When someone knocks on your door or sends a letter offering to lease your mineral rights, it can feel urgent. They'll talk about bonus payments and royalties, and the paperwork might seem straightforward. But a mineral lease is a legal contract that can bind you for years, and the terms are negotiable.

Here's what to look at before you sign.

Royalty Rate

The royalty rate is the percentage of production revenue you receive. The traditional standard was 1/8 (12.5%), but in many areas 3/16 (18.75%) or 1/5 (20%) has become more common. Rates should typically fall between 12.5% and 25%, with the exact number depending on your region, the level of competition for acreage, and your negotiation.

The royalty rate is negotiable. Don't assume the first offer is the best they'll do. There is typically a tradeoff between the royalty rate and the bonus payment: a higher royalty usually means a lower bonus, and vice versa.

Bonus Payment

The bonus is an upfront, per-acre payment for signing the lease. It varies widely depending on the area and drilling activity. Typical bonus payments range from $100 to $500 per mineral acre in less active areas, but in the core of major plays like the Permian Basin, bonuses can reach $5,000 per acre or more. Bonus payments are taxable as ordinary income.

Lease Term (Primary Term)

This is how long the lease lasts before it expires if no well is drilled. Common primary terms are three to five years. Shorter is generally better for the mineral owner because it gives the land back sooner if the company doesn't drill. Some operators push for five-year terms; negotiating down to three years is often possible.

Habendum Clause ("And So Long Thereafter")

Most leases contain a habendum clause with two parts: the primary term (a fixed period) and a secondary term that continues "as long thereafter as oil or gas is produced" from the leased land. This means if a producing well is drilled within the primary term, the lease can last indefinitely, so long as production continues in paying quantities.

Understand that once production starts, you may be locked into the lease terms for the life of the well.

Post-Production Cost Deductions

This is one of the most important clauses in any lease. Some leases allow the operator to deduct gathering, transportation, processing, and marketing costs from your royalty. Others are "cost-free" or "free of deductions" at the wellhead.

The difference can be dramatic. In one documented example, post-production deductions consumed 88% of the gross natural gas royalty. A cost-free lease would have paid the full gross amount. Read this clause carefully and negotiate it if you can. For more detail, review your lease language carefully.

Pooling and Unitization

Most leases give the operator the right to pool your acreage with adjacent tracts into a drilling unit. Understand whether the pooling clause requires your consent or if the operator can pool unilaterally. Also check whether pooling changes your royalty calculation. For a deeper explanation, see our post on pooling and unitization.

Pugh Clause

A Pugh clause protects you from having your entire leased acreage held by production from a single well. Without one, the operator can hold all your acreage indefinitely even if they only drilled on a small portion. A horizontal Pugh clause releases non-pooled surface acreage; a vertical Pugh clause releases deeper formations. Including a Pugh clause is widely recommended for mineral owners.

Surface Use

If you also own the surface, the lease should specify what the operator can and cannot do on your land. Look for provisions about road construction, well pad placement, water usage, and surface damage payments. Even if you don't own the surface, understand what activity may occur on or near the property.

Assignment

Most leases allow the operator to assign the lease to another company. This is normal in the industry, but it means you could end up dealing with an operator you didn't choose. Some mineral owners add a clause requiring notice of assignment.

Shut-In Royalty

If a well is drilled but not producing (shut in), the lease may include a provision allowing the operator to keep the lease active by paying a small annual shut-in royalty. This payment serves as "constructive production" and prevents the lease from expiring. Check the amount and whether there's a time limit: well-drafted leases cap shut-in periods at three to five years before the lease expires.

Depth Clause

Without a depth clause, the operator holds the rights to all depths below your land. A depth clause releases the deeper formations you haven't leased, allowing you to lease those separately if another company wants to drill at a different depth. This is particularly important in areas with multiple producing formations at different depths.

Get Help

If the bonus offer is significant or if the lease involves a large acreage position, it's worth paying a mineral rights attorney to review the lease before you sign. A thorough lease negotiation checklist covers dozens of clauses beyond the ones listed here. A few hundred dollars in legal fees can save you thousands over the life of the lease. At minimum, don't sign the first draft without reading every clause and understanding what it means.

Once you sign, record the lease in MinRight with the key terms: royalty rate, primary term, expiration date, bonus amount, and any deduction provisions. Understanding the difference between paid-up and delay rental leases helps you track what payments to expect. And pay close attention to the pooling clause, since it affects how your interest is calculated if the property is included in a drilling unit.