Two prices decide what your Anadarko Basin royalty is worth every month - the gas price and the NGL basket. Most sellers only ever hear about one of them.
If you're getting a royalty check off an Anadarko Basin well - Canadian, Blaine, Kingfisher, Dewey or Custer County, Oklahoma across the core of the STACK and SCOOP plays, or Roberts and Hemphill County on the Texas Panhandle side - your check almost never reflects a single gas price. It reflects gas plus a natural gas liquids basket: ethane, propane, butane, isobutane and natural gasoline, each stripped out at the processing plant and sold separately at its own price. That's what makes this basin different from a straight dry-gas play like the Marcellus. It's also what makes the check stub harder to read at a glance, because you're looking at multiple commodity prices moving independently, not one number going up or down together.
We've worked Anadarko division orders long enough to watch NGL prices carry a check through a stretch of weak gas prices, and we've watched the reverse happen too - strong gas prices while propane and ethane sat depressed. Anyone offering you a number without breaking out the gas and NGL components separately isn't giving you the full picture.
Your division order likely shows volumes and prices for residue gas plus each NGL component separately - sometimes lumped into one NGL line, sometimes broken out product by product depending on the operator. Continental Resources, Devon, Marathon and Camino Natural Resources have all held significant STACK and SCOOP acreage, and each prices and reports NGLs a little differently on the check stub. Ethane in particular can be uneconomical to process in a weak-price environment, and some operators will 'reject' ethane back into the gas stream rather than strip it, which changes your gas volume and your NGL volume both without you doing anything.
This is the single biggest thing the gas royalty desk explains to new Anadarko sellers: don't judge your royalty's health off the gas price alone. A month with flat gas prices but strong propane and butane pricing can still produce a solid check, and the reverse is just as true.
STACK acreage in Canadian, Kingfisher, Blaine and Dewey County and SCOOP acreage further south in Grady, McClain and Stephens County get talked about together, but they're not identical plays - different target formations (Meramec, Woodford, Osage among others), different pressure regimes, and different NGL yields depending on depth and thermal maturity. A tract deep in the STACK oil window produces a different product mix than one in a gassier, more condensate-light part of the play, and that difference shows up directly in your check.
On the Texas Panhandle side, Roberts and Hemphill County sit in the older, more established Anadarko Basin core with a long production history predating the STACK/SCOOP horizontal boom, often tied to Granite Wash or Cleveland formation wells with their own decades-long track record.
Because your gas gets processed to strip the NGLs before it ever reaches a sales point, your check stub typically carries a processing fee or percentage-of-proceeds deduction that a straight dry-gas royalty wouldn't show. That's not automatically a bad deal - stripping the liquids is usually what makes the gas economic to sell at all in this basin - but it means the deduction line on an Anadarko check needs a different read than a Barnett or Utica check stub does. The gas royalty desk wants to see whether you're on a percentage-of-proceeds contract or a fee-based processing arrangement, because they behave differently as NGL prices move.
The gas royalty desk also wants your lease's specific language on whether NGL revenue is even included in your royalty calculation at all - older Oklahoma leases sometimes define 'gas' narrowly enough to create a real question about whether liquids revenue was ever contemplated.
Valuing an Anadarko Basin interest means modeling gas price and NGL basket price as separate, sometimes offsetting variables, then layering in the specific well's decline stage and how much of its remaining production is condensate versus gas versus liquids. That's a more involved calculation than a single-commodity play, and it's why the gas royalty desk asks for six months of stubs at minimum rather than a snapshot month - one strong or weak month for propane can make a single check misleading on its own.
If you're weighing whether to sell now or keep collecting through further NGL price swings, that's ultimately a question about your own risk tolerance and cash needs, and your CPA can help you think through how a lump sum versus continued variable income fits your tax situation.
Because your royalty includes natural gas liquids - propane, butane, ethane and others - priced and sold separately from the gas itself. NGL prices can move independently of gas prices, so your check reflects both markets rather than one.
Both sit in the Anadarko Basin but target somewhat different formations and geographic areas - STACK runs through Canadian, Kingfisher, Blaine and Dewey County, SCOOP further south through Grady, McClain and Stephens County. Product mix and pressure regime differ between them, which affects your royalty makeup.
Generally yes, since the gas has to be processed to strip out the NGLs before it's marketable, and that processing typically shows up as a fee or percentage-of-proceeds deduction. Whether the amount is reasonable depends on your specific contract structure, which we review before quoting anything.
It can. Some older Oklahoma leases define covered production narrowly enough to raise a real question about whether NGL revenue was contemplated when the lease was signed. That's worth having an oil and gas attorney review on your specific lease before you sell.
We model gas price and the NGL basket as separate variables alongside the well's decline stage, using at least six months of check stubs rather than a single month, since one strong or weak month for a single NGL product can skew a snapshot valuation.
