Trace the world's most critical commodity through seven stages — from seismic exploration deep underground to the fuel pump at your local station.
Understanding where margins and costs sit across the chain helps explain why pump prices move and where capital is deployed.
Cost to produce one barrel at the wellhead. Varies by region, water depth, and recovery method. Middle East onshore is low; deepwater and EOR are high.
Difference between crude cost and value of refined products (e.g. 3:2:1 gasoline/diesel). Highly cyclical; drives refinery profitability.
Wholesale-to-retail margin. Retail fuel margins are thin; many stations rely on convenience and non-fuel revenue.
Typical capital intensity by stage:
| Stage | Typical capital investment |
|---|---|
| Exploration | $100M–$200M per deepwater well; $5–30M onshore |
| Production | $1B–$10B+ per major field (platforms, wells, EOR) |
| Refining | $5B–$10B+ for a new complex refinery |
| Transportation | $1–5M per mile (pipeline); $50–120M per tanker |
| Storage | $50K–500K bbl tanks; SPR-scale in billions |
| Marketing & retail | Terminals and network; $1–3M per station build |
Scroll through each stage to learn how oil moves from reservoir to retail. You can also click any stage above for detailed facts and charts.
Exploration is the first and riskiest stage: finding underground oil using seismic surveys (reflected sound waves build 3D subsurface maps), gravity and magnetic surveys, and exploratory drilling. It is extraordinarily capital-intensive — a single deepwater well can cost $100M–$200M, with no guarantee of a commercial find. The global exploration success rate is only about 10–30%, so most wells are dry. When a discovery is made, appraisal drilling follows to size the reservoir and plan development.
Primary recovery uses natural reservoir pressure and pumps to bring oil to the surface; typically only 5–15% of oil in place is recovered. Secondary recovery injects water or gas to maintain pressure and sweep more oil, often raising recovery to 25–40%. Tertiary (enhanced) recovery (EOR) uses steam, CO₂, or chemicals to mobilize stubborn oil and can push recovery toward 40–60%. Typical production profiles rise to a plateau and then decline over decades; offshore and unconventional wells often have steeper decline curves.
Refineries convert crude into products via distillation (separating fractions by boiling point) and conversion processes (cracking, coking, reforming) to increase yields of gasoline, diesel, and other products. Complexity is measured by the Nelson Index; higher complexity allows processing of heavier, sour crudes. Profitability is driven by the crack spread — the difference between crude cost and product prices. For more detail on how refineries work, see Basics of Refining.
Oil moves by pipelines (safest and most efficient for long-haul; typical tariffs on the order of $1–3/bbl for major routes), tankers (up to ~3M bbl per VLCC; rates via Worldscale), rail (~700 bbl per tank car; often $5–15/bbl for long hauls), and trucks for last-mile delivery. Choice depends on distance, volume, and infrastructure; pipelines dominate steady-state bulk flows.
Commercial storage — tank farms and terminals (50K–500K bbl tanks) — provides operational buffer and enables arbitrage when the market is in contango. Strategic reserves (e.g. U.S. SPR ~714M bbl, China, Japan, India) are government-held emergency stockpiles, often in salt caverns or large tanks, to cushion supply shocks. Storage economics are tied to contango/backwardation; in contango, storing physical oil and selling forward can be profitable.
Refined products move through wholesale distributors and trading houses (e.g. Vitol, Trafigura, Glencore) that sell to retailers and industrial users. The retail distribution network includes branded stations, independents, and hypermarket sites. Activities include pricing, branding, demand planning, and managing seasonal swings; trading firms arbitrage regional price differences and optimize flows.
The final touchpoint is gas stations, fuel pumps, and convenience outlets — over 150,000 in the U.S. alone. Margins are thin (often $0.05–$0.15/gal). Pricing at the pump reflects crude cost, refining margin, distribution, and regulation (taxes can be 30–50% of the price in some countries). Many stations rely on convenience sales and ancillary services for profitability; the sector is evolving with EV charging and alternative fuels.