From Wellhead to Check: What Susquehanna County, Pennsylvania Royalties Actually Pay

If you own a royalty interest in Susquehanna County, you have probably had this moment. The news quotes a natural gas price, you do the arithmetic on your decimal, and the check arrives for noticeably less. Nothing has gone wrong. Between a wellbore near Dimock and your mailbox, the price is marked down twice — once by geography, once by contract. Understanding both is most of what you need in order to judge whether an offer is fair.

Pennsylvania’s largest gas county sits in the dry gas window

Susquehanna County produced roughly 1.37 trillion cubic feet of natural gas in 2025, more than any other county in Pennsylvania — ahead of Bradford at 1.17 Tcf, Washington at 1.15 Tcf and Greene at 1.14 Tcf. Statewide production exceeded 7.8 Tcf, around 16 percent of all gas produced in the United States, according to FracTracker’s analysis of Pennsylvania DEP production data.

The county sits in the dry gas window of the Marcellus, along the state’s Northern Tier. The shale here is deep and thick: it reaches on the order of 9,000 feet in northeastern Pennsylvania, and the net organic-rich interval exceeds 250 feet here against less than ten feet along the Ohio border. Depth and thermal maturity are why the gas is almost pure methane.

That matters for your check. A wet-gas owner in Doddridge County, West Virginia is paid separately for ethane, propane and butane. A Susquehanna owner has one product, which cuts both ways: no liquids drag, but nothing to cushion the stub when methane is weak.

The first markdown: Appalachian basis

Henry Hub, in Louisiana, is the benchmark quoted on the news. Your gas is not sold there. It is sold into northeastern Pennsylvania pipeline points, which trade at a discount because the region produces far more gas than it consumes while takeaway capacity out of Appalachia has been constrained for over a decade. Appalachia supplied 31 percent of US marketed gas production in 2025, into a local market that cannot absorb it.

The discount is neither small nor stable. The US Energy Information Administration reported that from April through July 2026 the Appalachia regional average hub price ran 77 cents per MMBtu below Henry Hub, the second-widest discount on record for that hub. Readings since have been wider: as of September 2026, Tennessee Zone 4 Marcellus — a main index for northeastern Pennsylvania gas — averaged about $1.46 below Henry Hub, with Eastern Gas South near $1.27 below. This is the first markdown, and it happens before anyone deducts anything — a fact about where your gas is, not about your lease.

The second markdown: post-production costs, and why Kilmer made them lawful

The second markdown is contractual. Gas leaving the wellhead must be gathered, compressed, dehydrated and moved on interstate pipe. Those are post-production costs, and whether your royalty carries a share of them depends on your lease — and, in Pennsylvania, on a 2010 decision.

In Kilmer v. Elexco Land Services, decided March 24, 2010, the Pennsylvania Supreme Court held that the state’s Guaranteed Minimum Royalty Act — which requires at least a one-eighth royalty — is satisfied when that one-eighth is calculated at the wellhead by the net-back method: one-eighth of the sale price less one-eighth of the post-production costs of bringing the gas to market. Landowners had argued the statute required one-eighth of gross proceeds. The Court disagreed, unanimously, drawing the line at recovery: costs after the gas is out of the ground may be shared, costs of getting it out may not.

So “one-eighth” in a Pennsylvania lease does not by itself tell you what you will be paid. Two neighbors in the same unit, holding the same decimal, can receive materially different amounts because one lease says “at the wellhead” and the other says “gross proceeds, free of post-production costs.” The exact wording of your lease is worth reading before you value anything.

What Act 153 entitles you to see on the stub

You do not have to guess at any of this. Act 153 of 2022 amended Pennsylvania’s Oil and Gas Lease Act, and since March 3, 2023 unconventional operators must give royalty owners well-by-well production and sales information: the gas produced and sold from each well, the price received per unit, and deductions reported in categories rather than one lump.

The Act has teeth. If you request the information by certified mail and the operator fails to respond within 60 days, you may sue to compel it and recover attorney fees and costs. It also sets default payment deadlines, unless your lease provides otherwise: within 120 days of first sale, and thereafter within 60 days of month end.

If you are weighing a sale, request the well-by-well detail first. A buyer prices off your actual net revenue; work from the same number.

Pennsylvania takes no severance tax — so the gap is commercial, not governmental

One thing is not reducing your check: a state severance tax. Pennsylvania is the largest gas-producing state in the country without one. Instead, Act 13 of 2012 created an annual impact fee on each unconventional well, set by a schedule turning on the spud year and the average annual gas price, paid by the producer.

Because it is charged per well rather than as a percentage of production, you will not see a severance line reducing your gross the way a Louisiana or New Mexico owner does. The whole gap between the headline price and your net is commercial — basis and deductions. That matters: a commercial gap is one your lease language can move. A statutory one is not.

The name on your check has changed twice

Susquehanna County is unusually concentrated in one operator. Cabot Oil & Gas built the position and became Coterra Energy in the 2021 merger with Cimarex. At year-end 2025 Coterra held roughly 186,000 net acres in the county’s dry gas window, with 1,122.6 producing net wells, over 99 percent of them operated — running just one rig and one completion crew.

Then, on May 7, 2026, Devon Energy completed an all-stock merger with Coterra. The combined company kept the Devon name and the DVN ticker, with Coterra continuing as a wholly owned Devon subsidiary.

For a royalty owner this is mostly administrative — a merger changes neither your decimal nor your lease. But the remitter name on your stub may change, and new division orders are possible. Do not sign one assuming it merely reflects the merger: read the stated interest, because a division order that misstates your decimal creates a problem you will have to unwind.

The capital contest itself is not new, since Coterra already weighed Marcellus gas against Permian oil. Devon now weighs Susquehanna dry gas against Delaware Basin oil for the same dollars, and whether the county’s rig count holds turns on that competition. For anyone with undeveloped acreage, that is the thing to watch.

How a buyer actually prices a Susquehanna royalty

Buyers do not price off the headline gas price, and neither should you. They begin with your realized net revenue — what actually landed, after basis and deductions — then ask three questions.

• Where is the well on its decline curve? Marcellus wells fall steeply for two to three years, then flatten. A 2016 well and a 2025 well earning identical income this month are not worth the same money.
• Is there undeveloped acreage, and will it be drilled? Value for locations that may never be drilled is discounted heavily, and Devon’s priorities now sit partly outside Pennsylvania.
• What does your lease say about deductions? A gross-proceeds lease is worth more per dollar of production than a net-back lease. A buyer will read yours; read it first.

The common shorthand — multiplying recent monthly net income by somewhere between 36 and 72 months — is a starting point, not an appraisal. The low end belongs to interests in steep decline with no remaining locations; the high end assumes flat production and real drilling upside. A mature Susquehanna interest usually lands nearer the middle. Any buyer quoting a multiple before reading your check detail and your lease is guessing.

It is worth saying plainly when not to sell. If your income is stable, you do not need the capital, and you hold undeveloped acreage still being drilled, holding is usually the better decision. A sale makes sense when you want certainty rather than exposure: an estate to divide among heirs who cannot agree, an interest too small to administer, or an unwillingness to carry the risk that Appalachian basis stays wide.

Leases, assignments and pooling instruments for the county are recorded with the Susquehanna County Register & Recorder at 31 Lake Avenue in Montrose, searchable online through LANDEX. If you inherited an interest and no longer have the lease, that office is where the chain of title starts.

If you want a number on your interest

We buy mineral rights and royalty interests in Susquehanna County for cash, and we price from your actual check detail and lease language rather than a headline gas price. For an offer, or a second opinion on one you have already received, start on our Susquehanna County mineral rights page or get in touch with us directly. If holding is the better answer for you, we will tell you that too. Dry-gas owners to the west face the identical net-back question, and our Bradford County mineral rights page covers it on that side of the field. If you own minerals elsewhere in Pennsylvania, see how to sell Pennsylvania mineral rights.