Let’s Be Frank podcasts are perfect to introduce newbies to the petroleum equipment industry; from the latest products, new technology, install and maintenance tips and tricks to brushing up on the latest industry trends.
Here are 4 more episodes from Kali andLet’s Be Frank:
With over a decade of experience on jobsites all over the world, Loren Swalheim (Director, Technical Services) has pretty much seen it all. In this episode, we explore the FFS PRO® suite of services that are powered by Franklin Fueling Systems’ technical expertise and break down how distributors and installers can utilize the tools to make their jobs easier.
What is UL 2447? How does it affect your business? Anna Ogurek and I talk about what this UL certification means, the products it effects, and how Franklin Fueling Systems provides the widest offering of UL 2447 listed products in the industry.
This week I sit down with Anna Ogurek to talk about our new Carbon Series(TM) single and double wall fiberglass dispenser sumps. Hear how the new manufacturing techniques and interstitial monitoring options are making them the most versatile dispenser sumps in the industry.
This week’s theme is Regulation Navigation! The Underground Storage Tank Federal regulations by the EPA went into effect on October 13th, 2018. Are you complying? Gary Saltz and I navigate through these regulations to help you understand what your options are and how to stay in compliance.
The John W. Kennedy Company appreciates your business and continued support!
Our friends at OPW would just like to kindly remind everyone that the EPA’s new Environmental Testing Regulations go into full effect on October 13, 2018, and OPW has a full line of products that are compatible with the 4 major regulatory requirements for new and existing Underground Storage Tank (UST) systems.
OPW has put together a quick reference guide for everything you need to know to be compliant with the new EPA testing requirements.
Download OPW’s EPA Regulations guide to gain access to information from brochures, videos and articles to help you prepare for the October 13, 2018 compliance deadline. Please be sure to indicate the specific OPW EPA-Compliant testable products for which you would like to receive additional information.
Aside from getting some background on why the new regulation exists, who and what it affects, specifics about testing and what happens for non-compliance, it also includes 7 Ways Your Underground Fueling System Can Save You Money.
The following article was written by Richard Browne of Patriot Capital for www.cspdailynews.com. Read the original article here.
ATLANTA — There was a collective sigh of relief on Dec. 1, when Visa, followed quickly by MasterCard, announced a shift in the forecourt gas-pump liability date from 2017 to 2020. I believe there also was a smile in some boardrooms, as retailers that already have invested see an opportunity to capture gallons and inside sales.
Industry reports suggest that about 33% of dispensers in the market are capable of processing payments to Europay MasterCard Visa (EMV) data-security standards with either a software or small hardware upgrade. This represents dispensers installed since 2011, when both Wayne and Gilbarco started shipping “EMV-ready” dispensers. Both manufacturers are reportedly close to or have released the required software to enable EMV, and there’s high probability that many networks will be processing EMV from pumps by mid- to late 2017.
Consumers are quickly becoming used to using a chip card. They are aware of the reason for it: increased security. Crooks are aware of EMV, and can quickly identify fuel dispensers that have—or don’t have—EMV payment enabled.
I believe we’ll see two things happen:
Consumers will shift their buying behavior to EMV-enabled gas pumps, starting in 2017. A high percentage of your customers have had one of their cards breached in the past and want the most secure transaction possible. In Europe and Canada, which have completed their implementation, retailers saw gallons shift to “secure” EMV sites from those that hadn’t yet been upgraded. Switching costs are low in our industry; it’s very easy for a customer to drive another block for a safer experience.
Criminals will have a shrinking number of sites to target. About 10% of dispensers are replaced each year. This suggests that, with no acceleration in upgrades, more than 50% of dispensers will be EMV-enabled in 2018, and 70% in 2020. The crooks have got to eat, and they will have half the sites to target that they had in 2015. Combine this with EMV implemented at restaurants and retail, and the potential places to commit card fraud becomes a small target.
Gray Taylor, executive director of Conexxus, said that Visa and MasterCard’s delay announcements appear to not clearly delay liability for retailers who experience higher fraud rates or those accepting foreign-issued cards. “We don’t see this announcement as a true game delay, but a bit of breathing room,” he said.
It is important to review your fraud liability with your processor, and understand Visa and MasterCard’s plans and how increased fraud may affect you.
It’s highly unlikely that we’ll see the liability upgrade deadline move again. With the installed EMV base naturally approaching 80% or more dispensers, the arguments that caused the date to move have less sway, and all other U.S. payments markets will have been EMV-enabled for five years.
Waiting will get more expensive. It’s generally anticipated that the new administration’s economic plans will result in higher inflation and interest rates. Combine this with promised lower tax rates, which effectively reduce the benefits of capital depreciation and makes equipment more expensive on a net-cost basis, and increases in labor costs, and waiting will be expensive. For multisite operators, the change in bonus depreciation from 50% today to 30% in 2019 and 0% in 2020 can have a significant cash-flow impact.
Competitors that have upgraded to new pumps will have enhanced marketing capabilities that the newest pumps provide. Video screens and contactless payment provide marketing options that can increase adoption of customer-loyalty programs and drive more traffic into your store.
The bottom line: Delaying pump EMV upgrades means potential market-share loss and higher fraud risk for your site. Consumers—and crooks—will know who’s made the move.
The John W. Kennedy Company appreciates your business and continued support!
The spreadsheet is located in two sections on the website;
“Stage I Vapor Recovery Certification Forms” section, and
“Stage II Vapor Recovery Certification & Decommissioning Forms” section.
Please Review the Following:
Registered Stage I / II facilities:
The spreadsheet lists Stage I or Stage II facilities that are registered in the MassDEP Stage I / II database.
Reasons you cannot find a facility or certification form on the report:
There are a number of scenarios why you cannot find a facility or current certification form on the report:
A Stage I / II facility has not registered with the MassDEP Stage I/II program.
The annual Stage I or Stage II certification form, or Stage II decommissioning form, was not received by the Stage I/II program.
Tanks were removed at a facility, and the Stage I/II account was closed, but the Stage I/II program was not notified that new tanks were installed.
For example, a facility removes an underground storage tank (UST), but does not register a newly installed aboveground storage tank (AST) with the Stage I program. ASTs are applicable to the Stage I Vapor Recovery Program and must register with MassDEP by submitting the applicable Stage I certification form, either a Stage I Form A or Stage I Form C,
Data Fields and comments:
Facility ID: The “Facility ID” is Stage I/II ID number, NOT the UST ID number.
Company Name: Company name, facility name, and facility address currently on record in the Stage I / II database.
Tank Type: Indicates if an underground storage tank (UST) or aboveground storage tank (AST) is installed.
Class: Indicates if the facility is registered as a Stage I facility (STG1), or Stage II facility (STG2).
CARB #/Sys Type: Indicates the Stage II CARB number, Stage I CARB number, or Stage I system type.
Test Cycle: Stage II facilities have three test cycles; Third Annual, First Annual, and Second Annual.
Stage I facilities have one test cycle, First Annual, since the same tests are required every year.
Form Sent: The date the applicable Stage I/II form was generated by MassDEP.
Form: The type of form sent to the facility or received.
Form C – Stage I or Stage II Form C (refer to “Class” type)
Form D1 – Stage II Form D1 (no test required)*
Form D2 – Stage II Form D2 (test required)**
Decom – Stage II Decommissioning form
* Facilities eligible for Stage I Form D1’s will be generated starting in 2017.
** Facilities eligible for Stage I Form D2’s will be generated starting in 2018.
Test Date: Most recent Stage I/II compliance testing date.
Postmark Date: Date the completed form was mailed or emailed to the MassDEP Stage I/II program.
Due Date: Compliance Due Date for the applicable Stage I/II annual certification form.
Form Rcvd & Complete? Complete – Form was received and is complete.
Incomplete- Form was received but sections of the form are Incomplete.
Not Received – Form has not been received.
Suspended – Form has not been received and enforcement was issued.
Calculating Due Dates:
Facilities that have submitted Stage II decommissioning forms can be calculated as follows:
Decommissioning test date + 60 days + 1 year = First Stage I Form C due date.
For example, if MassDEP received a decommissioning form with a test date of 12/22/15 the next due date will be…
12/22/15 + 60 days + 1 year = 2/22/17
For decommissioned Stage II facilities the Stage I/II database will generate the first Stage I Form C based on this formula.
Next Due date for certification forms received:
A certification due date is determined by the postmark date on the envelope of your previous year’s certification submission to MassDEP. This approach ensures that all Stage I and Stage II systems are certified at least once every 12 months.
For example, if a facility’s Year 1 certification is postmarked March 23, the facility will be required to mail its next certification to MassDEP by March 23 of Year 2. If, however, the facility mails its Year 2 certification more than 30 days before the facility’s currently applicable due date (for example on February 20), the due date for its Year 3 certification will be February 20, and not remain March 23. Future certification due dates for certifications mailed less than 30 days before their currently applicable due date will remain unchanged.
If maintaining your facility’s current certification due date is important to you, simply schedule your compliance tests for no more than 30 days in advance of that date. You may also schedule your tests and submit your certification at any time before your due date if you wish.
If you have any questions, please contact:
Bureau of Air & Waste
Stage I / II Vapor Recovery Program
1 Winter St., 7th floor
Boston, MA 02108
The John W. Kennedy Company appreciates your business and continued support!
Technical Standards and Corrective Action Requirements for Owners and Operators of Underground Storage Tanks
Late last month, the USEPA published the long-awaited revisions to the Underground Storage Tank (UST) rules under 40 CFR 280 and 281. The full 120-page rule is available on the EPA Office of Underground Storage Tanks website (http://www.epa.gov/oust/fedlaws/revregs.html) and has just been published to the Federal Register. If you do not have the time to delve into the document, we have put together this summary of 10 key things you need to know about the 2015 rule rewrite. This is not an exhaustive list, and the full rule text should be consulted for a comprehensive understanding and evaluation of owner/operator obligations.
OPERATOR TRAINING IS REQUIRED FOR EVERYONE – The Energy Policy Act of 2005 only required training for operators in states that received monies from the EPA. This change ensures that all operators across the country and in states without operator training requirements, and in Indian Country, have training. The EPA is attempting to ensure that all operators across the country are trained to prevent and respond to releases. The EPA has provided a 3 year timeframe for implementation.
WALKTHROUGH INSPECTIONS ARE REQUIRED FOR ALL FACILITIES – Monthly (30) day inspections are required for all facilities that consist of a visual evaluation of spill prevention equipment and release detection equipment. Containment sumps such as for STPs, piping must be viewed at least annually. The purpose is to ensure that owners are looking regularly at their equipment to catch problems early and prevent releases. The EPA is allowing a 3 year adoption period for these inspections.
TESTING REQUIREMENTS FOR SPILL PREVENTION EQUIPMENT, OVERFILL PROTECTION EQUIPMENT, CONTAINMENT SUMPS, AND RELEASE DETECTION – Owners/operators are required to test spill prevention equipment, containment sumps used as secondary containment for piping and overfill protection equipment every three years, and release detection devices must be tested annually. This testing will ensure that all components of a UST system that are designed to detect and prevent a discharge are operating properly. Some components, such as spill buckets, will fail. This rule modification will help operators catch issues early. The EPA is requiring testing within 3 years of the adoption of the rule.
EMERGENCY GENERATORS ARE NO LONGER EXEMPT FROM PERFORMING RELEASE DETECTION MONITORING – With technology now available to monitor tanks and detect releases at remote locations, the EPA has lifted the deferral on this requirement. Owners/operators of emergency generator tanks are now required to equip tanks with release detection monitoring. The EPA is allowing 3 years for the upgrades to take place.
FIELD CONSTRUCTED TANKS AND AIRPORT HYDRANT FUEL DISTRIBUTION SYSTEMS MUST PERFORM RELEASE DETECTION – The 1988 UST Regulations deferred release detection for hydrant systems and field constructed tanks because there was not sufficient technology or information available to effectively test these systems. With technology changes in the marketplace, methods are now available to monitor and detect releases at alternative leak rates and frequencies. To address the uniqueness of these systems, EPA has added in an entirely new subsection (Subpart K) that outlines the general requirements and exceptions. As for an adoption timeframe, various provisions are phased in anywhere from immediately to over a seven year period.
VENT LINE FLOW RESTRICTORS ARE NO LONGER AN OPTION TO MEET OVERFILL REQUIREMENTS – UST systems used to be able to rely on flow restrictors on vent lines (ball floats) as a means to meet the overfill prevention requirements of the 1988 UST rule. Several inherent weaknesses had been identified with the use of this technology, which included in the over-pressurization of tanks. Owners/operators are required to use alternate overfill prevention measures listed in the rule (Subpart B) on all new systems and replaced vent lines. This portion of the rule goes into effect immediately.
INTERNAL LINING NO LONGER ACCEPTABLE AS A SOLE MEANS OF CORROSION PROTECTION -In the past, UST systems that relied on an internal lining as the sole method of corrosion protection could add another internal lining, cathodic protection, or both when internal lining failed a periodic inspection and could not be repaired. The new rule requires tanks using internal lining as the only method of corrosion protection to be permanently closed if the internal lining fails inspection and cannot be repaired according to a code of practice. This portion of the rule is effective immediately.
OWNER NOTIFICATION PRIOR TO SWITCHING TO REGULATED SUBSTANCE CONTAINING >10% ETHANOL, 20% BIODIESEL, OR THAT MEETS COMPATIBILITY CONCERN REQUIREMENTS – With the increased use of biofuels in the marketplace, there is an increasing concern regarding tank material compatibility. The rule revision addresses this concern by requiring owners/operators to notify the regulatory agency at least 30 days prior to switching to a regulated substance containing greater than 10 percent ethanol, greater than 20 percent biodiesel, or any other fuel that the agency identifies as a concern. The owner/operator must demonstrate material compatibility through a listing by a nationally recognized testing laboratory, equipment manufacturer approval, or other method that the agency deems to be no less protective. This change is effective immediately.
INTERSTITIAL MONITORING RESULTS NOW REPORTABLE – As interstitial monitoring becomes a more widely used method of release detection, the EPA has clarified the rule to include its use. Specifically, interstitial alarms are now considered an unusual operating condition under release reporting. EPA adds an option to test secondary containment when present as a means of investigating and/or confirming a release. The rule also adds an option for system closure if a test confirms a leak. This portion of the rule revision is effective immediately.
STATE PROGRAM APPROVAL REQUIREMENTS – States that receive monies from the EPA are required to address the changes made to 40 CFR 280 within 3 years of adoption. Specifically, states must meet the delivery prohibition, operator training, and groundwater protection requirements contained within the Energy Policy Act of 2005.
As stated at the beginning of this article, this list is not a comprehensive or complete summary of the rule changes. There are other key provisions and clarifications that are contained in the rule text and preamble. Should you have any questions regarding your tank system and whether or not your facility is in compliance with the new rule, we suggest you contact our Eclipse Division for an evaluation and consultation.
Joel Hershey is the Director of Environmental Compliance Services, Inc. (ECS’) Eclipse Fuel System Management Division. He has worked exclusively in the field of petroleum liquid storage systems since 1989. His expertise includes compliance testing, diagnostics, petroleum construction, maintenance, and upgrades for both UST and AST systems. During his career, Joel has held various positions, including Senior Petroleum Specialist, Operations Manager, and four years as Senior Vice President for Tanknology. There he managed and executed upgrades for more than 6,800 facilities to meet the 1998 federal UST systems upgrades. He can be reached at (800) 789-3530 or email@example.com.
As always, feel free to contact us at 1.800.451.4021 with any questions.
We appreciate your business and thank you for your continued support!