In this guide
Why the Anadarko matters to investors
The Anadarko Basin covers roughly 50,000 square miles across western Oklahoma, the Texas Panhandle, and slivers of Kansas and Colorado. It has produced continuously for over a century — first from shallow conventional sands, then from the deep gas boom of the 1970s–80s, then from the horizontal SCOOP and STACK plays that made Oklahoma a top-five producing state. Today the SCOOP/STACK fairways alone produce on the order of half a million barrels of oil per day, roughly 4% of U.S. output, alongside a much larger gas stream — Oklahoma's gross gas production runs near 7.5 Bcf/d.
For a mineral or royalty investor, the basin's pitch is straightforward: stacked pay (multiple producing intervals under one tract mean one lease can be drilled many times over decades), a mature legal system built around forced pooling that generates transparent lease-term data, and acreage that trades at a meaningful discount to Permian equivalents. The catch is that the Anadarko is a gassier basin than its Texas rivals — its capital cycle follows natural gas as much as oil — and well results are less forgiving of geography. The 2018–2020 STACK downspacing disappointments taught everyone that "core" is a smaller circle than the lease brokers claimed.
SCOOP and STACK are fairways, not formations. STACK = Sooner Trend, Anadarko basin, Canadian and Kingfisher counties. SCOOP = South Central Oklahoma Oil Province. They describe where operators drill; the rocks themselves are the Woodford, Meramec, Osage, Sycamore, and Springer. When evaluating a deal, ask which formation and which county — not just which acronym.
Geology & structure
The Anadarko is the deepest Phanerozoic sedimentary basin in cratonic North America. It began as part of the Southern Oklahoma Aulacogen — a failed continental rift — then buckled downward during the Pennsylvanian collision that raised the Wichita and Amarillo uplifts along its southern edge. The result is a strongly asymmetric foreland-style basin: sedimentary fill reaches roughly 40,000 feet in the deep axis just north of the Wichita Mountains front, then thins gradually up the long northeastern shelf toward Kansas.
That asymmetry is the single most useful thing an investor can understand about the basin, because it creates a predictable thermal-maturity gradient. The same source rocks that sit in the oil window on the shallow shelf are cooked to condensate and then dry gas as they plunge basinward. Drill the Woodford at 9,000 feet in eastern Grady County and you get liquids-rich production; drill it at 14,000 feet a few townships southwest and you get high-pressure gas. Operators map their "oil," "condensate," and "gas" windows along this gradient, and the value of a royalty acre moves with it.
The petroleum system is anchored by the Woodford Shale, a Late Devonian–Early Mississippian organic-rich shale that both sources and produces hydrocarbons, and by the overlying Mississippian carbonate-silt section (Osage, Meramec, Sycamore) that acts as a vast, low-permeability reservoir charged from below. Above that, Pennsylvanian sands, washes, and limes — Springer, Morrow, Granite Wash, Oswego — add conventional and tight targets. Overpressure in the deep basin helps deliverability; complex faulting near the Wichita front adds drilling risk.
Producing formations & intervals
The table below summarizes the horizontal targets that matter to investors evaluating SCOOP/STACK exposure. Depths are typical drilled depths in each play's core and vary with position on the shelf-to-basin gradient.
| Formation | Age / rock type | Typical depth | Fairway | Character |
|---|---|---|---|---|
| Meramec | Mississippian silty carbonate/siltstone | ~7,500–10,000 ft | STACK (Kingfisher, Canadian, Blaine) | Primary STACK target; thick (several hundred ft), oil to condensate; downspacing-sensitive |
| Osage | Mississippian cherty carbonate | ~8,000–10,500 ft | STACK / Sooner Trend | Below Meramec; secondary target, often co-developed |
| Woodford Shale | Devonian–Mississippian organic shale | ~9,000–15,000+ ft | SCOOP, STACK, Cana | The basin's source rock and a producer in its own right; oil window updip, condensate/gas downdip |
| Sycamore | Mississippian silty lime (SCOOP's "Meramec equivalent") | ~10,000–13,000 ft | SCOOP (Grady, Garvin, Stephens) | Liquids-rich; co-developed with Woodford |
| Springer | Pennsylvanian–Mississippian shale/sand | ~11,000–14,000 ft | SCOOP | Oiliest SCOOP target; thinner fairway, strong wells in Grady/Garvin |
| Granite Wash | Pennsylvanian arkosic wash sands | ~10,000–16,000 ft | Western basin / TX Panhandle | Stacked wash intervals along the Wichita–Amarillo front; liquids-rich gas |
Two practical notes. First, the MERGE area (Canadian/Grady counties) is simply where the SCOOP and STACK fairways meet — Woodford and Mississippian targets at intermediate depths. Second, the basin still produces from dozens of conventional Pennsylvanian and older horizons (Morrow, Oswego, Cottage Grove, Hoxbar, Cleveland, Tonkawa, Hunton, Arbuckle). A royalty tract with old vertical production may carry horizontal upside — or may already be held by production at a legacy 1/8 royalty, which cuts both ways.
Activity & operators (2025–2026)
The Anadarko's operator map has been redrawn since 2020, mostly toward private and consolidated hands:
- Continental Resources — taken private by the Hamm family in 2022 — is the basin's flagship, running roughly 7–9 rigs across SCOOP/STACK and leading Oklahoma in wells drilled in 2024.
- Mewbourne Oil, the perennially disciplined private operator, matches Continental's rig count and drills some of the basin's most consistent wells.
- Mach Natural Resources (Tom Ward's income-focused MLP, IPO'd 2023) has rolled up mature Anadarko production and moderates its rig count to fund distributions.
- Camino Natural Resources and Citizen Energy, both private-equity-backed, are top-five drillers in the core Mississippian fairways.
- Devon Energy holds its legacy Cana-Woodford position; ConocoPhillips inherited Marathon Oil's SCOOP/STACK assets in the November 2024 acquisition; Ovintiv and Coterra keep smaller positions and each restarted a rig in 2025.
Activity is clearly gas-led. As Henry Hub strengthened toward $4, Oklahoma's rig count climbed from 44 to 54 during 2025 — with private operators accounting for eight of the ten additions — and analysts project modest but positive gas growth, to roughly 7.7 Bcf/d gross by end-2025. That is the basin's rhythm now: no land rush, but steady development drilling by operators who own their acreage outright and answer to distributions rather than growth targets. For royalty owners, that profile means fewer surprise permits but more durable, multi-year development of held units.
Well economics
A modern SCOOP/STACK horizontal well — typically a 1- to 2-mile lateral — costs roughly $8–13 million drilled and completed, with STACK Meramec wells at the lower end and deep, overpressured SCOOP Woodford and Springer wells at the top. Deeper targets cost more but often deliver higher-pressure, higher-rate production.
| Parameter | Typical range (core fairways) |
|---|---|
| Drilled & completed cost | $8–13 million per well |
| Lateral length | 1–2 miles (2-mile now standard) |
| Product mix | ~20–60% oil; substantial gas & NGLs everywhere |
| WTI breakeven (operator/analyst estimates) | ~$40–55/bbl equivalent in core; fringe much higher |
| First-year decline | Steep — on the order of 50–70%, typical of shale |
Historic benchmarks frame the range: Wood Mackenzie once pegged SCOOP Springer breakevens near $41 WTI and SCOOP Woodford near $47, and Continental's record Meramec wells came in under $9 million. The honest caveat is variance. The STACK's 2018–2019 downspacing program showed that infill "child" wells in over-drilled units can underperform parents badly. When you underwrite a royalty or a drilling partnership here, the county, the operator, and the spacing assumption matter more than the play-level averages. Because so much revenue is gas and NGLs, run your model with a realistic gas deck — a SCOOP condensate well at $2 gas and at $4 gas are different investments.
What it means for investors
Taxes. Oklahoma's gross production tax is 5% for a new well's first 36 months, then 7% for the life of the well (raised from the old 2% incentive rate in 2018), plus a petroleum excise levy of roughly 0.1%. It's withheld from royalty checks automatically. Notably, Oklahoma does not layer a county ad valorem property tax on producing minerals — the gross production tax stands in lieu of it — which makes the effective state take simpler and generally lower than Colorado's stacked system. Compare regimes in our state-by-state severance tax guide.
Forced pooling. Oklahoma's signature feature. If you own unleased minerals in a unit, the Oklahoma Corporation Commission can pool you by order, giving you elections — typically cash bonus plus 1/8 royalty, less cash for 3/16 or 1/5, or heads-up participation in the well. Pooling orders are public, which makes Oklahoma one of the easiest states in which to benchmark what mineral rights are actually leasing for, county by county.
The royalty market. SCOOP/STACK minerals trade actively but cheaper per acre than Permian equivalents — partly the gas weighting, partly the post-2019 credibility discount. That discount is the opportunity and the warning: core Kingfisher/Canadian (STACK) and Grady/Garvin/McClain (SCOOP) acreage under Continental, Mewbourne, or Camino development is durable cash flow; fringe acreage marketed on play-level hype is how buyers overpay. Value any offer from the actual check stubs and decline, not the acronym — our royalty calculator walks through the math, and the royalties guide covers deal mechanics.
Direct participation. The basin hosts many sponsored drilling programs, and the tax benefits are the same as anywhere. Apply the standard diligence: which formation, which county, whose type curve, and what the sponsor charges over AFE. Oklahoma's operator-friendly, low-drama regulatory climate is genuinely a plus — permits are not the binding constraint they are in Colorado — but regulation was never what killed returns in this basin; overpaying for fringe rock was.
Key studies & data sources
- USGS Anadarko Basin Province assessment (2010–2011): mean undiscovered, technically recoverable resources of roughly 495 million barrels of oil, 27.5 Tcf of gas, and 410 million barrels of NGLs, with the Woodford Shale gas assessment unit alone at ~16 Tcf and the Woodford oil unit at ~393 million barrels. Older but still the benchmark government estimate of remaining potential.
- EIA state and basin data: Oklahoma production, rig counts, and the Natural Gas Monthly for the gas stream that drives basin cash flow.
- Oklahoma Corporation Commission (OCC): permits, spacing and pooling orders, completion reports — the primary-source record for any specific tract.
- Oklahoma Tax Commission: gross production tax rules and rates.
- Operator disclosures: Devon, ConocoPhillips, Coterra, Ovintiv, and Mach investor decks give current well costs and type curves; East Daley and other midstream analysts track the basin's rig and gas trajectory.