Forced pooling is routine in Oklahoma, and for SCOOP and STACK interests, the Corporation Commission's order is often more important to the file than the original lease.
The STACK play in Kingfisher, Blaine, and Canadian counties and the SCOOP play in Grady, Stephens, and McClain counties both stack multiple productive intervals, including the Woodford, Meramec, Osage, and other zones, under horizontal development that intensified after 2013. Oklahoma's forced pooling process through the Corporation Commission is used more routinely here than in many other states, which means a meaningful share of SCOOP and STACK interests are governed by a Commission spacing and pooling order rather than, or in addition to, a privately negotiated lease.
When an owner has not voluntarily leased ahead of drilling, Oklahoma's forced pooling statute allows an operator to pool that interest into the spacing unit under a Commission order that sets bonus and royalty terms, often giving the owner options for how to participate. Where an interest was established this way, the pooling order itself, obtainable from the Corporation Commission's public docket, should be the primary documentation source rather than a lease that may not exist.
Many STACK and SCOOP units have wells targeting both the Woodford shale and the overlying Meramec interval, sometimes drilled in separate phases years apart, similar in structure to the layered development seen in the Permian's Delaware and Midland basins. Each zone typically carries its own division order, so a file should list production by well and target formation rather than a single combined figure.
Because much of the SCOOP and STACK activity is relatively recent, the documentation challenge here is usually less about missing old records and more about keeping pace with frequent unit amendments and new wells added to existing units. Checking the Corporation Commission's current docket for a specific unit before finalizing a file avoids working from an outdated unit boundary.
The basin can frame formations, product windows, decline shapes, well designs, spacing, takeaway, basis, deductions, operator behavior, and development pace. The subject remains the specific property schedule, lease, unit, wells, owner decimal, burdens, and effective date.
Producing wells, behind-pipe intervals, permits, offsets, undeveloped benches, recompletions, and broad operator inventory in the basin carry different levels of support. Each layer receives its own source date, timing assumption, production shape, burden, price case, probability, and discount.
Resolve these questions so the appraisal conclusion can be traced to a defined interest, date, method, and evidence set.
It means the Oklahoma Corporation Commission issued an order pooling a non-leased interest into a spacing unit and setting the terms, often with owner election options, rather than the interest being governed by a privately negotiated lease.
The Oklahoma Corporation Commission maintains a public docket of spacing and pooling orders searchable by section, township, and range.
Operators frequently target both intervals from the same unit, sometimes with wells drilled in separate phases, and each zone typically carries its own division order even when reported on the same statement.
More frequently than in older, more settled basins, since much of this development has occurred since 2013; checking the Corporation Commission's current docket for a specific unit helps confirm the boundary is current.
Carry the same effective date, interest definition, evidence hierarchy, and limitations into these related appraisal procedures.
Barnett Shale wells are aging out of their peak decade. See how older division orders and legacy urban leases factor into a documentation-based valuation.
