India’s crude oil and energy trade, explained.
How crude oil and other energy imports changed, what India exports after refining, where the crude comes from, and how the wider energy system uses it.
The system view
Crude is the dominant import, but energy trade is broader than one fuel.
India imports crude, gas, refined fuels and industrial petroleum inputs. Its refineries also turn crude into a substantial stream of exported products.
$134.7bn
Crude imports
FY2025–26 · customs value
$200.7bn
Energy-product imports
FY2025–26 · customs value
88.7%
Crude import dependence
FY2025–26 · PPAC
$54.0bn
Energy-product exports
FY2025–26 · six HS-4 lines
India’s crude oil suppliers
Follow every year in the five-year transition, then switch between dollar exposure and physical tonnes to separate price effects from sourcing changes.
Share of crude imports
Switch between customs value and physical tonnes
India’s energy imports and refined-product exports
The flow view compares FY2025–26 customs values for crude oil, coal, gas, refined fuels and other petroleum products. Five-year change is summarized above the ribbons without crowding the chart.
Imports · FY25–26
$200.7bn
Import change
+4% since FY21–22
Exports · FY25–26
$54.0bn
Export change
-20% since FY21–22
241.6 MMT
FY2025–26 petroleum consumption · PPAC
Led by diesel (94.7 MMT), petrol (42.6 MMT), LPG (33.2 MMT), and industrial uses. This tonnage is not subtracted from the customs-value ribbons above.
Import and export categories are independently reported customs series. They meet at the energy-system node only to show that India refines, transforms and consumes energy; the ribbons do not claim that a specific imported category became a specific export.
India’s crude-price exposure, refining capacity and reserves
Imported volume determines how strongly global oil prices affect the bill. Refining capacity converts that crude into useful products, while strategic storage provides a limited disruption buffer.
India’s crude-import bill under different prices
Hold FY2025–26 import volume constant and move the assumed crude price.
$75/bbl
scenario price
$134bn
estimated annual crude cost
≈$17.9bn
Additional annual cost for every $10/barrel increase
Scenario uses 245.3 MMT of crude imports and an approximate conversion of 7.3 barrels per metric tonne. Actual customs cost also reflects crude grade, freight, insurance and timing.
Imported crude supplies nearly nine-tenths of demand
+7.0pp
since FY2016–17
PPAC’s consumption-basis measure; FY2025–26 is provisional.
India’s largest refinery sites
258.1 MMT/yr
all-India installed capacity
Reliance · Jamnagar
Gujarat
68.2
Nayara · Vadinar
Gujarat
20.0
BPCL · Kochi
Kerala
15.5
IOC · Panipat
Haryana
15.0
IOC · Paradip
Odisha
15.0
HPCL · Visakhapatnam
Andhra Pradesh
15.0
MRPL · Mangaluru
Karnataka
15.0
Capacity in million metric tonnes per year as at 1 April 2025. Reliance combines its 33.0 MMT domestic-tariff and 35.2 MMT SEZ units at Jamnagar.
Strategic petroleum reserves
5.33 MMT
operating Phase I capacity
≈7.9 days
at FY2025–26 import volume
Visakhapatnam
1.33 MMT
Mangaluru
1.50 MMT
Padur
2.50 MMT
Phase II: 6.5 MMT approved—not yet operating
Chandikhol (4.0 MMT) and a second Padur facility (2.5 MMT) would add roughly 9.7 days at FY2025–26 import volume. The government’s official benchmark for Phase I is 9.5 days using 2019–20 consumption.
Storage capacity is not the same as the amount of crude currently held.
One imported input becomes many domestic products
The refinery sits between the customs record and the final user. That is why crude-import data cannot directly answer which vehicle consumed it.
Imported crude
A raw input, not pump-ready petrol
Indian refineries
Separate and convert crude into many products
Road transport
Petrol and diesel
Aviation
ATF / jet fuel
Homes & kitchens
LPG
Petrochemicals
Naphtha and LPG feedstocks
Industry
Diesel, fuel oil and petcoke
Road building
Bitumen
28.0 MMT
Domestic crude production
245.3 MMT
Crude imported
272.1 MMT
Crude processed
284.9 MMT
Petroleum products produced
61.5 MMT
Petroleum products exported
FY2025–26 · PPAC. These indicators describe system scale, not a closed mass balance; inventories, refinery gains, feedstocks and product categories differ.
India’s domestic petroleum-use mix
PPAC reports consumption by petroleum product rather than by one exclusive end-use sector. This breakdown shows each product’s share of FY2025–26 consumption and connects it to the main purposes it serves.
Diesel
Freight, buses, farming and industry
39.2%
94.7 MMT
Petrol
Two-wheelers, cars and utility vehicles
17.6%
42.6 MMT
LPG
Homes, commercial kitchens and industry
13.7%
33.2 MMT
Pet coke
Cement and energy-intensive industry
7.6%
18.4 MMT
Naphtha
Petrochemicals and fertiliser feedstock
4.8%
11.7 MMT
Remaining
Derived remainder: fuel oil, lubes, LDO, kerosene and others
9.6%
23.1 MMT
Aviation fuel
Passenger and cargo aviation
3.8%
9.2 MMT
Bitumen
Roads and construction
3.6%
8.7 MMT
Domestic demand extends far beyond passenger mobility.
Diesel leads petroleum use by mass, while LPG, petroleum coke, naphtha, aviation fuel and bitumen connect the energy system to homes, freight, industry, travel and infrastructure.
FY2025–26 · 241.6 MMT total consumption · complete distribution grouped to avoid an unexplained remainder
State petroleum-product consumption
PPAC’s state sales data show where petroleum demand is concentrated. Toggle between total sales and sales per person to compare market scale with consumption intensity.
Apr–Sep 2024 consumption proxy
Petroleum-product sales · PPAC
Lower
Higher
Labels: share of India sales · colors: five equal state groups
Gujarat
12.1%
12.62 MMT
Share of India’s petroleum-product sales
Rank 1 of 36
India
104.48 MMT
Highest total sales
This is petroleum-product sales, used as a consumption proxy—not total energy use. It does not include electricity, coal used outside petroleum-product sales, gas or biomass. The per-person view helps separate population scale from consumption intensity; small territories can rank highly on that measure.
India’s petrol-pump operators
The distribution layer is led by Indian-controlled oil marketing companies. Pump-network share provides a consistent comparison; company revenue and annual fuel volume are shown separately with their reported scope.
≥92.6%
Indian-controlled pump footprint
Listed operators · FY2024–25
96,724
Petrol pumps nationwide
As at 1 April 2025
40.01 MMT
Petrol consumed
FY2024–25
91.41 MMT
Diesel consumed
FY2024–25 · 88% retail
Share of India’s petrol-pump network
Outlet count is the consistent distribution measure available across operators.
IndianOil
41.6%
HPCL
24.6%
BPCL
24.4%
Nayara Energy
6.9%
Jio-bp
2.0%
Shell India
0.3%
Other operators
0.2%
IndianOil
40,221 outlets
Government of India controlled
41.6%
Pump share
₹8.59 lakh cr
Revenue
85.0 MMT
Domestic petroleum-product sales
HPCL
23,747 outlets
Government of India controlled
24.6%
Pump share
₹4.66 lakh cr
Revenue
30.0 MMT
Retail sales · petrol 9.8 MMT
BPCL
23,642 outlets
Government of India controlled
24.4%
Pump share
₹5.00 lakh cr
Revenue
52.4 MMT
Market sales · petrol 10.74, diesel 21.56 MMT
Nayara Energy
6,683 outlets
Indian-incorporated · foreign-controlled
6.9%
Pump share
₹1.49 lakh cr
Revenue
8.3 Mn KL
Petrol and diesel sold through retail outlets
Jio-bp
1,916 outlets
Indian-controlled JV · RIL 51%
2.0%
Pump share
Not disclosed
Revenue
6.0 Mn KL
Petrol and diesel retail sales
Shell India
325 outlets
Foreign-controlled
0.3%
Pump share
Not disclosed
Revenue
Not disclosed
India retail fuel volume
Revenue is company-wide revenue from operations, not profit or petrol-pump revenue alone. Annual volume follows each company’s own disclosure and is labelled by scope; MMT and million kilolitres are not directly interchangeable. Jio-bp and Shell do not publish standalone India fuel-retail revenue in the cited sources.
Sources & method
Data definitions, source links and freshness notes
Sources & method
Data definitions, source links and freshness notes
Import values and source-country shares are from the Ministry of Commerce & Industry’s TradeStat commodity-wise country table. Product consumption, crude import dependence and gross petroleum trade come from the Petroleum Planning & Analysis Cell’s June 2026 oil and gas snapshot. The FY2024–25 fuel-distribution baseline uses PPAC’s April–March industry report. State petroleum-product sales and per-capita sales use PPAC’s H1 FY2024–25 Ready Reckoner; company revenue, outlet and sales-volume figures come from the annual reports linked in the operator table. Map geometry is simplified from Anuj Tiwari’s MIT-licensed state boundary dataset.
Refinery figures use PPAC’s installed refinery capacity table. Strategic-storage capacity and Phase II status come from the Ministry of Petroleum & Natural Gas’s March 2025 reserve update. The price scenario uses the EIA’s approximate 7.3 barrels-per-tonne conversion.
Country shares use TradeStat’s principal commodity “Petroleum: crude”. Value shares are reported by TradeStat; volume shares and unit values are derived from its tonnes series. Product mix uses HS-4 customs lines. PPAC figures describe the energy system and are kept separate from customs totals. State-map colors are quantile bands, with an equal number of states and UTs in each band. Price sensitivity holds import volume constant and is not a forecast. Reserve-day estimates divide stated capacity by FY2025–26 crude-import volume; they measure capacity, not current inventory. Pump shares divide each reported outlet count by the national total of 96,724. MMT means million metric tonnes; TMT means thousand metric tonnes; percentage-point changes may differ slightly due to rounding.
Freshness: TradeStat retrieved 1 August 2026 · PPAC energy data through FY2025–26 and June 2026.