Van Buren, Conway, White, Cleburne — if your royalty check names one of those counties, you're a Fayetteville Shale owner, and this is one of the states where the gas royalty desk would actually call it a real gas play, not an afterthought.
The Fayetteville Shale ran through its full boom cycle already — the heavy drilling years were roughly 2005 through 2012, and what's left today is a mature, dry-gas field with thousands of wells now well into their decline. That's not a knock on the play. Dry Fayetteville gas has been reliable production for over a decade for a lot of Arkansas families, and a lot of the original leases from the boom are still on the books paying royalty today.
What's changed is the growth story. New drilling has slowed a great deal since the play's peak, operators consolidated their acreage into fewer, larger companies over the years, and most owners today are collecting on wells that are ten, fifteen years into a long tail rather than sitting on fresh production.
Unlike a liquids-rich play where the operator's realized price gets a boost from natural gas liquids, Fayetteville production is almost entirely dry methane. That means your royalty rides gas price alone, without the NGL cushion that softens the swing for owners in a play like the Permian or Eagle Ford. When gas prices dropped hard in recent years, Fayetteville owners felt the full weight of that drop in a way liquids-rich owners didn't.
It also means the basis differential on your statement is specifically a gas basis number, tied to whatever pipeline your gas moves on out of north-central Arkansas, not a blended oil-and-gas realized price. Ask your operator which index they reference if your statement doesn't spell it out plainly — most will tell you if you call the royalty owner relations line. Keeping a few months of statements side by side is the easiest way to see how much of your check's swing comes from price versus volume decline.
A well drilled in 2008 or 2009 is now running on the flat, low tail end of its production curve. That's not a bad thing for steady income, but it does mean the growth is behind it — the decline curve has already done its steep early work, and what's left is a slow bleed that will keep paying smaller checks for years without much variation from month to month outside of price swings.
For an owner deciding whether to hold or sell, that maturity is actually useful information: we can look at fifteen years of production history on a lot of these wells rather than guessing at a type curve, which gives us a much more grounded number to offer than we could on a newer play. It also means there's less uncertainty baked into the offer, since we're not projecting an unproven decline against a well that's barely started.
South Arkansas is a different story entirely — the Smackover formation there has become a genuine lithium brine target in recent years, with companies drilling and permitting for lithium extraction rather than oil and gas. If your interest sits in south Arkansas and someone's approached you about a lithium lease, that's a separate conversation from a Fayetteville gas sale, and the two shouldn't be confused. We deal in gas royalties; a lithium brine lease is its own animal with its own valuation questions.
If you're not sure which category your interest falls into, tell us your county and we'll tell you straight whether we're the right buyer for what you've got.
Very little new drilling happens today compared to the 2005-2012 boom. Most current production comes from legacy wells now well into their decline, operated by a smaller number of consolidated companies than during the boom years.
Fayetteville production is dry gas with essentially no natural gas liquids to cushion the number, so your royalty tracks gas price movement directly without the buffer a liquids-rich well would have.
That depends entirely on your county. Fayetteville gas production is centered in Van Buren, Conway, White, and Cleburne counties in north-central Arkansas. South Arkansas Smackover lithium interest is a separate, unrelated opportunity.
Yes, and often more confidently than a newer well, since we have a long production history to work from instead of projecting a type curve on limited data.
It can. A tract held by multiple producing wellbores may show a smoother, more predictable check than a single-well interest, and we factor that into how we read the production history when putting together an offer.
