Sell Mineral Rights in Pennsylvania

Ask five Pennsylvania royalty owners what their check actually pays them, and most will point to the gross production number, not the smaller figure that landed in their account after deductions.

Pennsylvania's Marcellus shale created one of the largest gas royalty populations in the country, concentrated in Bradford, Susquehanna, Washington, and a handful of other counties, mostly built on leases signed between 2008 and 2010 when landmen were moving fast and lease terms varied enormously from one tract to the next. Some of those leases contain royalty language that looks straightforward until post-production costs, gathering, compression, processing, transportation, get deducted before the check is cut, sometimes eating a meaningful share of gross value.

We start with the lease itself, not the statement, because the deduction language written into a 2009 Marcellus lease is what actually governs what you are owed today, and it is rarely as simple as the flat percentage most owners think they signed up for.

Post-Production Cost Deductions on a Marcellus Check

Pennsylvania case law generally allows operators to deduct reasonable, actual post-production costs from royalty unless the lease specifically prohibits it, which means the exact language in your lease's royalty clause determines how much of the gross value you actually see. Leases with a market-enhancement clause or explicit cost exclusions pay differently than leases silent on the issue. We read the royalty clause directly rather than accepting the statement's deduction line at face value, since we've seen deductions applied that go beyond what a given lease's language actually supports.

The 2008-2010 Lease Vintage Problem

Leases signed in the earliest rush, before landowner groups and better guidance from your attorney reshaped the market, often carry lower royalty rates and broader cost-deduction language than leases signed just a year or two later once the going rate became clearer. Two neighboring Bradford County tracts can carry meaningfully different economics purely based on lease vintage. We identify when your lease was signed and compare its terms against what became standard later in the play, because that context shapes what a fair valuation actually looks like.

Many early leases also included five-year primary terms with an option to extend, and some owners are now on a second or third extension of the original agreement, sometimes at renegotiated terms and sometimes still under the original 2009 language. We confirm which version of the lease currently governs before pricing your interest.

Act 13 Impact Fees vs. Royalty — Don't Confuse Them

Pennsylvania's Act 13 impact fee is a per-well fee paid by operators to counties and municipalities based on a statutory schedule, and it has nothing to do with your royalty payment. Some owners mistake impact fee disclosures they see referenced in local reporting for something that affects their personal check; it does not. Your royalty is governed entirely by your lease, separate from any impact fee the operator pays the county. We keep these two clearly separated when we walk owners through what their interest is actually worth.

We mention this because the impact fee schedule is public and easy to find online, and owners occasionally arrive at a valuation conversation with expectations built on that number rather than on their own lease's actual royalty terms. Starting from the right document avoids that confusion entirely.

County Recorder Realities in Bradford, Susquehanna, and Washington Counties

These three counties saw the heaviest Marcellus leasing volume, and with it, the heaviest volume of assignments as early leaseholders sold positions to larger operators. A lease originally signed with a small landman-driven entity has often changed hands two or three times since. We verify the current operator of record and the full assignment chain at the county recorder before quoting a value, since the entity paying your royalty today may not be who you think signed the original lease.

Owners in these counties also sometimes hold interests split across multiple wells operated by different companies, each with its own deduction practices even under the same original lease language, since assignees don't always administer post-production costs identically. We review each well's statement separately when a family's holdings span more than one operator.