How Distributions Work
If you own a working interest in a producing well, money reaches you through a specific chain: wellhead → purchaser → operator → you. This page explains that chain, what has to happen before the first payment, why the amount changes every month, and what you receive on paper. It contains no income projections — program-specific economics belong in offering documents, not on a web page.
Why there are no dollar figures here. Distribution amounts depend on well performance, wellhead prices, deductions, and operating costs that no one can know in advance. Any monthly income figure published as marketing — including figures previously shown on this page — is an assumption dressed as a fact. Ask for the offering documents and the AFE, and model it yourself.
1. The revenue chain
| Step | What happens |
|---|
| Production | Oil is produced into lease tanks; gas flows into a gathering line. Volumes are measured — oil by tank gauge or LACT meter when a truck loads, gas by meter at the connection point. |
| Sale | A first purchaser (a crude marketer, refiner, or midstream/gas buyer) takes the production under a purchase contract. Price is usually a published benchmark adjusted by a differential for location, quality, and gravity — which is why the wellhead price is rarely the headline WTI number you see quoted. |
| Settlement | The purchaser settles for the month's volumes, typically on a lag of roughly 30–60 days after the production month, and remits to whoever is designated in the division order. |
| Netting | The operator accounts for the well: gross revenue less landowner royalty and any overriding royalty, less severance and production taxes, less lease operating expense (LOE) and the well's share of overhead. |
| Distribution | The remaining net revenue is allocated to working-interest owners in proportion to their interest and paid out — commonly monthly, by check or ACH, with a revenue statement. |
Practical note: many operators apply a minimum-payment threshold, holding small balances and releasing them once they accumulate or annually. If a well's net revenue is low, you may not receive a payment every single month even while the well is producing.
2. What a division order is
A division order is the document that tells the purchaser and operator exactly what fraction of revenue from a given well or unit is payable to each owner. It is generated after a title examination confirms ownership. You will be asked to sign one, confirm your legal name, address, and taxpayer identification number, and return it.
- It is a payment instruction, not a conveyance. Signing a properly drafted division order confirms your decimal interest; it should not alter the terms of your underlying agreement. Read it — some forms include additional language, and if the decimal does not match your expectation, raise it before signing.
- Nothing gets paid until it is executed and on file. An unreturned division order or a W-9 mismatch is one of the most common reasons a first payment is delayed, and revenue is typically held in suspense until it is resolved.
3. Why the first payment takes months
The gap between funding and the first distribution is measured in months, not weeks, and it is driven by a sequence of steps that each have to finish before the next can start:
Funding & permitting
Subscription funds, permits and regulatory approvals in hand, rig scheduled. Rig availability and weather both move this date.
Drill & complete
Drilling, logging, and the decision to complete or plug. Not every well reaches completion — a non-commercial result ends the sequence here.
Connection & first sales
Tank battery, trucking arrangement or pipeline tie-in, purchase contract executed, first volumes sold.
Title, division orders, first check
Title opinion, division orders executed, owner set up in the operator's revenue system, then the settlement lag before funds are released.
Why it commonly slips:
- Title curative. Gaps in the chain of title, unreleased old leases, missing heirs, or probate issues have to be cured before a title opinion can support payment. This is the most frequent cause of a long delay and it is largely outside the operator's control.
- Division orders. Mailing, signing, correcting decimals, and W-9 handling add time; revenue accrues in suspense until they clear.
- Takeaway. A gas connection can wait on a gathering-line tie-in or compression. Oil can wait on tank capacity or a trucking contract. A completed well with no route to market produces no revenue.
- Purchaser settlement lag. Even after everything is clean, the purchaser settles a production month on a lag — the first payment covers volumes sold weeks earlier.
Any specific timing estimate for a given program belongs in that program's documents, and it is an estimate. Treat a first-payment date as a plan, not a commitment.
4. Why the amount is different every month
- Production declines. Wells decline from their initial rate — steeply at first, then more gradually. Absent intervention, volume trends down for the life of the well. This is normal engineering, not underperformance.
- Price moves. Revenue is volume × realised price. Realised price is a benchmark less the differential, and both move.
- Operating costs vary. A routine month is not a month with a pump change, a rod job, or a saltwater-disposal spike.
- Timing artefacts. Prior-period adjustments, corrected volumes, tank-gauge timing (an oil sale falls in whichever month the truck loads), and suspended-then-released balances all shift dollars between months.
- Downtime. Weather, power outages, workovers, and shut-ins for offset operations reduce or eliminate a month's volumes.
5. What your monthly statement contains
A revenue statement (check detail) is your audit trail. Expect to see, per well or unit and per product:
- Property name and well identifier, and the production month being settled
- Gross volume sold — barrels of oil, Mcf of gas, and any NGL volumes
- Average price received per unit — compare this to the benchmark to see your differential
- Gross value, then your decimal interest applied to it
- Deductions itemised: severance and ad valorem taxes, gathering, compression, processing, transportation, marketing
- Lease operating expense and any capital or workover charges billed to your interest
- Net amount payable, plus any prior-period adjustments
Keep them. Statements are what let you check the operator's arithmetic, reconcile to your K-1, and support depletion at tax time. If a line item is unclear, ask the operator for the joint interest billing detail behind it.
6. Tax reporting and the K-1
- You get a K-1, not a 1099. Program income, deductions, and credits pass through and are reported on Schedule K-1.
- Expect it late. Drilling-program K-1s are routinely issued near or after the April filing deadline, because the program itself must first close its books and receive operator statements. Plan on filing an extension. Anyone promising you a K-1 comfortably before April is promising something the industry does not reliably deliver.
- Cash received ≠ taxable income. Your K-1 reflects your share of revenue and deductions, which will not match the total of the checks you received in the calendar year.
- State filings. Income is sourced to the state where the wells are located, which can create a nonresident filing obligation there regardless of where you live.
What can reduce — or end — distributions
- Higher realised oil or gas prices, or a narrower differential
- A well performing above the operator's expectation
- Lower operating costs in a routine month
- Release of amounts previously held in suspense
- A capital call. As a working-interest owner you can be invoiced, not merely paid. Workovers, recompletions, disposal costs, equipment replacement, and plugging can be billed to your interest — and are commonly netted out of revenue first, which can take a month's distribution to zero or produce a bill.
- Permanent well failure. Casing collapse, watered-out zones, an unrepairable mechanical failure, or economics that no longer cover operating cost end the income from that well entirely. The well is then plugged and abandoned — a cost that falls on working-interest owners.
- Oil and gas price declines, or a widening differential
- Natural production decline over the life of the well
- Higher-than-expected LOE, or downtime and shut-ins
- Loss of takeaway — a purchaser, pipeline, or disposal outage
- Operator financial distress or a change of operator
Read the full risk disclosure →
Where our current wells are
Slocum Hollow Project — Cattaraugus County, New York. A conventional vertical development in the Appalachian basin of western New York. Well count, working-interest units, cost structure, timing, and all economics are set out in the project's offering documents.
Correction: an earlier version of this page described Slocum Hollow as a Pennsylvania project and published example monthly revenue figures. The project is in New York, and those figures have been removed.
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