A permit means intent. A spud means steel in the ground. But neither means barrels. The gap between the two — a well that's been drilled but hasn't reported a drop of production — is the DUC, the drilled-but-uncompleted well. For an investor sizing up an operator, the DUC count is one of the most useful leading indicators there is: it's near-term production potential that doesn't require a rig, a new permit, or a single additional foot of hole.
So the real question isn't abstract. It's: how many wells has this operator drilled in this county that aren't producing yet, and how long have they been sitting? That's a question you can put straight to the record.
What a DUC looks like in the data
There's no field in any dataset labeled "DUC." You infer it from the intersection of three things the Wellsite data lake already tracks end to end:
- A permit on file for the location.
- A wellbore that exists — the well was drilled, so there's a bore in the record with an API number.
- No production history — the well has never reported oil or gas, or reports zero across every month since it appeared.
When those line up — permitted, drilled, silent — you've got a candidate. The record carries the full arc from first permit to last production for every well, so the absence of a production stream on a wellbore that otherwise exists is a signal, not a gap in coverage.
Asked conversationally, it's a single question: "List this operator's wells in Reeves County that have a wellbore but no reported production, and show the permit date for each." What comes back is a working DUC list.
Separating a real DUC from a reporting lag
The trap here is the well that's producing but hasn't shown up yet. State reporting runs on a lag — first oil can flow weeks before the volumes post to the public record. If you count every silent wellbore as a DUC, you'll overstate the backlog with wells that are already online.
This is where the permit-to-first-oil timing matters. Across the record, you can see how long a given operator typically takes to convert a permit into producing barrels in a given area — often somewhere in the range of a few months to a year, depending on the play and the operator's cadence. Use that as your yardstick:
- A silent wellbore younger than the operator's typical conversion window is probably just early — a well in progress, not a stranded one.
- A silent wellbore well past that window is a genuine DUC: drilled, and deliberately or otherwise left uncompleted.
So the sharper question is: "Of those non-producing wellbores, which ones are older than this operator's median time from permit to first production?" Now you're looking at real backlog, aged and ranked.
Why the age of the backlog tells a story
A fresh DUC and a two-year-old DUC mean very different things. A cluster of recently drilled, uncompleted wells usually reads as a deliberate inventory strategy — the operator is drilling ahead of completion crews, banking wells to smooth production or wait on service pricing. That's a healthy backlog, and it's a strong signal of near-term production growth once those wells get fracked.
A DUC that's sat for years is a different animal. It can flag a capital-constrained operator, a title or takeaway problem, or a well that came up short of expectations before completion. When you're evaluating an acquisition, those old wells are either upside the seller isn't crediting — or a warning worth understanding.
Either way, the fix is to sort the DUC list by age: "Order these non-producing wells by permit date, oldest first." The shape of that list — a tight recent cluster versus a scatter of aging bores — is the story.
Turning the count into a forecast
Once you've isolated the genuine DUCs, you can put numbers to them. Benchmark the operator's recent completions in the same county — pull the average first-year production from wells they've actually brought online nearby — and apply that as a rough per-well add. Ten aged DUCs against an operator's own recent type curve gives you a defensible estimate of the production that's waiting behind the completion queue.
That's the payoff for an investor: a DUC backlog isn't just a count, it's a bounded estimate of production the operator can turn on without drilling. Pair it with a permit alert on the same acreage, and you'll know the moment those wells start converting — before the volumes hit the headline reports.
The takeaway
DUCs live in the negative space of the record — permitted and drilled, but not yet producing. Find them by crossing wellbores against a missing production stream, age them against the operator's own permit-to-first-oil cadence to strip out reporting lag, and value them against nearby completions. Done right, you've quantified a backlog the operator's own summary probably won't hand you.