Frontieras Signs 30-Year Coal-to-Liquid Diesel Deal at Wyoming Mine

On 1 September 2026, Frontieras North America and Western Fuels signed a memorandum of understanding (MOU) to build a mine-mouth coal-to-liquid fuel facility at Wyoming’s Dry Fork Mine, locking in a framework for up to 5.4 million short tons of coal feedstock a year and a 30-year diesel offtake arrangement. That is a defined scope, not a concept study, and the numbers say so.

The timing matters. US coal has spent years losing ground in power generation, and this agreement is a deliberate attempt to reroute coal’s commercial future through fuel conversion rather than combustion.

It is also not an isolated move. The Dry Fork MOU lands five months after Frontieras broke ground on an $850 million facility in Mason County, West Virginia, a signal that a single company is now moving from concept to parallel execution in two coal basins at once. Here is what each party has actually committed to, where the Wyoming deal sits alongside Frontieras’s broader build-out, and the milestones worth tracking before the MOU becomes a project worth pricing.

What the Dry Fork deal commits each party to

The MOU is built from four interlocking commercial obligations, each a framework for a definitive agreement rather than a signed contract. That distinction runs through the whole deal.

The four components break down as follows:

• Ground lease: a site at or adjacent to the Dry Fork Mine near Gillette, Campbell County, where the FASForm facility would be built.
• Coal feedstock supply: Wyoming sub-bituminous coal delivered to the plant, ramping over the life of the project.
• Diesel offtake: Western Fuels would buy the ultra-low-sulfur diesel (ULSD) produced on site for its mining, haul, and member operations.
• Logistics: Frontieras would draw on Western Fuels Association’s existing rail infrastructure to move the facility’s product streams to market.

The feedstock ramp is the number that defines the deal’s ambition.

Advanced coal conversion economics in the US context are shaped by oil price sensitivity, regional labor markets, and the absence of a federal backstop, three variables that simultaneously make mine-mouth CTL projects attractive to coal basin operators and difficult to finance through conventional capital markets.

The coal supply agreement contemplates an intake of initially up to approximately 2.7 million short tons per year, rising to approximately 5.4 million short tons per year at full build-out, each on an initial 30-year term.

Set that against what Dry Fork actually digs out today, and the scale reads differently. The mine produced 1.08 million short tons in the second quarter of 2026, up from 1.00 million short tons in the same quarter of 2025, according to Mine Safety and Health Administration (MSHA) data. Global Energy Monitor put its 2024 saleable output at roughly 3.59 million tonnes.

At full build-out the facility would swallow coal at roughly 1.5 times the mine’s current annual saleable production. In practice, that means the mine’s entire output, and then some growth on top, would need to feed the plant.

The process itself is Frontieras’s FASForm Solid Carbon Fractionation technology, described as a continuous, closed-loop process that disassembles coal in a reducing atmosphere rather than burning it, yielding ULSD, naphtha, clean solid carbon, and other products. What matters for you as an observer is the gap between framework and funded project. Financial terms and construction dates for Dry Fork remain undisclosed, and that gap is precisely where most coal-to-liquid proposals have historically stalled.

Frontieras’s two-basin strategy: how Dry Fork fits the Mason County blueprint

To understand whether Dry Fork is credible, look at what Frontieras is already doing in West Virginia. Mason County is the working prototype.

That project is the first commercial-scale FASForm deployment: $850 million total, split into roughly $390 million for infrastructure and off-site battery limits and $460 million for the FASForm unit and processing equipment. Frontieras closed on 183 acres on 19 January 2026, broke ground on 2 April 2026, and is targeting commissioning in Q1-Q2 2028. In August, it named Yokogawa Corporation of America as its main automation contractor.

The structural parallels with Dry Fork are deliberate. Both projects start at approximately 2.7 million short tons of coal a year. Both pursue long-term offtake agreements covering the full slate of outputs. Both sit mine-mouth or coal-basin-adjacent.

Mason County’s economics carry real regional weight. Frontieras projects roughly 300 permanent jobs, though the West Virginia Department of Economic Development cited around 200; the discrepancy is not explained in public materials. Wages sit in the $70,000-$80,000 range, about 200% of the prevailing wage, with some 2,000 contract workers over 24 months during construction and an estimated 3% incremental state GDP impact once operational.

Where the two projects diverge

The feedstock is the clearest split. Mason County runs on Pittsburgh No. 8 northern Appalachian coal under a 10-year contract totalling 27 million tons, while Dry Fork would run on Wyoming sub-bituminous coal from the Powder River Basin.

Then there is the disclosure gap. Mason County has a capital cost, a construction timeline, and a named automation contractor at least partially on the record. Dry Fork has none of the three. What this tells you is straightforward: Mason County’s progress from land closing to groundbreaking to contractor selection over eight months shows Frontieras executing, not merely announcing, but Dry Fork remains at the framework stage where CTL momentum most often evaporates. Weight those two data points accordingly.

PRB coal’s structural backdrop and the commercial case for conversion

The Dry Fork deal does not exist in a vacuum. It sits inside a Powder River Basin production trajectory that explains why a mine operator would want a long-term mine-mouth customer in the first place.

Wyoming and Montana mines produced an estimated 228.2 million short tons in 2025, up 5.9% on the comparable 2024 period, according to US Energy Information Administration figures reported by Argus Media. That looked like recovery. The forward view does not.

Coal gasification technologies share several commercial characteristics with FASForm fractionation, including capital intensity, feedstock flexibility, and the challenge of proving unit economics at commercial scale before institutional lenders will commit.

Wood Mackenzie projects PRB coal production will fall by about 20 million short tons to 208 million short tons in 2026 as structural headwinds intensify.

That decline is the point. For Western Fuels, buying CTL-produced ULSD for its own mining, haul, and member operations creates a vertically integrated loop: coal that might otherwise face eroding power-generation demand becomes feedstock for fuel the company already buys externally. That commercial logic holds regardless of whether FASForm ultimately proves out at scale.

The risks, however, are equally structural, and CTL has a long history of stalling on them:

• Capital intensity and technology scale-up: commercial-scale FASForm remains unproven, and CTL projects typically demand multi-hundred-million-dollar commitments.
• Lifecycle emissions and carbon policy: no carbon capture arrangement has been publicly described for either Frontieras project, leaving open questions on lifecycle greenhouse gas performance.
• Oil price sensitivity: US CTL proposals over two decades have repeatedly collapsed at the financing stage when crude prices fell or climate policy tightened.

For anyone tracking Wyoming coal or domestic fuel supply, the read is twofold. The commercial rationale behind the deal is genuine, but the distance between an MOU and a producing facility is long, and that distance is where the real risk lives.

Carbon capture and utilisation has emerged as the primary mechanism through which coal-dependent regions are attempting to reconcile existing mine infrastructure with tightening lifecycle emissions standards, and the absence of any publicly described carbon arrangement for either Frontieras project is a detail investors in the space should weight carefully.

What comes next, and what to watch before Dry Fork becomes a real project

An MOU is a starting line. Knowing which milestones convert framework into funded project is the difference between informed positioning and premature conviction.

The sequence to watch runs like this:

1. Definitive agreements for Dry Fork’s four components: ground lease, feedstock supply, diesel offtake, and logistics. Until these are signed, no capital is committed.
2. Financing and capital cost disclosure for Dry Fork. No project cost, funding structure, air permits, or regulatory filings have been made public.
3. Mason County commissioning in Q1-Q2 2028, the first real-world validation of whether FASForm works at commercial scale.
4. A Dry Fork construction announcement, the point at which the Wyoming deal moves from paper to steel.

Of these, the single most important near-term signal is not the Dry Fork MOU itself. It is whether Mason County’s 2028 commissioning proceeds on schedule, because that outcome will either validate or deflate the entire FASForm commercial thesis that both projects rest on.

There is a structural overhang worth naming too. CTL projects are being pursued as regionally driven, privately financed initiatives without central federal support, which means they carry full market and policy risk without the backstop that would make institutional capital more comfortable.

The Dry Fork MOU in context: a framework worth tracking, not yet a project worth pricing

Frontieras is doing two things at once: building in West Virginia and staking a position in Wyoming. Mason County supplies the technology validation on which Dry Fork’s credibility ultimately depends, which is why the two projects should be read together rather than in isolation.

The Dry Fork agreement is a serious commercial framework with specific terms and a named counterparty. It is also several definitive agreements and an undisclosed financing package away from committed capital. Treating it as equivalent to a final investment decision would be a mistake.

That makes 2028 the year the US coal-to-liquid thesis gets its first genuine test, with consequences for PRB coal producers, regional fuel consumers, and energy investors watching the space.

Domestic fuel supply resilience has become a live policy argument for coal-to-liquid projects in a way it was not five years ago, with Hormuz-related supply shocks reframing US-produced diesel as a strategic asset rather than simply a commodity output competing on marginal cost.

This article is for informational purposes only and should not be considered financial advice. Investors should conduct their own research and consult with financial professionals before making investment decisions. Past performance does not guarantee future results. Financial projections are subject to market conditions and various risk factors, and forward-looking statements are speculative and subject to change based on market developments and company performance.