DOE Seeks 40 Million More Reserve Barrels, Testing Two-Site Delivery

The U.S. Department of Energy has solicited an exchange of up to 40 million barrels from the Strategic Petroleum Reserve’s Big Hill and Bryan Mound sites. The request is part of the previously announced 172-million-barrel U.S. release coordinated with other International Energy Agency members.

The solicitation creates a concrete test of whether two named sites can supply a large volume on a defined schedule. DOE says its earlier exchanges demonstrated rapid delivery, but the new request does not disclose or prove the reserve’s maximum sustainable emergency flow rate. Scheduled contract performance and reserve-wide emergency capability are related measures, not interchangeable ones.

Bids are due by 11 a.m. Central Time on October 6, 2026. The action follows five earlier solicitations that collectively awarded more than 133 million barrels across four completed exchanges. DOE says deliveries under awarded exchanges are scheduled for November and December 2026.

Inventory is not the same as deliverable supply

The distinction matters because the reserve held 284.6 million barrels in the week ending September 18, its lowest inventory since November 1982. Its net decline during 2026 had reached 125 million barrels amid a disruption to tanker traffic through the Strait of Hormuz, a waterway that normally carries roughly one-fifth of the world’s seaborne oil.

A barrel in inventory counts toward the national reserve, but emergency performance also depends on whether the relevant cavern, well, pump, pipeline connection and supporting equipment are available when needed. A successful 40-million-barrel exchange would demonstrate that Big Hill and Bryan Mound can execute the awarded delivery schedules. It would not establish how long the entire reserve could maintain its nominal peak rate under a broader or longer emergency.

DOE criteria list a designed withdrawal rate of 4.415 million barrels per day. Yet a Government Accountability Office assessment found that effective withdrawal capability stood at 61% of the designed rate as of December 2025. More than one-quarter of the inventory was then unavailable for withdrawal, largely because Big Hill lacked withdrawal and fill capability during life-extension construction.

Those figures are a dated system-level assessment rather than a statement of Big Hill’s condition for this solicitation. The current request indicates that DOE now plans to draw crude from Big Hill, but fresh operating data would be needed to determine how much capability has been restored and how the two sites contribute to the delivery schedule.

Oil can leave much faster than it can return

DOE is using exchanges rather than outright sales. Participating companies borrow crude and contractually return an equivalent quantity of similar oil plus premium barrels. That structure provides a path to rebuild inventory and can reduce the government’s effective acquisition cost. It does not preserve the same emergency flexibility while the barrels are outside the reserve.

The designed fill rate is 785,000 barrels per day, less than one-fifth of the designed peak withdrawal rate. The December 2025 GAO assessment placed effective fill capability at 56% of design. Separately, a brine-disposal problem at West Hackberry reduced that site’s stated fill capability from 225,000 to 112,000 barrels per day. Based on the stated site limits, the calculated combined maximum is 672,000 barrels per day under optimum conditions.

At that rate, returning 133 million barrels would require at least 198 days of continuous filling. Actual replenishment could take longer because return dates, crude specifications, construction outages and site availability must all align. DOE’s exchange mechanism guarantees a contractual obligation to return oil, not instantaneous restoration of emergency capacity.

This creates a tradeoff for fuel consumers and emergency planners. Releasing crude can address an immediate supply disruption, while premium barrels may eventually increase the quantity returned. During the interval between withdrawal and repayment, however, the country has fewer stored barrels and a refill system that operates much more slowly than the withdrawal system.

The reserve also cannot accept just any available crude. DOE has said it does not store oil below 22.3 degrees API because the operational costs outweigh the benefits; the Venezuelan heavy grades discussed as possible substitutes fall below that threshold. Replacement oil therefore has to satisfy contractual timing and the reserve’s quality requirements.

The November and December delivery schedule will provide a meaningful operational data point for Big Hill and Bryan Mound. The more consequential milestone will come later: how quickly the contracted barrels and premiums are actually returned while maintenance, construction and emergency readiness continue across the four-site system.

By Thomas Caldwell — AMI’s senior editor for mechanical and mobility engineering, covering vehicle electronics, systems integration, electrification, chassis systems, propulsion, and safety policy.