Most plunger-lift "optimization" attempts move one variable, watch for two days, and call it good. Real optimization works the well's 30-day envelope — pre-tuning data, baseline, change, validate against the right KPIs. This 21-point checklist is what a field engineer with a target on production efficiency runs through before, during, and after every meaningful tuning campaign on a plunger well.
Original completion details, perforation depths, last 3 workovers, current tubing depth and ID, last DHTOP / DHCAS pressure survey, last fluid level shot. Tuning a plunger without knowing the tubing ID is rounding-error work.
Plunger type and weight installed, last installation date, last bumper spring change, lubricator condition, valve and arrival sensor function. Mechanical drift is the single most common cause of "the controller is wrong" reports.
Average and standard deviation for: arrival velocity (ft/min), cycle frequency (cycles/day), afterflow duration (min), fall time (min), MCF rate, casing pressure, flowing tubing pressure, line pressure. Target: capture all 8 series at minimum hourly resolution
Foamer SKU, dose rate (gal/day or lbs/cycle), last program change date, FSR notes for last 90 days. Plunger and chemistry interact — don't tune one in isolation.
If line pressure has crept up 30+ psi over the prior 60 days, plunger arrivals were going to slow regardless. Eliminate this confounder before changing setpoints.
If three wells on the same CTB are all slowing simultaneously, the problem is downstream and tuning your one well will accomplish nothing. Diagnose by group, not by well.
Which KPI is moving the wrong direction? Arrival velocity? No-arrival count? MCF rate? "Optimize the well" without a quantified target is a way to spend a week and not know whether you helped.
For typical conventional plungers: 700–1000 ft/min. Brush plungers: 500–700. Pad / bypass plungers: 300–500. Target arrival inside this window 90% of cycles Below 300 ft/min repeatedly: plunger is fighting too much head, redesign territory
If arrivals are slow, cycle is too short — the well isn't building enough casing pressure to lift the plunger. Lengthen cycle 10% per iteration. If arrivals are fast and afterflow MCF is small, cycle is too long. Shorten cycle 10% per iteration.
End afterflow when the well's MCF curve has flattened and is starting to roll over (entering decline phase before the next cycle). Continuing afterflow beyond this point gains marginal MCF but extends fluid accumulation time. Typical afterflow: 30–90 min depending on well GLR
Plunger fall time should be 0.7–1.2 ft/min for conventional plungers in dry tubing, faster (0.5 ft/min) when wet. Anomalies usually mean tubing wear, plunger damage, or fluid accumulation in the lower joints.
A well at 950 ft/min average arrival with 8 no-arrivals/day is NOT optimized — it has a bimodal distribution and the no-arrival cycles are erasing your gains. Tune cycle frequency until no-arrival rate is below 1%, then refine on velocity.
Fastest arrivals don't mean the highest production. The relationship is non-linear and well-specific. After every change, the question is whether 14-day rolling MCF is up — that's the only KPI that pays the bill.
Wait 7–14 days between meaningful changes. Plunger lift dynamics have a long settling time and you'll chase noise if you tune daily. Document each change with a timestamp; future-you will need it.
Conventional plungers typically run 30,000–80,000 cycles. Brush plungers: 50,000–120,000. If you're tuning a plunger that's been in the hole 18 months on a well doing 50 cycles/day, the answer may be "swap it before tuning anything."
If fall time has increased 25% over baseline without a chemistry change or reservoir change, the plunger or tubing has worn enough to leak past. Trigger: schedule plunger pull for inspection
If afterflow is producing >65% of the cycle's total MCF, the plunger is working but the cycle is too short. If afterflow is producing <15%, cycle is too long or well is over-producing during build-up phase. Sweet spot is roughly 30–50%.
If the well is consistently below Coleman critical velocity at current rate (see Liquid Loading Early Warnings for the formula, or use the free Turner/Coleman/Lea calculator), no plunger tuning is going to fix it — the well needs a velocity string or smaller tubing.
High water cut + dry plunger = no-arrivals. High water cut + brush plunger = healthy arrivals + extended life. Low fluid load + brush plunger = unnecessary friction and slower velocities. Re-evaluate plunger type whenever the FSR shows water-cut step change
If three full tuning iterations across 30 days haven't pulled KPIs back into target range, you're not tuning anymore — you're masking. Redesign is plunger swap, velocity string, gas-assisted plunger, or transition off plunger. The matrix below decides which.
A single sentence in the well file: "What I changed, when, why, and what KPI moved." Plunger lift expertise lives in the well file or it doesn't exist. The next engineer or the next pumper has to be able to pick up where you left off.
When the 21-point checklist has been worked and KPIs still won't budge, this is what the symptom set is telling you.
| Symptom set | Likely cause | Action |
|---|---|---|
| Slow arrivals, no-arrivals <5%, fall time normal | Cycle / chemistry mistune | TUNE |
| Fall time inflated >25% baseline, arrivals slow | Plunger or tubing wear | REDESIGN — pull plunger |
| No-arrivals >5% even after cycle increase | Insufficient pressure build / fluid load too high | REDESIGN — heavier plunger or velocity string |
| Three or more wells on same CTB with similar pattern | Gathering-side issue (line pressure, compressor) | ESCALATE — gathering, not artificial lift |
| MCF below Coleman critical velocity even with healthy arrivals | Tubing too large for current rate | REDESIGN — velocity string |
| Wide bimodal arrival velocity distribution | Fluid slugging / inconsistent build-up | TUNE — chemistry first, then cycle |
| Increasing soap stick consumption with no MCF lift | Foamer mismatch with current fluid composition | TUNE — chemistry SKU change |
| Plunger lift well producing below own baseline at lower line pressure | Reservoir-side decline, not lift problem | ESCALATE — DCA / reservoir review |
One engineer can carry this checklist in their head for 5 wells. At 50 wells, the depth-of-attention required to apply all 21 points to every well drops below the threshold for catching subtle drift. At 200 wells, the checklist is theoretical — nobody has the hours.
That's the point at which automation earns its keep. Daily diagnostics that check arrival velocity drift, no-arrival rate inflation, fall-time creep, afterflow ratio shift, and the rest of the signature for every plunger-lift well in the portfolio every morning — and surface only the 3–5 that need attention today — is what scales the engineer's judgment instead of replacing it.
WellRX runs that automation. It is not a black-box "AI optimizer." It is a virtual-engineering team applying the same checklist above, every day, to every well, and showing the data and reasoning when something fires.
Charter-partner operators (20–200 active gas wells) get every plunger-lift well checked against this 21-point framework daily, with the deviations surfaced in a ranked queue before 6:30 AM CT. Setup waived, 50% off three months, penalty-free wind-down at week 12.
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