Production allocation and revenue distribution are two different jobs that share a month-end deadline. Allocation splits commingled volumes into per-well, per-lease, and per-owner numbers. Revenue distribution takes those allocated volumes, multiplies by the price the oil and gas sold for, and writes checks to working interest owners and royalty owners. If either step is wrong, owners are paid wrong and the backlog of correspondence and corrections eats into the next month.
This page explains how the two connect, where most mistakes happen, and what software each job requires. If you are an independent operator trying to understand why month-end takes a week when it should take a day, the answer usually lives somewhere in this handoff.
The Two Jobs, Side by Side
| Job | What it produces | Who does it | Typical software |
|---|---|---|---|
| Production allocation | Per-well, per-lease, per-owner volumes (oil, gas, water) | Production accountant or allocation specialist | FieldCap, PakEnergy Allocate, Avocet, TOW, Excel |
| Revenue distribution | Per-owner dollars, broken out by revenue type (oil, gas, NGLs), minus severance tax and deductions | Production accountant | WolfePak, PakAccounting, OGSYS, Bolo |
Allocation is a volume calculation driven by well tests and allocation factors. Revenue distribution is a dollar calculation driven by sale price, interest decks, severance tax, and deductions. The output of allocation is the input to revenue distribution. Clean handoff, or the whole month-end breaks.
How the Handoff Actually Works
A typical month on a multi-well lease with commingled production looks like this.
Daily. Pumpers gauge tanks and record run tickets. Oil volumes sold to the purchaser are logged with the sale price. Gas volumes meter to the gas purchaser separately.
End of month. The total commingled volume for the month (say, 620 barrels of oil and 8,400 Mcf of gas) is known from the purchaser statements. The volume has to be allocated back to individual wells.
Allocation step. A well test ratio or an allocation factor splits the 620 barrels into per-well numbers. For example, well A gets 248 barrels, well B gets 186, well C gets 124, and well D gets 62. The split is driven by the most recent well test or by a decline-curve-based factor.
Revenue distribution step. For each well, the per-well volume is multiplied by the average monthly sale price to get gross revenue. Severance tax is calculated per state rules. Gross revenue minus severance tax equals taxable revenue. The taxable revenue is split across the interest deck: working interest partners, royalty owners, and any overriding royalty interests.
Check writing. The revenue distribution output becomes the payment run. Each owner gets their share. Each working interest partner gets their JIB statement. The state regulator gets the per-well production report.
If any step upstream has bad data, every step downstream is wrong.
Where Mistakes Actually Happen
Across the independent operators we work with, the most common revenue-distribution failures trace back to three points.
Bad production data on day one. A gauge read was missed. A run ticket was logged to the wrong well. A downtime code was forgotten. The allocation engine has no way to recover the right numbers if the input data is wrong. We see a 6% pump-to-net improvement inside six weeks on leases that move from paper gauge sheets onto a mobile production app, because the input-data quality improves that much.
Outdated well tests. Allocation factors are usually driven by the most recent well test. If the test is six months old and the well has declined or been worked over, the allocation split is wrong. A stripper well that tested at 12 bbl/day last year but is making 6 bbl/day today will be over-allocated, and a neighboring well will be under-allocated. Royalty owners on each lease see the difference.
Interest deck drift. Division orders change. Mineral interests change hands. Overriding royalty interests get assigned. If the interest deck inside the accounting platform is not updated in real time, revenue distribution pays owners based on stale interests. Correcting the back-owed amounts is expensive and slow.
Clean production data, current well tests, and a disciplined interest-deck review process together solve 90 percent of the failures.
What Software Each Job Needs
Allocation and revenue distribution are not the same purchase. Most independent operators run three separate platforms, each doing one piece.
Production capture: GreaseBook (or Scout FDC, FieldCap, WellEz) captures the daily volumes at the wellhead. Clean input data means everything downstream runs cleaner.
Allocation: FieldCap, PakEnergy Allocate, Avocet, or TOW splits the commingled volumes. For smaller shops, a disciplined Excel workflow works. The test is whether the math is audit-ready and the well tests are current.
Revenue distribution and accounting: WolfePak, PakAccounting, OGSYS, or Bolo takes allocated volumes, runs the revenue math, and writes the JIB and royalty checks.
The handoff between the three platforms is usually a nightly or monthly file feed. Some operators run custom integrations. The important thing is that each system owns its job and the data flows reliably.
Why Operators Try to Combine Them (And Why Most Regret It)
Every year a vendor pitches a unified platform that does field capture, allocation, and accounting in one system. The pitch is appealing. In practice, the trade-offs are real.
- Vendors strong at field capture are usually weak at accounting.
- Vendors strong at accounting are usually weak at mobile field capture.
- Vendors strong at allocation are sometimes weak at both ends.
The pattern we see in mature independent shops is three purpose-built tools talking cleanly to each other, not one platform claiming to do everything. The integration complexity is real but manageable. The quality drop from forcing one platform to cover three specialties is worse.
Who This Page Is Not For
This page is not for royalty-owner personal finance research (mineral owners tracking what they are owed on a monthly check). It is not for offshore production operations with deeply different allocation architectures. It is not for enterprise shops running Quorum end-to-end.
This page is for independent operators trying to understand why month-end takes too long and where the fix lives. The answer is almost always in the handoff between allocation and revenue distribution, and it usually starts upstream with the production data quality.
Related Pages
- Pillar: oil and gas production allocation software.
- Allocation picks: best oil and gas production allocation software.
- Research documents: oil and gas production allocation software PDF.
- Accounting boundary: oil and gas accounting software.
Frequently Asked Questions
What are allocations in oil and gas?
Production allocation is the process of splitting commingled production volumes into per-well, per-lease, and per-owner numbers. The split is usually driven by periodic well tests or decline-curve-based allocation factors. The output feeds revenue distribution, JIB, state reporting, and severance tax.
What are the 3 P’s of oil and gas?
The 3 P’s are proved, probable, and possible reserves, a reserves-classification concept from reserves reporting. Not directly related to allocation or revenue distribution, though reserves estimates do flow from production history and allocation can affect per-well reserves over time.
What is production allocation?
Production allocation is the technical discipline of splitting commingled production into per-well, per-lease, and per-owner volumes. It sits between field measurement (how much was produced collectively) and revenue distribution (who gets paid what).
How to calculate the GOR?
GOR (gas-oil ratio) is the volume of gas produced divided by the volume of oil produced, usually expressed in Mcf per barrel. GOR is an operational metric for wells, not a revenue calculation. It comes from the production capture layer (the gas and oil volumes recorded by the pumper or the meter), which makes it another reason clean production data upstream matters.
Ready to Clean Up Month-End?
If your month-end is running too long and you suspect the problem lives in allocation or revenue distribution, start upstream with production data. Take the 60-second quiz and see whether cleaner field capture would fix the downstream math.
Two minutes. No sales call, no pushy follow-up.
If GreaseBook lands and the fit turns out wrong inside year one, the 200% money-back guarantee refunds you twice the contract price. That is how confident we are in the pumper-adoption bar.
P.S. This page is not for midstream operators handling gas-plant allocation and NGL revenue split. No hard feelings. If you are still deciding, the quiz gives you a straight answer in the time it takes to refill your coffee.