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This is a brief description of the most popular Tests that we provide. For more information please contact us via the "Contact Us" tab.

Annual Compliance Test

Annual Compliance Testing is comprised of  these 7 individual tests:

  • Pressure Decay

  • Vapor Tie

  • P/V Vent Cap Testing

  • Dynamic Backpressure/Liquid Blockage

  • Air-to-Liquid Ratio

  • Leak Detectors

  • ATG Monitor certificate Testing

In Massachusetts all of these tests must be passed every year to be compliant with state and/or federal law.

Tank Tightness Test


Tank Tightness Testing is required in the event of a failed or non-conclusive Statistical Inventory Reconciliation (SIR) report, as mandated by local, state or federal inspectors, or as required by the owner’s insurance company.

Requirements for Tank Tightness Testing: 

  • Maximum of 20,000 gallon capacity for each tank.

  • Minimum of 24 inches of product in each tank.

  • Minimum of 12 hours waiting period after fuel delivery.

  • Maximum of 10,000 gallons Ullage (vapor space).

  • Minimum 1 hour test time.

  • Typical down-time for test: 2-5 hours.

Pressure Decay

Static Pressure Decay Testing is usually required annually for stations equipped with Stage II vapor recovery.

Requirements for Static Pressure Decay Testing:

  • Maximum 25,000 gallons of Ullage (vapor space) in the gasoline system. Diesel is not included.

  • Minimum of 1,000 gallons of Ullage in each tank.

  • Minimum 6 inches of fuel in each tank.

  • Minimum 3 hour period between fuel delivery and test.

  • Example:

    • Site equipped with (3) 10,000 gallon gas tanks (no diesel). This means the system capacity is 30,000 gallons.

    • Must have a minimum of 5,000 gallons in the entire system at the time of the test to meet the maximum requirement of 25,000 gallons of Ullage. The following combination would suffice (or any combination):

      • Regular 3,000 gallons

      • Midgrade 1,000 gallons

      • Premium 1,000 gallons

    • No more than 9,000 gallons of fuel in each tank

    • Each tank must have at least 6 inches of product to conduct the test

  • Typical down-time for test: The entire station must be shut down for 30 minutes prior to conducting this test. Test length is 5 minutes; however, typical testing time varies from 1-3 hours depending on troubleshooting requirements.

Cathodic Protection Test


Steel tanks equipped with a Cathodic Protection (CP) system require testing once every three years at a minimum. In addition, sites equipped with an impressed current system have a rectifier which requires inspection once every 60 days. Owner/operators may conduct the 60-day inspections, however, a certified CP tester is required for the three year test.

Requirements for Cathodic Protection System Testing:

  • Access to the rectifier (if applicable).

  • Access to the protected structures (tanks, lines, etc.).

  • Site or products will only require down-time in the event the protected structures are located in a high-traffic area near the fuel dispensing area. 

  • Typical test time: 30-45 minutes per tank.

Leak Detector Test


Leak Detector Testing is required annually for all underground pressurized lines regardless of line configuration. A 3GPH leak must be simulated by a licensed technician once a year to ensure the line is protected from a catastrophic failure.

Requirements for Leak Detector Testing:

  • Access to circuit breaker and turbine relay boxes.

  • Simulate 3GPH leak at a metering pressure of 10 PSI.

  • Typical down-time for test: 30-45 minutes.


ATG Monitor Test


The technician must test every sensor under the dispensers and underground to ensure that each is working properly to warn for any failures. They then gather the information via the print out on your automatic fuel tank gauge system.

Stage II Decommissioning


U.S. EPA Allowing Decommissioning of Stage II Vapor Recovery Systems


In the 1990s, The United States Clean Air Act (CAA) required many ozone nonattainment areas to adopt Stage II Vapor Recovery systems at their gasoline-dispensing facilities (GDF). Beginning in 1998, the CAA also required vehicle-makers to add onboard refueling vapor recovery (ORVR) systems for capturing gasoline vapors during refueling to all automobiles and light- and medium-duty cars, vans and trucks. Since 2006, all new vehicles and trucks have been equipped with ORVR systems.

In large part because of the positive impacts ORVR systems have had on the reduction of harmful fugitive emissions during refueling, on May 16, 2012, the U.S. Environmental Protection Agency (EPA) issued a final ruling stating that since ORVR is now in widespread use, all states and regions with Stage II Vapor Recovery programs in place for ozone nonattainment areas have the option of removing these programs from their state implementation plans (SIPs). In order to approve the SIP revision, the EPA requires the state or region to produce a technical demonstration showing that removing a Stage II Vapor Recovery systems will not adversely impact air quality.

GDFs that provide an acceptable technical demonstration to the EPA are allowed to permanently decommission their Stage II Vapor Recovery Systems. To aid in this process, the Petroleum Equipment Institute has created "RP300: Recommended Practices for Installation and Testing of Vapor-Recovery Systems at Vehicle-Fueling Sites," specifically Section 14: Decommissioning State II Vapor-Recovery Piping.


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