The Texas Railroad Commission counts more than 130,000 stripper wells in the state alone. Most of them have been producing for decades and most of them are not depleted in any meaningful sense. They have plenty of oil left in the formation. What kills the monthly check is almost always one of four flow restrictions, and three of them are fixable without a workover rig.
Cause 1: Plugged perforations
The casing perforations are the holes in the steel pipe that let oil from the formation enter the wellbore. Over years of production, those holes get partially or fully blocked. Scale. Mineral deposits. Asphaltene buildup. Whatever the rock and the produced fluid happen to leave behind.
How to spot it: Production drops gradually but steadily over months or years. Pump efficiency stays normal. The well still pumps off when you expect it to. You just get less oil up the tubing each time.
What it costs to fix: Acid jobs run a few thousand to tens of thousands depending on well depth. They can work but they consume chemistry and they do not address restrictions deeper in the formation. Mechanical re-perforation works but takes the well offline.
Cause 2: Formation blockage
The producing rock has tiny passageways called pore throats. Oil has to travel through them to reach the wellbore. Over time those pore throats get tighter, either from buildup or from changes in wettability as the rock and the fluid sit in chemical contact for decades. Oil gets held in place by capillary forces and effectively stops moving.
How to spot it: You’re producing fluid but a lot of it is water. Total fluid production stays steady or even increases while oil cut keeps falling. The well isn’t broken. The oil just isn’t making it to the wellbore.
What it costs to fix: Surfactant treatments target this but the chemistry has to be repurchased on a schedule. Nanobubble stimulation addresses formation blockage by reducing surface tension and shifting wettability so oil starts moving again. The fluid is gas-charged water, not a proprietary chemistry.
Cause 3: Saltwater channeling
Once a well has been producing for a while, water finds the easiest path through the formation and starts dominating it. Oil gets pushed out of the way. You end up pumping a lot of saltwater and very little oil. This is one of the most common patterns on stripper wells across the Mid-Continent.
How to spot it: Water cut over 90% on a well that used to run 60% or 70%. Pump tickets show roughly the same total fluid as a year ago, but oil barrels are way down.
What it costs to fix: Traditional approaches are water shutoff treatments and squeeze jobs, both of which are expensive and risk damaging the productive zone. Improving oil flow in the formation redistributes the dominant flow path so water gets crowded back and oil takes a bigger share.
Cause 4: Actual depletion (the rare one)
Real depletion does happen. After enough years and enough barrels, the original-oil-in-place number gets drawn down to a point where there isn’t much left within drainage of the wellbore. But on a stripper well that’s only ever produced a few thousand cumulative barrels, true depletion is the smallest of the four buckets.
How to spot it: Production decline matches the predicted decline curve from the reservoir. Pressure surveys show formation pressure dropping in line with cumulative production. Nothing else is going wrong mechanically and water cut hasn’t shifted dramatically.
What it costs to fix: Honestly, nothing. If the rock is genuinely drained within the well’s drainage radius, no stimulation method brings oil back that isn’t there. This is the case where Boost or anyone else should tell you to plug the well or convert it.
How to figure out which cause is on your well
Pull the last 24 months of pump tickets and lay out three numbers side by side: total fluid per day, oil cut, and water cut.
- Total fluid steady, oil down, water up: cause 2 or 3 (formation or channeling).
- Total fluid steadily falling, oil cut roughly the same: cause 1 (plugged perforations) or cause 4 (depletion).
- Both falling fast, water cut climbing: usually 1 plus 3 stacked. Common on older wells.
That tells you the story. From there, the question is whether to spend money on a fix and how to make sure you can measure whether it worked.
What to do next
For wells where the diagnosis is causes 1, 2, or 3, nanobubble stimulation is one of the lower-risk options because it works without a rig and the well stays online during treatment. We measure baseline flow before we start and post-treatment flow before we drive off. If your well does not respond, you have the data and you have not paid for a workover that left your well shut in for a week.
If you’re sitting on a candidate, send us the well details. We’ll tell you straight whether it’s worth treating.
Related reading: Stripper well stimulation without a rig · What is nanobubble well stimulation?