Preventive maintenance checklist for fuel stations

A station that operates without a formal checklist depends on the memory of the operator on duty. Memory fails; the checklist does not. The Petroleum Equipment Institute's PEI RP900 standard — the only inspection and maintenance practice referenced in the EPA's underground tank regulation (40 CFR Part 280) — defines two formal lists: a monthly one (walkthrough) and an annual one (more thorough). To those two must be added the triennial tightness tests of PEI RP1200.

What follows is the checklist we use in Panamanian stations, organized by frequency. Each item is mapped to its regulatory reference so the operator knows why it is checked, and so that, in an inspection, they can show the backing. If you want the version adapted to the specific equipment of your station (Veeder-Root TLS-350 vs TLS-450PLUS, sump type, dispenser brand), request a station assessment and we will build it with the exact items.

Monthly list: walkthrough every 30 days

Done by a trained operator (the EPA regulation's Class A/Class B concept). Document date, responsible person, and observations. Typical time: 30 to 60 minutes.

Spill buckets

• [ ] Free of liquid or residue.
• [ ] Fill cap properly secured.
• [ ] No visible cracks in the bucket.
• [ ] Drain to the tank works (if applicable) or product purged.

Containment sumps and STP sump

• [ ] Dry (no water, fuel, or residue).
• [ ] Piping penetration boots without cracks or displacement.
• [ ] Liquid sensor installed vertical to the bottom of the sump.
• [ ] Sump lid properly sealed.

ATG console (Veeder-Root TLS-350 / TLS-450PLUS)

• [ ] No red or yellow alarm lights.
• [ ] LCD screen without an "alarm" message.
• [ ] In function → "liquid status": each sensor (L1, L2, L3...) shows "normal condition".
• [ ] Monthly report printout filed (minimum 12 months on file).

Tanks

• [ ] Water measurement at the bottom (precision ≥1/8 inch), no significant accumulation.
• [ ] No inventory discrepancy greater than 1.0% of dispensed volume + 130 gallons in the month.
• [ ] Last delivery reconciles with the inventory reported by the ATG.

Lines and dispensers

• [ ] No fuel odor in the island area without active dispensing.
• [ ] Under-dispenser sumps (UDC) free of liquid.
• [ ] Hoses, nozzles, and breakaways without visible damage, leaks, or dripping.

General safety

• [ ] Emergency stop functional (pressed and reset in a test).
• [ ] Fire extinguishers with current charge and NFPA-marked.
• [ ] Hydrocarbon separator without overflow or obstruction.

The item that fails most often on this monthly list, in our experience, is the printing and filing of the ATG report. The operator reviews the console but does not print. Without the filed ticket, there is no proof in an inspection that the review existed, even if it was done.

Annual list: deep functional inspection

Performed by a certified technician. Typical time: 4 to 8 hours depending on the number of islands. Documented with a signed logbook.

ATG and leak detection

• [ ] Complete electronic operability test (console, probes, alarms).
• [ ] Backup battery tested.
• [ ] Probes removed: residue cleaning, free floats, undamaged shaft, untwisted cables.
• [ ] Overfill alarm tests (set at 90% alert / 95% cutoff).
• [ ] Configuration verification: tank chart, alarm thresholds, communication.

Pressurized lines (if there is no continuous monthly monitoring)

• [ ] Line tightness test capable of detecting a 0.1 gph leak at 1.5× the operating pressure.

Cathodic protection (steel tanks/lines)

• [ ] Impressed-current inspection already covered in the 60-day cycle.
• [ ] Documentary review: reading records, anode status, continuity.

Cathodic protection applies only to metal tanks and lines: per PEI RP100-17 §12.1, systems built with corrosion-resistant materials (such as fiberglass) do not require additional cathodic protection. If the station has FRP tanks, this section of the checklist is replaced by interstitial integrity verification.

Dispensers

• [ ] Filters: change if high pressure differential or "chocolatey" appearance.
• [ ] Meter seals: leak inspection.
• [ ] Quick calibration test against a certified 5-gallon prover (detection of metrological drift).
• [ ] Electronic vs. mechanical totalizer: reconciliation.
• [ ] Under-dispenser sump: drain, flex connectors, seals.

Civil works and structure

• [ ] Canopy: anchor torque, oxidation on columns.
• [ ] Slab: cracks, settlement, slope toward drains.
• [ ] Drains and hydrocarbon separator: cleaning, measurement of the product layer.

Logbook

• [ ] Close the annual logbook with the technician's signature, a list of activities performed, and observations for the next cycle.

The item that fails most often in the annual is the physical removal of the ATG probes. The technician tests the electronics from the console but does not pull the probes, and probes with residue or stuck floats are a frequent cause of false readings that are later discovered in a real, poorly detected leak.

Triennial list: tightness tests

Performed by a third party with certified equipment (PEI RP1200). Frequency: every 3 years from the last test.

Spill buckets

• [ ] Tightness test by vacuum, pressure, or liquid depending on the type.

Overfill prevention

• [ ] Activation test at the configured volume (90-95% capacity).

Containment sumps (double-walled)

• [ ] Interstitial tightness test.

These three components — spill bucket, overfill prevention, and containment sump — are the ones PEI RP100-17 §7.1-§7.4 and §8 require to be installed as layers of protection, and the ones PEI RP1200 requires to be tested every 3 years. A spill bucket installed without the correct slope or an overfill whose activation was never tested at 90-95% are installation failures that the triennial cycle reveals, but only if the test is performed, not if it is postponed.

Cathodic protection

• [ ] Complete certified test by a qualified evaluator (not the 60-day inspection, the formal test).

These triennial tests are the ones most often delayed because they "are not visible." A station that religiously meets the monthly walkthrough can go 5 years without testing a spill bucket, and that is exactly where the chronic leaks that reach the subsoil appear.

How to use this list at a real station

Three operational rules.

Rule 1: the list is completed on site, not in the office. The operator with a tablet or paper walks the station marking each box with the item in front of them. A list filled in "from memory" at the end of the shift is worthless in an audit.

Rule 2: each box with an observation generates an action. If the spill bucket has liquid, the purge action is recorded with date and responsible person. If the ATG shows an alarm, the investigation is documented separately. A list without derived actions is a dead, filed list.

Rule 3: the quarterly review crosses lists vs. execution. The station manager or program lead reviews every three months: were all the monthly walkthroughs done? Is the annual up to date? Are the triennial tests scheduled or overdue? This review is what turns the list into a program.

The items that fail most often (summary)

• Printing and filing of the monthly ATG report.
• Physical removal of probes in the annual inspection.
• Triennial tests of spill buckets and overfill (delayed for years).
• Sump sensor documentation (vertical position, calibration).
• Electronic vs. mechanical totalizer reconciliation in dispensers.

If your station has any of these pending, you are not alone, but it is not optional either. Schedule an tightness test if the triennial ones are overdue, or ask us for a compliance audit that closes the list above in a single visit. What is not on the list, in practice, does not exist.