Why Oil Futures Went Negative in April 2020

In April 2020, WTI crude oil futures fell below zero for the first time, with contracts trading at minus $37 per barrel. The collapse wasn’t mysterious once you understood the squeeze: physical storage was maxed out, demand had collapsed during the pandemic lockdown, and traders holding May contracts faced a choice between accepting delivery of oil they couldn’t store or paying others to take it off their hands.

The Storage Crunch

When global lockdowns cut oil demand by roughly one-third in early 2020, refineries and consumers simply stopped buying. But oil production didn’t stop immediately. Tankers kept arriving, pumps kept running, and storage tanks filled to capacity across North America. The U.S. Strategic Petroleum Reserve and commercial storage facilities at Cushing, Oklahoma—the delivery point for WTI contracts—were nearly full. Every barrel of oil produced had to go somewhere.

Normally, producers can hold excess oil in storage, wait for demand to recover, and sell later. But storage is finite, and by late April the cost of renting tank space was climbing. More importantly, available storage was running out. Once every tank was full, producers faced a nightmare: pay to keep output underground, mothball wells (expensive to restart), or accept pennies for immediate sale.

How Futures Contract Expiration Works

Here’s where the mechanics became brutal. The May 2020 WTI contract was set to expire on April 21. Traders holding long positions faced three choices: sell the contract before expiration (take the loss), roll forward to the June contract (bet prices would recover), or accept physical delivery of 1,000 barrels of crude oil.

Physical delivery sounds straightforward. In reality, it means arranging transport, securing storage space, and taking possession of oil at Cushing. For speculative traders—which make up the bulk of futures contracts—holding oil was economically impossible. They had no refinery, no tanks, no use for physical crude. They had to sell.

As expiration neared, holders of May contracts faced a deadline. The last trading day was April 20. Anyone still holding contracts at the close would be assigned 1,000 barrels. The pressure to exit before the deadline created a cascade: sell orders piled up, buyers disappeared, and the price slid toward zero, then past it. Someone would buy the contracts, but only if the seller paid them. The holder would literally pay the buyer to take the contract off their hands and assume delivery obligation.

Why Prices Crossed Below Zero

On April 20, the May contract closed at −$37.63 per barrel. The mechanism is subtle. A trader holding a contract might pay −$37 not out of charity, but because staying long for one more day meant mandatory delivery. To avoid that obligation, they would pay $37 per barrel to a buyer willing to accept delivery instead.

This was rational. Storing 1,000 barrels of oil for even a few days could cost $100 to $500 in rent and logistics. So paying $37 to exit the contract was the cheapest way out. The June contract, with more time before expiration, stayed positive but fell sharply. Over the next weeks, as storage filled further and demand remained depressed, June futures also approached zero before recovering.

Crucially, this happened only in the front-month (nearest-term) contract. The structure of the futures curve meant that further-out contracts remained positive. Traders could roll from May to June and beyond, avoiding negative prices by shifting the delivery obligation forward. But the May contract, with nowhere left to run, bore the full brunt of the supply glut.

Who Got Caught

Most heavily affected were commodity trading firms and speculators who had positioned for a bounce-back. Major hedge funds and proprietary traders had built large long positions in the hope that storage would fill, production would fall, and prices would recover by April. They were wrong on timing. A few high-profile funds sustained severe losses when the market moved against them and they scrambled to exit at any price.

More broadly, passive index trackers and other momentum-following strategies got hurt. Many commodity indices automatically roll positions from the expiring front-month contract to the next month, locking in whatever price was available at rollover. Funds tracking oil indices took losses rolling from May (negative) to June (depressed).

Producers hedging their output fared better, as their short positions (contracts to sell oil) moved in-the-money. But the damage to financial buyers was real and visible: one fund lost billions, and the event became a cautionary tale about futures liquidity and the difference between financial and physical price discovery.

The Broader Lesson

The negative-price event revealed a fault line in crude oil futures. The contract is designed for hedging and speculation, not for storing oil. When financial demand dries up, the price of the expiring contract can plummet, while the physical market (actual transactions between producers, traders, and refiners) may reflect fundamentals more closely. In April 2020, a June futures contract that was still positive could coexist with a May contract at −$37 because buyers weren’t willing to take May delivery—only June, when storage space might have opened up.

The crash also illustrated the limits of leverage and the power of a deadline. Futures are leveraged products; you can control many barrels with a small deposit. When you’re forced to exit before the deadline, you’re a seller at any price. The market found that price: negative.

Within weeks, as demand slowly recovered and storage began draining, prices rebounded. By June, crude was trading above $30, and by late 2020 had climbed further. But for those who held May 2020 contracts into the final session, the lesson was stark: never ignore the contract’s delivery mechanics, and never assume liquidity will be there when you need it most.

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