In this guide
Why the PRB is different
Every few years the industry re-discovers the Powder River Basin. It happened with conventional Minnelusa oil in the 1970s–80s, with coalbed methane in the 2000s, with the first horizontal Niobrara and Turner wells in the mid-2010s, and it is happening again now as operators armed with Permian-grade drilling and completion technology work through the basin's Cretaceous stack. The prize is straightforward: the PRB has 3,000-plus feet of stacked, oil-prone Cretaceous section in its deep trough, it already accounts for more than 70% of Wyoming's crude output (2022–2024, per the Wyoming State Geological Survey), and it runs roughly 11 of Wyoming's ~15 active rigs — the busiest oil play in the state by a wide margin.
What the basin is not, yet, is a manufacturing play. Well results vary more than in the DJ or Midland basins because the industry is still learning which benches, spacings, and frac designs work where. That immaturity is the whole investment case, in both directions: acreage and minerals are priced well below DJ and Permian equivalents, and the operators drilling here — EOG, Continental, Devon, Anschutz — are exactly the kind who tend to crack a code eventually. Whether they crack it on your acreage, and when the BLM lets them, is the underwriting question.
Geology & the coal legacy
The PRB is an asymmetric Laramide foreland basin covering roughly 22,000 square miles of northeastern Wyoming and southeastern Montana, with its deep axis running along the west side near the Bighorn uplift. Oil and gas generation is dominated by two world-class Cretaceous source rocks — the Mowry shale and the Niobrara — which the USGS credits with sourcing about 1.2 billion barrels of cumulative conventional production before a single horizontal well was drilled. The modern play simply goes to the kitchen itself: landing laterals in the source rocks and in the tight sandstones (Turner, Frontier, Parkman, Sussex, Shannon) that the source rocks charged.
Two pieces of legacy context matter to investors:
- Coal. The PRB is America's coal engine — the Wyodak-Anderson seams of the Fort Union Formation supply roughly four of every ten tons of U.S. coal from enormous surface mines near Gillette. That history shapes everything from BLM land-use planning (the same field offices manage coal and oil leasing) to local politics and infrastructure. Federal coal-leasing decisions in the Buffalo BLM planning area have been litigated for a decade, and oil and gas leasing rides the same administrative rollercoaster.
- Coalbed methane. The 2000s CBM boom drilled tens of thousands of shallow gas wells into those same coals, peaked around 2009, and collapsed with gas prices — leaving orphan-well cleanup that Wyoming is still working through. For royalty owners the lesson endures: shallow-gas checks in this basin proved brutally price-sensitive, while the new oil play is a different animal on much deeper rock.
The investor translation: the PRB's geology supports a multi-bench oil play concentrated in Converse and Campbell counties (with Johnson County emerging to the north). But surface and mineral ownership is a federal-state-private checkerboard, so two otherwise identical sections can carry very different permitting timelines and royalty terms. In this basin, title and land questions come before rock questions.
Producing formations & intervals
Depths below are approximate vertical depths in the Converse–Campbell county core; the section shallows toward the basin edges.
| Formation / bench | Typical depth | Type | Notes for investors |
|---|---|---|---|
| Parkman / Teapot sandstones | 4,500–7,500 ft | Tight oil sandstone | Shallow, cheap horizontal targets on the east flank; smaller wells, quick payouts |
| Sussex / Shannon sandstones | 6,000–8,500 ft | Tight oil sandstone | Thin marine bars; highly local — great where present, absent a mile away |
| Niobrara shale | 8,000–11,000 ft | Shale / marl (oil) | The basin's most-drilled shale bench; Anschutz's primary development target |
| Turner / Frontier sandstones | 8,000–11,500 ft | Tight oil sandstone | Thin but high-deliverability; many of the basin's best wells; Turner is the Frontier's eastern equivalent |
| Mowry shale | 10,000–13,000 ft | Shale (oil/condensate) | The deep source rock itself; the basin's biggest resource question mark and its main upside case |
| Minnelusa sandstone | 6,500–9,500 ft | Conventional (oil) | Legacy vertical play on the east flank; low-decline waterflood-style cash flow |
| Fort Union / Wyodak coals | 300–2,500 ft | Coalbed methane | The 2000s CBM boom; largely plugged or orphaned today — a cautionary tale, not an investment |
The stack is real — the Wyoming State Geological Survey lists the Frontier, Niobrara, Parkman, Turner, and Mowry as the basin's five most productive reservoirs in 2024 — but unlike the Permian, no one yet develops six benches from one pad. Most units today are drilled to one or two proven zones, with the rest carried as possibility rather than bankable inventory.
Activity, operators & the federal factor
Basin activity runs at a deliberate tempo: roughly a dozen rigs, a few hundred horizontal permits a year, and a short list of operators who matter.
- EOG Resources — the largest acreage holder at roughly 400,000 net acres, with more than 1,600 identified locations across the Niobrara, Mowry, and Turner. EOG treats the PRB as a growth asset behind its premium plays, so its pace flexes with capital allocation.
- Anschutz Exploration — the private Denver company that has quietly become the basin's most active driller (~65 wells per year), focused on full-field Niobrara and Mowry development. In 2025 it drilled the basin's first three-mile laterals in Johnson County, extending the play north.
- Continental Resources — entered by buying Chesapeake's PRB position in 2022 (~$450 million) and has built to roughly 25,000 Boe/d (Q4 2025), participating in 28 gross wells during 2025.
- Devon Energy — holds ~300,000 net acres carried as longer-dated inventory behind its Delaware Basin program.
- Occidental — large legacy landholder through the Anadarko acquisition, currently harvesting rather than growing.
Now the federal factor. A very large share of PRB minerals are federal, managed by the BLM's Buffalo and Casper field offices, frequently in checkerboard with state and fee sections. That means federal drilling permits (APDs) for most units, federal lease sales for new acreage, and exposure to whichever direction national leasing policy is blowing — quarterly lease sales have swung from record offerings to near-zero within single administrations, and resource management plans in this basin attract litigation the way porch lights attract moths. New federal leases also carry the 16.67% statutory royalty set in 2022, up from the historic 12.5%. Operators manage all this with permit inventories built years ahead; investors should check how much of any given deal's acreage is fee versus federal, because it changes both timing risk and royalty mechanics.
Well economics
Representative figures for 2025–2026 horizontal development, with the caveat that PRB results are streakier than in mature basins:
- Drilling & completion cost: roughly $8–12+ million for two-mile laterals depending on target depth — Parkman wells at the cheap end, deep Mowry tests at the expensive end. Three-mile laterals, new in 2025, aim to cut per-foot costs the way they did in the Permian.
- Well results: good Niobrara and Turner two-mile wells commonly recover in the range of 600 MBoe–1 MMboe with high oil cuts (65–85%); the Turner's thin, permeable sand delivers some of the basin's biggest IPs. Mowry results are improving but less consistent — it remains the play's largest unbooked prize.
- Breakevens: better acreage is generally quoted in the $50s WTI, with much of the basin needing $60-plus — competitive with mid-tier Permian, behind core Midland. Costs in the Rockies run higher per unit than in Texas (winter operations, trucking distances, smaller service market).
- Declines: standard shale hyperbolic — roughly 60–70% in year one, flattening toward single digits by years four to six. Model the curve, not the first check; our royalty calculator does the arithmetic.
Spacing is the swing variable. The DJ Basin taught the Rockies that early wells drilled too close together cannibalize each other. PRB operators are still converging on answers — units have been developed anywhere from two to eight wells per section per bench. When you evaluate a PRB royalty or working interest, ask what spacing assumption sits under the location count. An "inventory" slide built on aggressive spacing is the most common way PRB deals disappoint.
What it means for investors
Working interest / drilling partnerships. The PRB shows up in direct participation programs less often than the Permian, and when it does the honest framing is "development-stage": offsets exist, but statistical control is thinner. Diligence the operator's own well history in the specific township — not basin-average curves — and remember the year-one IDC deduction math works the same on a $10 million Wyoming well as a Texas one.
Royalties and minerals. PRB royalties under active operators are genuine oil checks with normal shale declines. Undeveloped minerals are the deep-value end of the Rockies: prices per net royalty acre sit far below the DJ and Permian because buyers discount for federal-permitting timing and spacing uncertainty. That is the trade — cheaper entry, longer wait, wider outcome distribution. Fee minerals inside an announced development unit of EOG, Anschutz, or Continental are the cleanest way in.
Taxes. Wyoming levies a 6% severance tax on oil and gas, and county ad valorem production taxes add roughly another 6%, so the all-in production-tax burden runs about 11–12% — among the heavier takes in the Lower 48, though Wyoming has no state income tax to stack on top. The full comparison is in our severance tax guide.
Key studies & data sources
The USGS's 2006 assessment of the Powder River Basin Province estimated means of 639 million barrels of undiscovered oil, 16.6 Tcf of gas, and 131 million barrels of NGLs — a figure that predates the horizontal play and is widely viewed as conservative for the Niobrara and Mowry. The companion USGS study of the Mowry Shale and Niobrara Formation as continuous hydrocarbon systems (Anna & Cook) identified those two units as the basin's primary source rocks, credited with ~1.2 billion barrels of cumulative sourced production — the geological foundation of today's play. The Wyoming State Geological Survey's PRB summaries track reservoir-level production and confirmed the Frontier, Niobrara, Parkman, Turner, and Mowry as the top producers in 2024.
For current data, the Wyoming Oil and Gas Conservation Commission publishes permits, spacing orders, and well-level production — the primary source for verifying any interest you are offered. The EIA's Short-Term Energy Outlook and drilling-productivity data cover Rockies supply trends, and the BLM Wyoming lease-sale and APD dashboards are the place to check the federal development clock on specific townships.