China Taps Reserves as Iranian Crude Dries Up, NEA Orders More Drilling

Chinese refiners drew 530,000 barrels per day from storage in September to cover a widening gap between crude runs and imports, and Beijing's answer is now official: drill more at home. Following an October 21 meeting, the National Energy Administration has directed PetroChina, Sinopec and CNOOC to expand production capacity, increase investment and accelerate the building of national oil and gas supply bases, with steady growth in crude output and rapid growth in gas.

The directive lands after eight months of Middle Eastern supply disruption and the effective disappearance of Iranian crude from the market. When the Iran war began in February, China held an estimated 1.3–1.4 billion barrels in commercial and strategic inventories. That cushion let refiners slash imports rather than chase Brent above $100. In June alone, Chinese crude imports fell by an estimated 4.4 million bpd against the 2025 average — a reduction that offset part of the global supply lost to the conflict.

How far can the stockpile stretch?

September tells the arithmetic plainly. Refiners processed roughly 13.99 million bpd, according to official data: 4.43 million bpd of domestic production and 9.03 million bpd of imports. The remaining 530,000 bpd came out of tanks — the fourth inventory draw in five months.

China is not running dry. EA Crude Oil Inventories data put onshore stocks at about 1.192 billion barrels in the week ending October 19, down 162 million barrels from the early-May record but only 13 million barrels below the same period last year. The plain takeaway: Beijing has spent the war consuming cheap barrels bought earlier while keeping most of its cushion intact.

What happens now that Iranian barrels are gone?

The remaining discount outlet is closing. Iranian exports that kept reaching Chinese buyers from offshore storage even after Washington imposed its naval blockade have reportedly dried up. Kpler estimates Iran's floating crude inventories available for delivery to China fell below 1 million barrels by October 5 and were subsequently exhausted.

For years, discounted Iranian barrels helped independent refiners offset thin margins, with shadow-fleet tankers and offshore storage keeping the trade alive under sanctions. Now those refiners must replace them with costlier grades from the Middle East and Africa, often at extraordinarily high freight rates.

Beijing is also courting Moscow. On October 21, China and Russia agreed to support companies seeking to expand oil cooperation, Chinese state media reported — though the announcement carried no specific new supply commitments. Russia's production is declining, and expanded deliveries would require sufficient pipeline and shipping capacity, financing, and available crude.

Can domestic production fill the gap?

Not soon, but the base is real. China produced about 216 million metric tons of crude in 2025, a record, and gas output exceeded 260 billion cubic meters, with gas rising by more than 10 bcm annually for nine straight years. Still, September imports ran more than double domestic crude output.

The growth strategy now leans on deepwater exploration, deep formations, unconventional resources and enhanced recovery at mature fields — capital-intensive plays requiring specialized equipment and years of buildout, all against natural decline rates. State producers have the balance sheets and political direction to back projects that couldn't compete with cheap imports on commercial terms, but an unattractive barrel looks different when imports cost more than $100.

Gas carries its own urgency: Persian Gulf LNG disruptions showed import vulnerability extends beyond crude, and industrial and power demand keep growing. The regulator's strategic supply bases are meant to support longer-term production, not just add storage — inventories can cover a shortage today; new oilfields cannot.

What's the watch item?

Near-term purchases still track price. October imports should recover above 10 million bpd on cargoes booked when Brent dipped below $80 in August, but with prices climbing again, FGE NexantECA and Energy Aspects have cut fourth-quarter Chinese import forecasts to roughly 9.2–9.3 million bpd.

Beijing can keep drawing inventories when prices are unattractive and rebuilding on weakness, and modest gains in domestic output, stockpiles and supplier diversity could soften how hard the world's largest importer must compete for available barrels. With global supply already tight, China's willingness to buy less when prices rise remains one of the few big flexibilities left in the market. The number to watch is the next monthly inventory draw.