Royalties & Contingent Income

How to Underwrite a Mineral or Oil and Gas Royalty

Underwrite a mineral or oil and gas royalty by forecasting production from existing and future wells using decline curves, multiplying by net royalty interest and a commodity price deck, and deducting taxes and post-production costs. Title quality, operator development plans and price sensitivity are the main drivers.

What makes mineral and oil and gas royalty underwriting different

A mineral or royalty interest entitles the owner to a share of production revenue from oil, gas or mined minerals without paying drilling or operating costs. What makes it distinct is that income depends on geology, operator decisions and commodity prices. Value comes from producing wells, future drilling locations and long-lived reserves. Risk comes from steep decline rates in shale wells, operators slowing development, falling commodity prices, title defects and deductions for post-production costs. Unlike a working interest, royalty owners do not control drilling, so the operator's plans are central.

Equity buyers underwrite proved developed producing reserves for downside and value undeveloped locations for upside, often using engineering reports and type curves. Lenders to mineral companies set borrowing bases on proved reserves using conservative price decks, with periodic redeterminations. Sellers are often families or estates, while buyers include funds and public mineral companies. Diligence focuses on title, net royalty acres, division orders and the operator's activity in the area. Buyers often focus on acreage within active development units where permits and rig activity show near-term drilling.

Key metrics

How to underwrite it, step by step

1. Verify title and calculate net royalty interest for each tract.
2. Collect production and revenue history by well.
3. Build decline curves and forecast production from existing wells.
4. Assess undeveloped locations and operator drilling plans.
5. Apply price decks and deductions to project net revenue.
6. Discount cash flows and stress price and production scenarios.
7. Close with title opinions and transfer division orders.

Due diligence checklist

• Title opinions and runsheets
• Leases and royalty provisions
• Division orders
• Revenue statements
• Production data by well
• Reserve reports
• Operator drilling permits and plans
• Tax records
• Lien searches
• Purchase and sale agreement

Key risks and mitigants

Typical financing and deal structure

Mineral and royalty interests are bought outright by funds and mineral companies. Lenders provide reserve-based loans with borrowing bases determined by proved reserves and price decks, redetermined periodically. Public mineral companies may use equity and notes. Some deals include contingent payments tied to drilling. Hedging is less common for royalty owners but may be used by leveraged buyers. Reserve-based facilities typically advance a percentage of the discounted value of proved reserves, with redeterminations semiannually and a cure period if the borrowing base falls below outstanding debt. Purchase agreements often hold back part of the price against title defects found after closing, and revenue in suspense with operators is reconciled at transfer so the buyer receives payments that were held pending title.

Red flags

• Title gaps or unresolved ownership disputes
• Revenue statements not matching production data
• Operator with financial distress
• Heavy reliance on undeveloped locations for value
• Large post-production deductions not reflected in model

Frequently asked questions

Related terms

Educational content, not investment, credit, legal or tax advice. Benchmarks are common practitioner rules of thumb and vary by lender, market and cycle.