Market Size, Demand & Growth

The global oil refining market was valued at roughly $1.79 trillion in 2024 and is estimated near $1.88 trillion for 2025, with analysts projecting expansion to about $2.65 trillion by 2034 at a compound annual growth rate close to 4.4% (Fortune Business Insights, 2025; Market.us, 2025). Those numbers describe the throughput value of the whole sector — they are not the addressable market for a first-time operator. A business plan that quotes the trillion-dollar figure and stops there will not survive a single lender meeting.

The structural reality matters more than the headline. No grassroots refinery has been built in the United States since 1976 (US EPA, New Source Review). US refining capacity has stayed broadly flat — about 18 million barrels per day across roughly 130 operable refineries — and was "largely unchanged" as of January 2025 (BIC Magazine / EIA, 2025). The market is consolidated at the top: Marathon Petroleum runs about 2.95 million bpd across 13 plants — roughly 16% of national capacity — and Valero Energy holds about 2.21 million bpd, near 12%. Phillips 66, ExxonMobil and PBF Energy round out the leaders.

So where does a new entrant fit? Almost always at the small, modular end. The credible path in 2026 is a modular topping or hydroskimming refinery of 5,000 to 30,000 barrels per day, built as prefabricated skids and commissioned in under 20 months. Nigeria is the clearest live proof: Dangote Refinery reached around 650,000 bpd and announced a 1.4 million bpd expansion in October 2025 (Dangote Refinery, 2025), while a cluster of modular plants — Waltersmith, Edo Refinery, NDPR, OPAC and Aradel — supply local diesel and naphtha demand. The UK runs in the opposite direction: as of December 2025 only four refineries remain operational after the closure of Grangemouth and the administration of the Lindsey site (ICLG Oil & Gas, UK 2026).

The takeaway for your plan: anchor everything to a specific configuration (topping versus conversion), a specific capacity in barrels per day, a named crude source, and a named product slate. Investors and lenders in this sector read past the market-size paragraph in seconds; they spend their time on feedstock security, the refining margin assumption, and the permit timeline.

It also helps to be clear about which demand you are serving. Refined products do not move as one undifferentiated commodity. Diesel (called automotive gas oil, or AGO, in much of the world) follows freight, agriculture and power-generation demand. Gasoline tracks light-vehicle miles. Jet fuel rides aviation recovery. Naphtha feeds petrochemical crackers. Fuel oil and bitumen serve shipping and roads. A small refinery rarely chases all of these; it picks the one or two products where local demand is short and the nearest large supplier is far away, then sizes the plant to that gap. The plans that win funding read like a logistics and demand argument first and a chemistry argument second.

Questions Founders Ask First

Before the financial model, most first-time refinery developers are circling the same handful of questions. Here are direct answers, before we go deep on each.

What is a modular refinery, and is it cheaper to build?

A modular refinery is prefabricated, assembled and tested at the factory, then shipped as skids — no field welding, everything flanged together on site. For plants under about 20,000 bpd this cuts the build to under 20 months and slashes the on-site labour bill. It is not "cheap," but a 5,000–10,000 bpd unit at roughly $15M–$50M is a different financing universe from a $3B–$6B grassroots conversion refinery.

Why hasn't a new oil refinery been built in the US since 1976?

Permitting and economics, not demand. A grassroots facility triggers New Source Review (NSR/PSD) and Title V preconstruction review; full federal approval can add five to ten years before a shovel breaks ground. Existing operators have instead expanded "inside the fence" at sites that already hold permits. For a new entrant, this is exactly why the modular route — often sited overseas or as a niche specialty plant — is the realistic strategy.

Do you actually make money refining at small scale?

You can, but margin is thin and volatile. A small topping plant earns the spread between the crude it buys and the products it sells, minus $5–$12 per barrel of operating cost. In a strong quarter that nets several dollars a barrel; in a weak one it can vanish. Profitability comes from feedstock advantage (discounted local crude), a product slate matched to local demand, and ruthless cost control — never from price alone.

What It Costs to Build

Refinery CAPEX is best understood per barrel of daily capacity, because that number scales cleanly and lets a lender sanity-check your build estimate against published norms. A simple topping plant runs roughly $12,000–$15,000 per barrel of daily capacity installed, while a more complex plant with cracking and hydrotreating units sits at $20,000–$40,000 per barrel (ProfitableVenture, refinery cost analysis). That is why a moderately sized 150,000 bpd complex refinery carries a $3B–$6B price tag — and why most entrants never go there.

Modular CAPEX by Scale

• Topping unit, 5,000–10,000 bpd: $15M–$50M (£12M–£40M) — diesel, naphtha, fuel oil cut
• Mid-size modular, 20,000–30,000 bpd: $180M–$250M (£145M–£200M), 12–18 month build
• Licensing & permitting fees: $1M–$10M depending on jurisdiction and process units
• Crude inventory & working capital: a refinery must buy feedstock before it sells product — size this to 30–60 days of throughput
• Storage tankage & loading: crude and finished-product tanks, truck/rail rack or jetty access
• Utilities & safety systems: fired heaters, flare, firewater, instrumentation, control room

Notice what dominates: process equipment and the feedstock working capital, not the marketing budget that fills a typical small-business plan. A refinery model that does not ring-fence cash to buy the first cargoes of crude is not financeable.

Two cost lines are routinely underestimated by first-time developers. The first is pre-operations and commissioning — the months of test runs, catalyst loading, staff training and regulatory sign-off between mechanical completion and steady-state production, during which the plant burns cash and earns nothing. The second is environmental and safety infrastructure: flare systems, firewater, secondary containment, emissions monitoring and the safety-case documentation a regulator demands. On a modular project these can add 10–20% to the headline equipment cost, and leaving them out is one of the fastest ways to lose credibility with an experienced lender. Build a contingency line of at least 10% of total project cost; refinery construction overruns are the norm, not the exception, and a plan that pretends otherwise invites scrutiny.

Funding Routes

In the US, modular and specialty refining projects are typically funded through a blend of project-finance debt, equity from energy-focused private capital, and equipment vendor financing; SBA 7(a) loans (up to $5M) only reach the very smallest specialty or re-refining operations, not a fuels refinery. In the UK, the Start Up Loans scheme (up to £25,000 at 6% fixed) is irrelevant at this scale — UK projects rely on development-finance institutions, strategic offtakers and export-credit agencies. In Nigeria and other developing markets, DFI debt (the African Development Bank and Afreximbank have both backed modular refineries) plus a crude-supply allocation is the standard structure. Whichever route you pursue, the plan must present a 5-year forecast with the crude differential, refining margin and debt-service coverage ratio modelled explicitly.

Crude Supply & Site Selection

Location is not a soft "where's nice" decision in this business; it is a margin decision. A refinery wins or loses on the gap between the crude price it pays and the product price it captures, and both ends of that gap are geographic. The best sites sit close to a discounted crude source, close to product demand, or — ideally — on the logistics path between the two.

Where Entrants Are Actually Building

• US Gulf Coast (PADD 3): the densest refining cluster, deep crude and product logistics, but Gulf Coast crack-spread margins fell more than 45% from their 2022 peak before recovering through 2025 (US EIA, Q3 2025) — a high-competition zone for a small plant
• US inland / Bakken & Rockies: stranded crude and trucking economics can favour a small topping plant serving local diesel demand
• UK & Western Europe: a shrinking refinery base (four UK plants left) — entry is realistic only as specialty, bio- or re-refining, not new fuels capacity
• Nigeria / West Africa: the most active modular-refinery market, with crude allocations and strong local diesel (AGO) demand driving Waltersmith, Edo, NDPR and Aradel
• Middle East & emerging Asia: integrated petrochemical refineries dominate, but niche modular plants serve isolated demand pockets

Your plan should name the specific crude grade (and its typical discount or premium to Brent/WTI), the offtake channel for each product, and the haul distance to market. A refinery that buys a light sweet grade and sells into a nearby distillate-short market reads completely differently to a lender than one assuming flat, benchmark pricing on both sides.

Topping vs. Hydroskimming vs. Conversion

The single most consequential design choice is plant complexity. It sets your CAPEX, your product slate, and your margin ceiling.

Most first plants are topping or hydroskimming. The template walks you through choosing a configuration and tying it to a defensible CAPEX line rather than a round-number guess.

What a Lender Wants to See in the Site Section

A strong site section does more than state an address. It quantifies the logistics chain on both sides of the plant: how crude arrives (pipeline, rail, truck or jetty), how far it travels, and what that haul costs per barrel; then the same for every product leaving the gate. It identifies the offtake market by name and distance, and shows why that market is short of the products you intend to make. It confirms utilities — power, water, gas — and grid or pipeline access, because a refinery that cannot secure reliable power or a water permit is stranded regardless of how good the crude deal looks. And it addresses host-community and environmental factors honestly, since these are where projects most often stall at the planning stage.

Where the existing v5 page and most competing guides stop at "choose a location near your market," the version a lender funds goes further: it treats the site as the central variable in the margin equation and proves the logistics economics with numbers. A 7,500 bpd plant sitting on a stranded crude source 600 kilometres from the nearest large competitor is a completely different investment proposition from one squeezed into an oversupplied coastal hub, even if the engineering is identical.

Crack Spreads & Margins

Refinery revenue is the wholesale value of your product slate — gasoline, diesel, jet fuel, naphtha, fuel oil. The margin you actually keep is the crack spread: the gap between the crude you buy and the products you sell. The industry benchmark is the 3-2-1 crack spread, which assumes three barrels of crude convert into two barrels of gasoline and one barrel of distillate (US EIA, refining margins). That spread is your gross margin per barrel before operating costs.

Gross refining margins commonly sit in the $8–$25 per barrel band, but they swing hard with crude prices and product demand. From there you subtract operating costs of roughly $5–$12 per barrel — energy, catalysts, labour, maintenance — to reach the net margin that flows through to EBITDA. At the corporate level, even the majors often run net margins in the low-to-mid single digits as a percentage of revenue. This is a high-throughput, thin-margin business, and any plan that models a fat, flat margin will be discounted immediately.

Worked Example — 10,000 bpd Modular Topping Plant

Take a 10,000 bpd modular topping refinery running 330 days a year (allowing for turnaround and downtime). That is roughly 3.3 million barrels of throughput annually. Assume a gross crack spread of $14 per barrel and operating costs of $8 per barrel, leaving a net margin of $6 per barrel:

• Annual throughput: 10,000 bpd × 330 days = 3,300,000 barrels
• Gross refining margin: 3.3M bbl × $14/bbl = $46.2M
• Operating costs: 3.3M bbl × $8/bbl = $26.4M
• Operating margin (pre-debt, pre-depreciation): ~$19.8M
• Sensitivity: a $4/bbl swing in the crack spread moves operating margin by ±$13.2M — the single biggest risk in the model

That sensitivity line is the whole point. The plan must stress-test the margin assumption — show what happens at a $6/bbl crack spread, not just the $14 base case — because lenders care far more about how the project survives a bad year than how it performs in a good one. The template includes a margin sensitivity grid built for exactly this conversation.

The Three Levers That Actually Move the Number

Once the structure is in place, refinery profitability reduces to three levers, and your plan should show explicit assumptions for each rather than burying them in a blended margin.

• Feedstock cost. Every dollar of discount you secure on your crude grade versus the benchmark drops almost straight to the bottom line. A locked supply agreement at a fixed differential is worth more to a lender than an optimistic margin assumption.
• Product yield and mix. A barrel that yields more high-value diesel and less low-value residue earns more, regardless of the headline crack spread. Configuration choice (topping versus hydroskimming versus conversion) sets this ceiling, so it must be justified, not assumed.
• Utilisation and uptime. A refinery's costs are heavily fixed, so margin per barrel improves sharply with throughput. A plant running at 90% utilisation is a very different business from the same plant at 65%. The model should ramp utilisation realistically across the first three years and reserve days for turnaround.

Beyond the core fuel sales, a well-structured plan also identifies secondary revenue: selling residue or fuel oil to industrial users, supplying naphtha to a nearby petrochemical buyer, blending and selling lubricant base stocks, or — increasingly — co-processing renewable feedstocks where regulation rewards it. These streams rarely dominate, but they smooth the volatility of the primary crack spread and give a lender a reason to believe the cash flow holds up across a cycle.

Permits & Legal Pathway

Refining is one of the most heavily regulated activities a private business can undertake. Permitting is not a checklist appendix in your plan — it is a multi-year workstream with its own budget and its own critical path. Underestimate it and the whole project schedule is fiction.

United States

• NSR / PSD preconstruction permit (EPA, via the Clean Air Act) — required before building any new or significantly modified source; grassroots federal approval can add 5–10 years
• Title V Operating Permit — established under the 1990 Clean Air Act Amendments; the public can petition the EPA to object to a specific permit
• RCRA hazardous-waste handling and disposal authorisations
• SPCC plan (Spill Prevention, Control and Countermeasure) for crude and product storage
• State and local zoning, fire-code and emergency-response approvals

United Kingdom

• Environmental Permit under the Environmental Permitting (England and Wales) Regulations 2016, issued by the Environment Agency
• COMAH 2015 (Control of Major Accident Hazards) — crude oil is a named dangerous substance, so a refinery is a top-tier COMAH establishment requiring a full safety case
• The COMAH Competent Authority — the HSE and the Environment Agency acting jointly — enforces this framework
• Planning consent (often a nationally significant infrastructure project), DSEAR explosive-atmosphere assessment, and product-quality compliance

Nigeria (and other emerging markets)

• Licence to Establish and Licence to Operate from the regulator (NMDPRA, formerly the DPR)
• A crude-oil supply allocation or domestic crude purchase agreement — the make-or-break input for any Nigerian modular refinery
• Environmental Impact Assessment approval and host-community engagement under the Petroleum Industry Act
• The government's modular-refinery policy actively encourages 5,000–30,000 bpd entrants, which is why most new African capacity is modular

Across all three jurisdictions, build the permit timeline into the funding plan: investors will not release construction capital until the critical environmental and safety permits are secured or clearly de-risked.

Mistakes That Sink Refinery Plans

Most refinery business plans we are asked to rescue fail on the same five points. None of them are about writing quality — they are about modelling the business honestly.

• Modelling a grassroots mega-refinery. Quoting a $3B–$6B complex refinery as your project when you are a first-time operator. Lenders know the realistic entrant scale is a 5,000–30,000 bpd modular plant. Match your ambition to a financeable configuration.
• Assuming a flat refining margin. Crack spreads moved more than 45% off their 2022 peak before recovering in 2025. A model with a single fixed margin and no sensitivity range signals that the founder does not understand the business.
• Underbudgeting permits and timeline. Treating Title V, NSR/PSD or COMAH as a quick formality. Permitting alone can run years and cost $1M–$10M; it belongs on the critical path, not in an appendix.
• Ignoring feedstock working capital. Forgetting that you must buy crude before you sell product. A refinery that runs out of cash to purchase its next cargo stops, regardless of how good the margin looked on paper.
• Treating offtake as automatic. Assuming products sell themselves at benchmark prices. Without wholesale rack contracts, export agreements or a captive local market, the revenue line is a hope, not a forecast.

The Avvale template flags each of these as a built-in prompt, so the version you write avoids the failure modes that get plans rejected before the financials are even read.

Refinery Terms Your Plan Should Use Correctly

Lenders and technical reviewers in refining notice when the language is wrong. Using the right vocabulary signals that the founder understands the operation, not just the spreadsheet. These are the terms that recur throughout a credible crude oil refinery business plan.

• Crack spread: the gross margin per barrel — the difference between the cost of crude and the combined wholesale value of the products refined from it. The 3-2-1 benchmark assumes three barrels of crude yield two of gasoline and one of distillate.
• Topping plant: the simplest refinery, performing only atmospheric distillation to separate crude into straight-run cuts. Low CAPEX, no upgrading, dependent on a feedstock advantage.
• Hydroskimming: a topping plant plus catalytic reforming and hydrotreating, producing on-specification fuels. Needs hydrogen and catalyst supply.
• Conversion refinery: adds cracking units (FCC, hydrocracker, coker) that break heavy residue into higher-value light products. Highest complexity, highest margin flexibility.
• Nelson complexity index: a standard measure of how much upgrading capability a refinery has relative to simple distillation. Lenders use it as shorthand for a plant's sophistication.
• Feedstock differential: the discount or premium your chosen crude grade carries against a benchmark such as Brent or WTI. A persistent discount is often the entire economic case for a small plant.
• Product slate: the mix and proportion of finished products a refinery yields from a barrel of crude — the key driver of revenue per barrel.
• Turnaround: the planned shutdown for inspection and maintenance, typically every few years, during which the plant produces nothing. Your utilisation assumption must account for it.
• Offtake agreement: a contract committing a buyer to purchase product, the document that turns a revenue forecast into a financeable cash flow.

Sample Business Plan Preview

Here's an extract from a crude oil refinery business plan written by our team, so you can see the level of operational and financial detail lenders expect:

What's in the Template

Every Avvale business plan template includes these sections, pre-structured for a crude oil refinery operation:

• Executive Summary — capacity, configuration, crude source and product slate in the first 60 seconds
• Company Overview — legal structure, site, ownership, and the technical team behind the build
• Industry Analysis — refining market data, capacity context, and the modular-entrant thesis
• Feedstock & Supply Plan — crude grade, allocation or purchase agreement, and price differential
• Configuration & Operations Plan — topping vs. hydroskimming vs. conversion, throughput, turnaround schedule
• Product & Offtake Strategy — product slate, wholesale rack or export channel, named buyers
• Permitting & Compliance Timeline — Title V, NSR/PSD, COMAH or local licences on the critical path
• Management Team — operator and engineering bios, advisory board, key hires

The optional Financial Forecast add-on (included in our $300/£250 and $1,000/£800 packages) provides a 5-year Excel model with the crack-spread assumption, crude differential, income statement, cash flow, balance sheet, debt-service coverage ratio, and a margin sensitivity grid — the figures a project-finance lender actually underwrites against.

Whether you write the plan yourself from the free template or have our team build the bespoke version, the structure is the same one experienced refining lenders expect: a tight executive summary, a feedstock argument backed by a supply agreement, a configuration justified against CAPEX per barrel, a product slate matched to a named short market, a permitting timeline on the critical path, and a financial model that survives a stressed crack spread. Get those six right and the plan does its job — it moves the conversation from whether the project is credible to how it gets funded.

Frequently Asked Questions