An operator's investor deck loves a map. Pins scattered across five or six counties, a legend of prospect names, a headline acreage number. It reads like diversification. But acreage isn't production, and production isn't evenly spread. When you're underwriting a company — or deciding whether to farm in, buy a package, or short the story — the question that matters is simple: where do this operator's barrels actually come from?
The map won't tell you. The record will.
The question a real analyst asks
"This operator reports around 400 wells across Reeves, Loving, Ward, Winkler, and Culberson. What's the current daily oil and gas out of each county, and how many wells is it coming from?"
That's a production summary rolled up by operator and split by county — exactly the kind of slice the Wellsite data lake is built to return. Instead of pulling monthly state reports for hundreds of wells and stitching them into a spreadsheet, you ask the question in plain language and get the breakdown back: barrels of oil per day, mcf of gas per day, active well count, and average per-well rate for each county.
More often than not, the answer looks nothing like the map.
What concentration actually looks like
A typical result: one county holds 55% of the wells but 75% of the daily oil. Another county has 60 wells contributing single-digit barrels each — old verticals, marginal producers, or acreage the operator drilled to hold and then walked away from. The "diversified" footprint is really one core county doing the heavy lifting, propped up by a long tail of low-rate wellbores that inflate the well count without moving the production needle.
That distinction changes how you read everything else the operator says. If 75% of the oil rides on one county, then:
- The company's future is a bet on that county's inventory, not on the whole footprint. The outlying acreage is optionality at best.
- Per-well averages are misleading if you blend them. A company-wide "average well makes X barrels a day" number buries the fact that the good county's wells are two or three times better than the marginal ones dragging the mean down.
- Decline exposure is concentrated too. If the core county is stacked with recent completions still on steep early decline, the corporate curve is going to roll harder than a flat well count implies.
Benchmark the core county against itself
Once you know which county carries the book, the next move is to benchmark the operator's wells there against the county average and against offset operators. The record supports this directly: pull the county's average per-well production, then compare the operator's wells drilled in the same vintage.
An operator with 75% of its oil in one county and above-average wells there is a genuinely strong position — they're concentrated in the right rock and they're outperforming the neighbors. An operator equally concentrated but sitting below the county average is a different story: they've bet the company on a single county and they're the worst driller in it. Same map, opposite conclusions. You only see it when you break the production apart and stack it against the field.
Watch the trend, not just the snapshot
A single-month snapshot tells you where the barrels are today. The trend tells you where the operator is heading. Ask for the county-level production over the last 24 to 36 months and you'll see which counties are ramping and which are quietly rolling over.
Sometimes the core county is flat or declining while a smaller county is climbing — a sign the operator is migrating its capital to newer acreage and the reported "core" is yesterday's story. Sometimes every county but one is in decline, and that one county's growth is the only thing keeping corporate production from falling. Either way, the direction of the barrels is the leading indicator of where the drilling budget is actually going, regardless of what the strategy slide claims.
Why this beats the deck
Corporate presentations aggregate. They give you one production number, one type curve, one story. Aggregation hides concentration risk, hides the marginal-well tail, and hides which county is really the franchise. Breaking the record down by county and operator — and then benchmarking each piece against its peers — turns a tidy map into an honest picture of where the value sits and where the exposure is.
The footprint is the easy part to show. The barrels are the part worth checking.
The takeaway
Before you take an operator's diversification at face value, roll their production up by county and ask three things: where do the barrels come from today, how do those wells stack against the county and the offsets, and which direction is each county trending? The answers usually collapse a five-county story down to one or two counties that matter — and that's the story you're actually underwriting.