By Timothy Porritt — May 16, 2026
There are policy shifts that arrive with a press conference and there are policy shifts that arrive as a Federal Register notice on a Tuesday in late October. The first kind reprices headlines. The second kind reprices balance sheets.
What the Department of Energy issued on October 28, 2025 belongs to the second category. The interim final rule amending 10 CFR Part 609 — the rule that governs the Title XVII Loan Guarantee Program — did exactly one thing that matters more than every other thing in it combined: it broadened the statutory definition of “energy infrastructure” to include, in plain text, the word refining.
For a decade, the Title XVII universe had been adjacent to refining. It financed transmission, generation, fossil-fuel infrastructure in narrow circumstances, and — once the Energy Infrastructure Reinvestment provision of Section 1706 was added in 2022 — projects that retooled retired or underutilized energy facilities provided they reduced greenhouse-gas emissions. Refining itself was outside the door. The “EIR” frame asked applicants to avoid, reduce, utilize, or sequester air pollutants or anthropogenic emissions as an eligibility gate. A new-build distillation tower could not pass that gate.
Under the One Big Beautiful Bill Act, signed July 4, 2025, that gate was removed. Section 1706 was rebranded the Energy Dominance Financing Program. The emissions-reduction eligibility criterion was struck. The authorization ceiling was lifted to $250 billion in new loan guarantees, riding a $1 billion appropriation for credit subsidy, both available through September 30, 2028. And the interim final rule then operationalized the rebrand by writing the new scope into the definitions section of 10 CFR 609 itself: “Energy Infrastructure” now means a facility, and associated equipment, used for identification, leasing, development, production, processing, transportation, transmission, refining, and generation of energy and critical minerals.
That is the statutory frame for the largest dollar pool of federal energy lending in U.S. history, now explicitly open to refining capacity for the first time since the program’s 2005 creation.
Three numbers everyone in mid-downstream should memorize
Before getting to the consequences, the three numbers that pin the new regime to the calendar:
- $1 billion. OBBBA-appropriated credit subsidy for Section 1706 activities. The credit subsidy is the leverage layer — it is what allows DOE to put guarantees on a face-value pool an order of magnitude larger than the cash on hand.
- $250 billion. New authorized guarantee ceiling for the Energy Dominance program. For context, the Loan Programs Office had authorized roughly $48 billion cumulatively across all of its sub-programs as of mid-2024.
- September 30, 2028. Authorization cliff. Anything that has not closed or is not in a credible execution pipeline by that date converts back to a political negotiation. The first cohort of operators to organize feasibility studies, NEPA reviews, and Pre-Application Consultations against that clock will be the cohort that wins the program’s first major awards.
Why “refining” is the operative word
The substantive change is not aesthetic. The pre-OBBBA program structure was designed around energy transition — projects that decarbonized, electrified, or sequestered. Refining capacity does none of those things on its own. The pre-OBBBA program could finance, say, a renewable diesel retrofit of an existing hydrotreater, because that fit the avoided-emissions test. It could not finance a new modular crude distillation skid in West Texas designed to clear local light-sweet barrels into the USGC distillate stream, no matter how compelling the energy-security argument.
After the rule change, both projects are eligible. The shift is from “is this project decarbonizing?” to “is this project producing, processing, transporting, refining, or generating energy or critical minerals on U.S. soil?” That second test is approximately the test that the upstream and midstream halves of the U.S. energy industry already pass by default. Mid-downstream now sits inside the same statutory tent.
This is the policy match for a market that was already pulling hard on incremental U.S. refining capacity. The USGC 3-2-1 crack spread has run at roughly $41.75/bbl April month-to-date, up 95% year-over-year, with ULSD margins above $60/bbl. WTI traded into the $103–$106 band this week on continued geopolitical pressure around the Strait of Hormuz. Distillate inventories are short of the five-year band heading into the Memorial Day demand step-up. The economics are loud; the policy was the missing piece.
What this actually does to a project feasibility model
The Energy Dominance Financing Program is a loan guarantee program — DOE does not lend the cash; commercial or institutional lenders do, with DOE standing behind a portion of the obligation. The mechanical effect on a project model is not a free dollar. It is two adjustments that, taken together, usually move a marginal modular refinery project from “no” to “yes”:
- Cost-of-debt compression. Guaranteed senior debt prices closer to the federal cost of funds than to a project-finance lender’s risk-adjusted rate. On a typical modular refinery cap stack, the all-in cost of debt drops 250–400 basis points. On a 25-year amortization that is a serious NPV move — typically larger than the project’s own equity tranche.
- Senior-debt advance-rate expansion. A guaranteed-tranche structure routinely supports advance rates north of 75% of total project cost, against the 50–65% that conventional project-finance lenders will write for a first-of-class refining asset. The equity slice shrinks. The equity IRR rises.
The combined effect is the difference between a modular refinery thesis that needs strategic equity to close and one that can be closed with a mainstream project-finance syndicate plus a sponsor equity tranche in the 15–25% range. For operators sitting on permitted brownfield positions or shovel-ready greenfield sites, the change in the cost-of-capital stack is not theoretical — it is what makes the next ten years’ worth of US distillate capacity additions financeable.
The dual-use angle: energy security is now an explicit selection criterion
The other half of the rule change matters less to the spreadsheet and more to the application narrative. The Energy Dominance program added two specific selection criteria that did not exist under the EIR frame: projects that “increase capacity or output” and projects that “support or enable the provision of known or forecastable electric supply at time intervals necessary to maintain or enhance grid reliability or other system adequacy needs.”
Read that the way DOE program staff will read it. “Increase capacity or output” is a U.S.-soil energy-security test. “Maintain or enhance grid reliability” is a national-security test. Together they tilt the program toward exactly the kind of projects — distillate-first modular refineries, critical-minerals refining, midstream resilience builds — that the strategic-stockpile and dual-use sides of the federal government have been asking the energy industry for since the Strait of Hormuz environment hardened in early 2025.
That tilt has consequences for project sponsors. The strongest applications under the new program are not the ones with the cleanest emissions math. They are the ones that can write a credible, defensible energy-security narrative on top of a financeable refining or critical-minerals project. The sponsor that can describe, in plain English, which barrels of which slate the project clears into which terminal in which time horizon under which Hormuz scenario will out-compete the sponsor who can only describe IRR.
Three things mid-downstream operators should be doing this quarter
For operators staring at a modular-refinery or refining-adjacent thesis, the operational checklist for Q2 and Q3 is short and aggressive.
- Schedule a Pre-Application Consultation with the Office of Energy Dominance Financing now, not after the feasibility study is complete. The Pre-App is non-binding, low-cost, and is the single best filter on whether your project’s selection narrative will survive intake. The cohort that uses Pre-Apps as project-development tooling — not as application formalities — will compress 9–12 months out of the eventual loan-closing timeline.
- Rebuild your feasibility model around the new debt assumption. A pre-OBBBA model that assumed commercial project-finance terms is now wrong on cost-of-capital, advance rate, tenor, and covenant package. The NPV difference between the two assumption stacks routinely flips project sign.
- Write your energy-security narrative before you write your engineering narrative. The selection committee is now reading energy security first and engineering second. Lead with which barrels, which slate, which terminal, which Hormuz scenario, which time horizon. The engineering case follows.
The 2028 cliff and the strategic implication
The September 30, 2028 sunset is the program’s most important feature. It is what forces operators off the sidelines and onto the page. A federal program with three years of run-time, $251 billion of effective leverage, and a statutory definition that for the first time explicitly includes refining is a transient market — by design. Operators that move now will close into the program. Operators that wait will close into whatever the program’s successor is — and federal energy lending programs are not naturally pro-refining when the political wind shifts.
For U.S. mid-downstream as a sector, this is the most refinery-friendly federal policy shift since the Strategic Petroleum Reserve’s expansion authorizations of the late 2010s. It is being underplayed in trade press because the rule change arrived dressed as a rebrand of an existing program rather than as a new program in its own right. That mismatch — large structural change, small political signal — is precisely the kind of window that closes when the second cohort of operators notices it.
The first cohort is already in the room.
About Porritt Inc.
Porritt Inc. is a Salt Lake City–based engineering and project-development firm focused on modular refining capacity, AI-native industrial-controls software, and PSM-compliance tooling for U.S. mid-downstream. Our Project Genesis Phase A — a 25,000 BPD distillate-first modular refinery on a permitted brownfield position — is in active Pre-Application development under the Energy Dominance Financing Program.
If you are an operator weighing an EDFP application and want a working-session review of your Pre-App narrative or feasibility model, reach out at hello@porrittinc.com.
If you are an institutional investor looking at the EDFP-financeable mid-downstream cohort, request a Project Genesis investor briefing at the same address.