Washington is putting national-security money behind an industry normally associated with commercial energy markets. On October 22, the Trump administration announced plans to make up to $150 million in Defense Production Act funding available to expand U.S. petroleum production, storage and refinery logistics, arguing that domestic fuel infrastructure is critical to military readiness and economic security.
The legal foundation for that push was laid earlier in 2026, but the new funding plan turns that authority into a potentially significant industrial-policy tool. It also highlights an awkward feature of American “energy dominance”: despite producing more crude oil than any other country, the United States still relies heavily on Canadian barrels. Canada supplied 63.4% of all U.S. crude imports in 2025, making the two countries’ petroleum systems far more intertwined than political slogans about energy independence sometimes suggest.
Washington Is Treating Refining Capacity as a Defence Asset
The administration’s ability to channel defence-related support into petroleum infrastructure comes from Section 303 of the Defense Production Act, the 1950 law created during the Korean War era to ensure that industries essential to national security could expand when ordinary market conditions were considered inadequate. A presidential determination issued on April 20 identified domestic petroleum production, refining and logistics as resources essential to national defence. It specifically covered exploration and production, gathering and transmission pipelines, storage facilities and marine terminals.
That determination went further than simply declaring oil strategically important. It said constrained financing, long project timelines, permitting bottlenecks, infrastructure limitations and supply-chain problems could prevent private industry from providing enough capacity quickly enough. The administration therefore authorized tools such as purchases, purchase commitments and financial support for additional production capability. Because a national energy emergency had already been declared, Trump also waived several normal Section 303 requirements. The result is a broader federal financing channel capable of reaching parts of the petroleum system far beyond military bases themselves.
Up to $150 Million Is Now on the Table for Refineries
The Department of Energy’s October 22 announcement puts real money behind that authority. DOE said it intends to make as much as $150 million in Defense Production Act Title III funding available for projects that expand petroleum production, storage and logistics associated with U.S. refineries. The department said the investments are intended to increase production of gasoline, diesel, jet fuel and other petroleum products, with combined projects expected to add millions of gallons of daily refining output.
The $150 million initiative sits within a larger pool of federal resources. Congress provided $1 billion for the Defense Production Act through the 2025 reconciliation law, with the Trump administration increasingly directing those authorities toward energy infrastructure judged important to national security. DOE has not yet published a complete list of winning petroleum projects, and its October 22 announcement said the selection process remained underway. That detail matters. An authorization for $150 million does not mean every dollar has already been committed, nor does it establish exactly how much new refining capacity will ultimately reach the market.
Delek’s Texas Refinery Shows What the Strategy Could Look Like
One early example emerged before the broader funding announcement. Vice President JD Vance said on October 13 that the administration planned to use the Defense Production Act to help expand Delek US Holdings’ refinery in Tyler, Texas. The facility currently processes roughly 74,000 barrels of crude per day. Vance presented the project as a way to produce additional commercial fuel as well as fuel meeting military requirements, linking everyday consumer energy costs with the Pentagon’s need for secure supplies.
Important details remain unresolved. Neither the administration nor Delek initially disclosed the size of the federal contribution, the amount of additional refining capacity expected from the project or a construction timetable. That is significant because refinery expansions are generally capital-intensive projects that can require months or years of engineering, permitting and construction. Still, Tyler provides a practical illustration of how the new policy could work: Washington can identify an existing privately owned refinery, classify additional capacity as strategically useful and then employ Defence Production Act authorities to help overcome financial or infrastructure barriers that might otherwise delay an expansion.
Canada Still Supplies Nearly Two-Thirds of U.S. Crude Imports
For Canada, the scale of existing trade makes the U.S. funding push particularly important. Canada supplied 63.4% of all crude oil imported by the United States in 2025, according to the Canada Energy Regulator. U.S. Energy Information Administration data show American imports of Canadian crude averaged approximately 3.9 million barrels per day that year. No other foreign supplier comes close to matching that volume.
The relationship is equally important from Canada’s perspective. Canadian producers exported about 4.3 million barrels of crude per day in 2025, with approximately 3.9 million barrels per day, or 90.1%, destined for the United States. That concentration reflects decades of investment in pipelines, storage terminals and refineries constructed around cross-border flows. The Canada Energy Regulator also reported that crude oil accounted for the largest share of Canadian hydrocarbon exports to the United States. Even as Ottawa and western Canadian producers increasingly discuss trade diversification, the U.S. remains by far the dominant customer. Any major change in American refinery investment therefore has consequences well beyond the U.S. oil industry.
Record American Oil Production Does Not Eliminate the Need for Imports
The dependence on Canadian crude can sound counterintuitive because the United States is simultaneously the world’s largest oil producer. U.S. crude production averaged a record 13.6 million barrels per day in 2025, according to the Energy Information Administration. That was roughly 3% higher than in 2024 and continued a run in which American shale regions, particularly the Permian Basin, pushed domestic output to levels unmatched by any other country.
But barrels are not interchangeable. Much of the newer U.S. production is relatively light, low-sulfur crude, while many sophisticated American refineries were built or upgraded to process heavier and higher-sulfur grades. Canadian oil-sands production provides large quantities of precisely those heavier barrels. EIA has repeatedly noted that complex U.S. refineries can find discounted heavy crude economically attractive because they already possess equipment capable of converting it into gasoline, diesel and jet fuel. The United States can therefore export millions of barrels of its own lighter crude while simultaneously importing Canadian heavy crude without the two flows being contradictory.
Midwest Refineries Are Especially Tied to Canadian Barrels
The strongest Canadian connection is found in the American Midwest and parts of the Mountain region, where pipeline geography has made western Canadian oil a fundamental refinery feedstock. EIA has reported that nearly all crude oil used by refineries in those regions comes from Canada. Midwest operable refining capacity stood at approximately 4.25 million barrels per day in 2025, and those facilities recorded an annual utilization rate of 93.2%, illustrating how heavily the existing system is already used.
The pipelines feeding that network are similarly busy. The Canada Energy Regulator reported that the Enbridge Mainline moved an average of about 3.08 million barrels per day across its Manitoba border point in 2025, while available capacity averaged roughly 3.23 million barrels per day. That translated into average utilization of 95.2%. These are not easily replaced trade relationships. Refineries, pipelines, storage facilities and crude-quality requirements have developed together over decades. A policy designed to strengthen U.S. refining could consequently reinforce demand for Canadian feedstock in some regions rather than automatically displace it.
Military Fuel Demand Explains the National-Security Argument
Calling refinery capacity a defence asset is more than rhetorical because the U.S. military is an enormous petroleum customer. Defense Logistics Agency Energy says it procures roughly 80 million barrels, or about 3.36 billion gallons, of petroleum fuel annually while also managing transportation of tens of millions of barrels of inventory to military fuel-support locations around the world. Those supplies include aviation fuels such as JP-5 and JP-8 as well as marine diesel and other refined products.
The individual service numbers help put that scale into perspective. DLA reported approximately 1.5 billion net gallons of bulk fuel support for the U.S. Air Force in fiscal 2025 and another 1.1 billion gallons for the Navy. DLA Energy’s fiscal 2025 spending data also show more than $8 billion in obligations associated with petroleum refineries. In a major conflict or supply disruption, crude oil in the ground is only part of the equation. Aircraft, ships, trucks and generators require refined fuels in the correct specifications, delivered through resilient logistics networks. That is why Washington is increasingly treating refining, storage and transportation capacity as part of the defence industrial base.
More U.S. Refining Does Not Automatically Mean Less Canadian Oil
For Canadian producers, the most important distinction is between expanding American refining capacity and replacing imported crude. They are not necessarily the same policy. The April presidential determination focuses on infrastructure located in the United States: production facilities, refineries, pipelines, storage and marine terminals. The October funding announcement did not announce a new ban or quota on Canadian crude. Instead, it targets the ability of U.S. facilities to turn crude into usable fuels.
That could produce very different outcomes depending on which projects receive money. If additional capacity is designed primarily around lighter domestic shale crude, American refiners could process more U.S.-produced barrels. But if federal support expands complex refineries already configured for heavy oil, Canadian suppliers could benefit from higher feedstock demand. EIA has specifically identified Canadian heavy crude as attractive to sophisticated U.S. refineries. Project location will therefore matter almost as much as the amount of federal funding. A refinery expansion in an inland market connected directly to Canadian pipelines carries different implications than additional light-crude capacity near a major U.S. producing basin.
Trans Mountain Has Given Canada More Room to Diversify
Canada is less dependent on a single export route than it was only a few years ago. The expanded Trans Mountain system, which entered service in 2024, provided western producers with much greater access to the Pacific coast. In 2025 the pipeline transported an average of about 761,000 barrels per day and operated at roughly 85% of available capacity. Shipments from its Westridge Marine Terminal increasingly moved heavy Canadian oil toward the U.S. West Coast and Asian markets.
That change is already visible in trade statistics. The Canada Energy Regulator says the share of Canadian crude exports going to countries other than the United States increased to about 9% in 2025, compared with roughly 2% in 2021. EIA also reported that U.S. crude imports from Canada fell around 4% in 2025, partly because increased Trans Mountain utilization allowed producers to reach other buyers. Yet diversification should not be confused with separation. Approximately nine of every 10 Canadian export barrels still went to the United States in 2025, leaving the American refinery system central to Canadian oil economics even after the Pacific expansion.
The Next Test Is Where Washington Actually Spends the Money
The October announcement establishes a funding direction, not a finished map of projects. DOE says the selection process for the petroleum initiative is still underway, while the presidential determination gives the government considerable flexibility to support exploration and production, pipelines, storage facilities, refineries and marine terminals. That means the most consequential details will come when Washington names recipients, funding amounts, required private investment and expected additions to capacity.
There is pressure to move quickly. EIA reported a national average on-highway diesel price of $6.276 per gallon for the week ending October 19, 2026, more than $2.65 above the level recorded a year earlier. The administration is presenting additional refining capacity as part of its response to tight fuel markets and global supply disruption. Yet building durable refining and logistics infrastructure cannot produce instant barrels of gasoline or diesel. For Canada, the key question is whether this new U.S. defence-financing channel eventually competes with Canadian crude or strengthens the cross-border system that already supplies most American imported oil. The answer will be found in the projects Washington chooses to fund.
