Asia is trying to save itself any way it can. With Gulf barrels harder to get, buyers are pulling crude from wherever it is still available – even from as far away as Brazil. The barrels are alike to those stranded by the Strait of Hormuz blockage, Asia’s appetite for them need is soaring. The only problem is that they have to cross half the world first.
The timing of the US-Iran war could hardly be better for Brazil. Its crude exports reached a record 2.3 million b/d in March and stayed at the same level in April, just as China was losing access to a large part of its usual crude needs from the Gulf. Before the crisis, Middle Eastern crude exports to China were averaging 5-5.2 million b/d, almost half of total seaborne imports. By April, those flows had fallen to about 2.4 million b/d. Saudi Arabia alone saw its exports to China drop by around 600,000 b/d between February and March, to roughly 1 million b/d, losing its position as China’s second-largest seaborne crude supplier. Brazil moved into that space quickly. Its share of China’s total crude imports rose from around 10% in January to roughly 18% in April, even as China’s overall import demand weakened. The 1.43 million b/d of Brazilian crude that Chinese refiners bought last month is the highest monthly reading on record, surpassing the previous record posted in February.
China’s soaring demand only highlights the importance of the country’s import patterns. Sinopec is the anchor buyer, while PetroChina, CNOOC and Sinochem take in smaller volumes. Before the crisis, state-led companies were already buying roughly 55-75% of Brazilian crude imports into China. As Gulf supply tightened, their share rose to 83% in February and around 91% in April, according to Kpler. Smaller independent refiners could not compete with the financial strength and supply-security mandate of state firms. In a tighter physical market, Brazilian oil cargoes became a strategic replacement for lost Gulf crude.Related: Petrobras Hits Record Output as Refining Gains Reduce Imports
India’s sudden interest in Brazilian grades quickly turned it into the second-largest Petrobras client in Asia. Before the crisis, India was importing a total of around 5.2 million b/d of crude. Brazil was already present in the Indian refining slate, but largely through occasional cargoes. In April, Brazil became India’s fourth-largest crude supplier, sending around 290,000 b/d, up by about 200,000 b/d year-on-year. Twelve Brazilian crude cargoes were offloaded in India in April, while 17 were already heading there for May, including two VLCCs that had offloaded in the first days of the month, indicating a rising trend in total cargo volumes.
The more interesting shift is inside India’s buyer mix. In 2025, Brazilian crude was mostly a public-sector refiner trade, with state-owned IOC accounting for around 80% of imports and private Reliance for around 20%. In January-April 2026, Reliance’s share rose to almost half of visible volumes, state companies took around 40%, and HMEL (a mix of public and state ownership) accounted for another 10%. That is a major difference from China. In China, Brazilian crude is becoming more concentrated in state hands. In India, it is moving deeper into the complex-refining system, where buyers are driven by yield, margin, and crude economics rather than just supply security.
The appeal is partly in the Brazilian barrel itself. Tupi and Buzios, Brazil’s two key export grades, are around 30 and 28 degrees API, respectively, with a low sulphur content. They are medium-sweet crudes, close enough to some of the Gulf barrels Asia has lost and useful for refineries trying to protect middle-distillate yields. That matters in a market short of diesel and jet fuel. For China, the value is security of supply. For India, it is also refinery economics: complex plants can use Brazilian crude to support product output at a time when domestic fuel demand is still rising.
Brazil has the production base to make its Asian pivot viable. Domestic crude output reached around 4.24 million b/d in March, up about 15% year-on-year from 3.6 million b/d in March 2025. State-owned Petrobras alone reported total oil production of about 3.73 million b/d in the same month, equivalent to 88% of the country’s production. With extra barrels available, the state oil company fully shifted its focus on Asia and reported early May that it had cut crude exports to the US to zero from around 60,000 b/d in March. The commercial logic is straightforward. Asia needs the barrels more, and the margins are better. Consequently, more than 60% of Petrobras exports are now going to China.
The ceiling, however, is not just Brazilian supply. It is also dictated by the shape of Asian demand and freight economics. In April, China’s crude oil imports fell by around 77 million barrels month-on-month – a 25% fall compared to March. It coincided with the ongoing weakening of fuel demand in the domestic market: China’s gasoline demand is falling by around 3.5% and diesel by about 5% year-on-year, reflecting electrification, weaker industrial activity, and a weaker demand in the road-fuel market. However, that alone does not explain April’s crude import collapse. The April import plunge was driven by a proper supply shock, not just a demand correction. Strategic reserves can cushion the gap in the short run, but they do not solve the physical problem if Gulf barrels remain constrained. This would suggest further growth of Brazilian crude volumes coming to China. However, that is where freight starts to dictate trade flows. Brazil can supply China, but it is geographically too remote. The voyage to China is roughly 50 days, tying up VLCCs and raising delivered costs in a market where tanker availability has become part of the crude price. Moreover, Russia’s Arctic barrels will become more competitive as the Northern Sea Route opens seasonally. From Russian Arctic terminals to China, the journey can take around 25-27 days from May to November, roughly half the Brazil-China route. That does not make Brazilian crude irrelevant, but it limits how much further China can lean on it once shorter-haul (and slightly cheaper) Russian options become available.
India has a stronger case for sustained Brazilian inflows. Unlike China, India is still adding road-fuel demand: gasoline consumption is rising by around 6% year-on-year and diesel by about 3.5%. India also has less strategic reserve flexibility than China, so refiners have less room to absorb a prolonged supply disruption through stock draws. If crude is available and the refinery economics work, Indian buyers have a clear reason to keep taking it. The shift from IOC-led buying in 2025 to a Reliance-heavy slate in early 2026 suggests Brazilian crude is no longer just a diversification cargo. It is becoming a more active part of India’s refining economics.
Brazil’s rise in Asia is therefore not a simple export-growth story. It is the result of three forces arriving at once: Gulf supply disruption, Brazilian production growth, and crude specifications that fit Asian refinery needs. China is buying Brazilian barrels because it needs to replace stranded Gulf oil, and its state companies have joined the import spree alongside Shandong teapots. India is buying them because demand is still growing, and complex refiners can make the economics work. Petrobras is redirecting exports because Asia pays better than the US, and the trend is likely to persist in the foreseeable future. The only stubborn obstacle is geography. Brazil has become one of Asia’s emergency crude suppliers, but every barrel still has to cross half the world before it can fix the shortage.
