’s first Catalytic Iso-Dewaxing Unit for premium lube base oils (2003), and a second such unit , a first-of-its-kind installation in India , commissioned in 2024.
- Mathura (Uttar Pradesh) - commissioned 19 January 1982, built at a cost of ₹253.92 crore; expanded from 6 MMTPA to today’s 8 MMTPA. Chosen for green hydrogen investment specifically because of its proximity to the Taj Trapezium Zone, where emissions rules are tightest.
Refineries and pipelines are how Indian Oil is built. For most Indian households, they’re not how Indian Oil is known.
That distinction belongs to a cylinder: Indane, Indian Oil’s LPG brand.
- LPG marketing in India actually began in 1955, in Mumbai, under Burmah Shell , one more thread tying back to the same colonial-era ancestry
- Indian Oil conceived the Indane brand in 1964, the same extraordinary year as the Guwahati–Siliguri pipeline and the Indian Refineries–Indian Oil merger
- The first Indane connection was released on 22 October 1965, in Kolkata
- Today, Indane is trusted by over 15 crore kitchens , more than 150 million households , making it one of the largest LPG distribution operations run by any single company in the world
Indian Oil refills more than 27 lakh LPG cylinders a day. Every second LPG cooking-gas connection in India is an Indane connection.
It’s worth sitting with what that means for the shape of the company. The industrial story , refineries, pipelines, petrochemical complexes , is a story about moving crude oil and its derivatives at scale. The Indane story is a story about a cooking flame in a kitchen in a village that may never have had one before. Both are Indian Oil. Neither one is the whole picture without the other.
The Technology Underneath: Indian Oil’s R&D
One more piece is easy to miss if you only look at refineries and retail: Indian Oil has spent decades building in-house process technology, not just buying it.
The clearest example is INDMAX , a Fluid Catalytic Cracking technology developed by Indian Oil’s own R&D Centre, designed to maximise LPG and gasoline yield from heavy, low-value ends like Reduced Crude Oil. Its first commercial unit was installed at the Guwahati refinery, the same site where Indian Oil’s public-sector refining story began in 1962 , old infrastructure hosting new, homegrown technology.
That in-house capability extends into:
- Catalysts and process development for refining and petrochemicals
- Lubricant formulation, under the Servo brand
- Alternative fuels research, including the 3G ethanol plant and hydrogen pathways
It’s a quieter part of the Indian Oil story than a ₹34,000 crore refinery inauguration, but it’s the connective tissue between the old refining company and the current energy-transition company , the same R&D centre that perfected INDMAX in Assam is now the one working on green hydrogen electrolysis and carbon capture.
Indian Oil’s current capital allocation makes the strategic shift explicit in a way refining statistics alone don’t.
In August 2026, Director (Finance) Anuj Jain told investors the company would spend roughly ₹1 lakh crore over the next five to six years specifically on petrochemicals , lifting production capacity from 4.3 MMTPA today toward 13 MMTPA by 2030 , alongside a separate target of 18 gigawatts of renewable power capacity within three to four years. That 18 GW figure is a near-term milestone on the way to a larger, longer-dated goal: Indian Oil’s own roadmap calls for a 31 GW renewable energy portfolio by 2030, expanding further to 200 GW by 2050.
“Renewables and petrochemicals are the two sectors that will account for the bulk of our capex.” - Anuj Jain, Director (Finance)
That petrochemical push sits inside a larger, longer-dated commitment: in August 2022, Indian Oil declared it would reach Net Zero operational emissions (Scope 1 and Scope 2) by 2046 , deliberately chosen to coincide with India’s 99th year of independence , backed by an investment that has grown from an initial estimate of over ₹2 lakh crore to roughly ₹2.5 lakh crore in more recent disclosures.
Put together, the capital picture looks like this:
- ₹1 lakh crore : petrochemicals, through 2030
- 18 GW : renewable power target, three to four years
- ₹2.5 lakh crore : the full Net Zero roadmap to 2046, covering green hydrogen, CBG, renewables, carbon capture, and nature-based offsets
This isn’t a handful of green side-projects bolted onto a fuel company. It’s a structured, multi-decade capital-allocation transition, with the petrochemical spend as its nearest-dated component.
Annual capex guidance, climbing in step:
- FY25: ~₹35,000 crore
- FY26: ~₹33,000 crore
- FY27–FY29: run-rate approaching ~₹40,000 crore a year
That puts Indian Oil’s medium-term capital programme in the same range as major global energy companies , financed by a company that just posted a quarterly loss.
Green hydrogen, the harder road:
- 2021–2024: ambitious announcements for Mathura and Panipat; the flagship Panipat tender was cancelled twice, in February 2024 and again in October 2024
- 2025: Panipat project finally awarded to L&T Energy Green Tech , a 10,000 tonnes/year offtake-backed plant, meant as a replicable template across the refinery network
- Parallel push: a green hydrogen project announced at Kochi Airport, signalling intent to supply aviation-adjacent demand, not just refineries
- A dedicated green-energy vehicle, Terra Clean Limited, has since been set up to house these efforts
The unfinished ambition worth naming: alongside BPCL and HPCL, Indian Oil has for years been part of discussions around a mega 60 MMTPA refinery on India’s west coast in Maharashtra , the long-stalled project more widely known as the Ratnagiri Refinery. The same project Saudi Aramco was reported to be quietly stepping back from in early 2026, even as it explored a stake in BPCL’s Andhra Pradesh project instead.
It’s the clearest sign that not every large Indian refining ambition gets built on the timeline it’s announced on. It’s also a reminder that Indian Oil’s expansion, unlike BPCL’s single-site Andhra bet, is deliberately spread across many smaller, less politically fraught expansions rather than one enormous new-build.
Indian Oil’s transition isn’t only about petrochemicals and renewable power. There’s a parallel build-out happening in gas , moving the company from a liquid-fuels distributor toward what increasingly looks like a molecules-and-electrons company.
City Gas Distribution (CGD): Indian Oil now serves 49 geographical areas across 115 districts, bringing piped natural gas and CNG to homes, transport, and industry , a network that has expanded significantly from the roughly two dozen areas it covered just a few years ago.
LNG infrastructure: the Ennore LNG Terminal’s regasification capacity is being doubled, from 5 MMTPA to 10 MMTPA , approval received July 2026.
Compressed Biogas (CBG): a joint venture with Petronet LNG to develop 25 CBG plants across India, announced January 2026, feeding off the same SATAT scheme Indian Oil has backed for years.
Ethanol blending in petrol stands at 18%, with a near-term target of 20% , plus Ethanol100 fuel, now available at around 400 outlets, and involvement in the world’s first 3G ethanol plant.
The sequence is deliberate: natural gas and CGD infrastructure first, LNG import capacity second, CBG and biofuels third, hydrogen last , each layer building on the pipeline and distribution muscle the company already had.
Underneath the refineries and petrochemical complexes sits the business that actually touches most Indians day to day: the pump.
The network, by the numbers:
- 40,000+ retail outlets nationally - the largest fuel retail network in the country
- 20,000+ km pipeline network (see above)
- 43.1% domestic market share (quarter ended June 2026) , the highest among India’s three state refiners
- ~25% of outlets now carry EV charging infrastructure, as of early 2026
- Roughly 3.2 crore customers served daily across the retail network
That EV number is a sharp climb. Indian Oil had just 448 EV charging stations and 30 battery-swapping stations when it first set its expansion target in late 2021.
The retail model is changing shape, not just growing:
- Large-format outlets rebranded as “energy hubs” - petrol, diesel, CNG, and EV charging side by side
- A battery-swapping joint venture, Indofast, with Singapore’s Sun Mobility , letting two- and three-wheeler owners rent a battery and exchange it at the pump rather than wait to charge it
- Chairman Arvinder Singh Sahney, on where this goes next: “If some hydrogen comes, that too will be part of these large-format stores.”
None of that has a real analogue in the fossil-fuel retail business Indian Oil grew out of.
The Crude Nobody Can Agree On
The tension that opened this piece , a record operating quarter that still produced a loss , isn’t a one-off. It’s structural, and it runs through Indian Oil’s crude sourcing as much as its retail pricing.
How we got here:
- Since 2022: Indian Oil and its peers built a significant share of their crude diet around steeply discounted Russian barrels, flowing in the aftermath of Western sanctions on Russia following the invasion of Ukraine
- By late 2025: Russian-origin crude accounted for roughly a third of India’s total crude imports
- October 2025: the United States sanctions Rosneft and Lukoil directly , Russia’s two largest oil companies
That forced every major Indian refiner into a fast, awkward recalibration:
- Reliance Industries : India’s largest single buyer of Russian crude , halted Rosneft purchases outright, and stopped processing Russian oil at part of its Jamnagar refinery entirely
- Indian Oil " paused, then resumed, but explicitly “from non-sanctioned entities” only
“Russian crude is not sanctioned. It is the entities and the shipping lines that have come under sanctions… We are absolutely not going to discontinue as long as we are complying with the sanctions.” - Anuj Jain, Director (Finance), October 2025
The numbers moved fast: Russian oil imports into India fell to 1.38 million barrels a day in December 2025 , a 22% drop from the previous month , before dipping again to 1.215 million in January 2026. Russia remained India’s top single supplier anyway.
That’s not a footnote to Indian Oil’s story. It’s the same balancing act the company has been running since 1959, updated for a different decade: caught between what the market actually offers and what Delhi , and now, in a live and complicating way, Washington , will permit.
Epilogue: What Indian Oil Became , and What Comes Next
Indian Oil's history reveals a fairly consistent pattern.
It rarely replaces one energy system with another. It builds the next one around what already exists.
A refinery becomes a petrochemical complex. A pipeline network expands from products into crude and gas. A fuel station becomes an energy hub. A petroleum company moves into LNG, CBG, biofuels, EV charging, renewable power and green hydrogen.
That pattern is visible again in the projects now underway.
Panipat and Paradip are moving deeper into petrochemicals. Pipeline capacity continues to expand. Ennore LNG is moving toward 10 MMTPA. Green hydrogen has moved from repeated tenders to an awarded 10,000-tonne-per-year Panipat project. And behind all of it sits a ₹1-lakh-crore petrochemical programme and a ₹2.5-lakh-crore Net Zero roadmap to 2046.
So the next chapter of Indian Oil is unlikely to be a simple transition from oil to something else.
The evidence in 2026 points to something more complicated:
Indian Oil began in an era when India's challenge was securing greater control over petroleum.
Its next test is whether an energy system built around oil can successfully become something much larger than oil , without stopping being an oil company along the way.
And that leaves an interesting question for the industry:
With refining, petrochemicals, pipelines, gas, hydrogen, biofuels, renewables and electric mobility all being built at the same time, what will Indian Oil actually be ten years from now -an oil company, an integrated energy company, or something India hasn't built before?
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