A Production Sharing Contract (PSC) is a contractual framework between a host government (or its national oil company) and an international oil company (IOC) for the exploration and development of petroleum resources. Under a PSC, the government retains legal ownership of the hydrocarbons in the ground, while the contractor bears all financial risk of exploration and development. If successful, the contractor recovers its costs from a defined share of production (cost oil) and receives a portion of the remaining production (profit oil) as compensation. The PSC model was pioneered by Indonesia in 1966 and has since been adopted by over 40 countries, governing roughly 30% of the world's petroleum production.
How It Works
A PSC divides production revenue through a structured waterfall of deductions and splits:
- Cost Oil (Cost Recovery) — The contractor recovers exploration, development, and operating costs from a percentage of total production. A cost recovery limit (or ceiling) is typically set at 40% to 80% of total production. Unrecovered costs carry forward to future periods. For example, if total production is worth $100 million and the cost recovery limit is 60%, the contractor can recover up to $60 million of costs from production in that period.
- Profit Oil — The remaining production after cost recovery is split between the government and contractor according to the contract terms. Common splits range from 60/40 to 85/15 in favor of the government. Some PSCs use a sliding scale tied to production rate or cumulative production, with the government's share increasing as the project becomes more profitable. A typical split might be 70/30 (government/contractor) at production below 50,000 BOPD and 80/20 above that threshold.
- Government Take Components — In addition to profit oil, the government may levy corporate income tax on the contractor's share, require signature bonuses ($5 to $500 million depending on the prospectivity of the block), impose domestic market obligations (requiring the contractor to sell a portion of production at below-market prices to the local market), and mandate government participation (the national oil company takes a working interest, sometimes carried through exploration).
- Total Government Take — When all fiscal elements are combined, government take in PSC regimes typically ranges from 55% to 85% of total project value, compared to 40% to 65% in royalty/tax systems.
Countries using PSC or PSC-variant systems include: Indonesia (the original and archetypal PSC), Angola, Nigeria, Egypt, Libya, Kazakhstan, Azerbaijan, Brazil (modified PSC since the 2010 pre-salt law), and Timor-Leste. Each country's PSC has unique terms, making country-specific fiscal modeling essential.
Why It Matters
The PSC structure fundamentally changes project economics compared to a concessionary system. Because cost recovery limits can delay the contractor's return of capital, and because the government's profit oil share increases with success, PSC projects tend to have lower contractor IRR but more predictable government revenue. For IOCs evaluating entry into PSC countries, the detailed terms of the contract — cost recovery ceiling, profit oil split schedule, tax rate, and ring-fencing rules — determine whether the project meets corporate return thresholds. A 5-percentage-point difference in the profit oil split on a $1 billion development project represents $50 million in contractor value over the project life.
How Netora Handles PSC Economics
Netora Upstream Platform models Production Sharing Contracts with full cost recovery waterfall calculations, profit oil splits (fixed or sliding scale), government participation, and applicable income taxes. The platform supports PSC variants for multiple countries, enabling accurate comparison of the same geological opportunity under different fiscal frameworks. Economic outputs include contractor NPV, IRR, and payout after accounting for all PSC mechanisms. Learn more about Netora Upstream Platform.