Section 130. Pollution prevention standards and procedures

Part III. Pollution Prevention Requirements

A. Pollution prevention standards and procedures for facilities are listed in this section. Aboveground storage tanks with an aggregate capacity of one million gallons or more shall comply with the requirements of subsections B and C of this section.

B. Requirements for aboveground storage tanks at facilities for 25,000 gallons or more. Section 62.1-44.34:15.1 of the Code of Virginia provides the following requirements for existing aboveground storage tanks at a facility with an aggregate aboveground storage capacity equal to or greater than 25,000 gallons of oil or for an existing individual aboveground storage tank with a storage capacity equal to or greater than 25,000 gallons of oil, unless otherwise exempted.

1. Inventory control and testing for significant variations.

a. The following aboveground storage tanks shall not be subject to inventory control and testing for significant variations:

(1) Aboveground storage tanks totally off ground with all associated piping off ground;

(2) Aboveground storage tanks with a capacity of 5,000 gallons or less located within a building or structure designed to fully contain a discharge of oil; and

(3) Aboveground storage tanks containing No. 5 or No. 6 oil for consumption on the premises where stored.

b. Each operator shall institute inventory control procedures capable of detecting a significant variation of inventory. A significant variation shall be considered a variation in excess of 1.0% of the storage capacity of each individual AST. Reconciliations of inventory measurements shall be conducted monthly. If a significant variation persists for two consecutive reconciliation periods, the operator shall conduct an investigation to determine the cause of the variation and reconcile physical measurements to 60°F at 14.7 pounds per square inch absolute. This investigation shall be completed within five working days of the end of the second reconciliation period. If this investigation does not reveal the cause of the inventory variation, the operator shall notify the board and the local director or coordinator of emergency services and shall conduct additional testing to determine the cause of the inventory variation. The testing method, schedule, and results of this additional testing shall be submitted to the board for review. For a refinery, a significant variation of inventory shall be considered a loss in excess of 1.0% by weight of the difference between the refinery's input and output of oil.

c. Inventory records shall be kept of incoming and outgoing volumes of oil from each tank. All tanks shall be gauged no less frequently than once every 14 days and on each day of normal operation. For a refinery, the operator shall calculate the input and output of oil at the refinery on a daily basis. The operator shall reconcile daily inventory records with the inventory measurements conducted monthly.

2. Secondary containment.

a. The operator shall have and maintain secondary containment or another method approved by the board for each AST. The containment structure must be capable of containing oil and shall be constructed in accordance with 40 CFR Part 112 so that any discharge from the AST will not escape the containment before cleanup occurs. The operator shall have each secondary containment or approved method evaluated and certified to be in compliance with the applicable requirements of 40 CFR Part 112, the Uniform Statewide Building Code and its referenced model codes and standards, and 29 CFR 1910.106. The operator of a facility existing on June 24, 1998, shall have had this evaluation or certification performed by a professional engineer or person approved by the board on or before June 30, 1998, and every 10 years thereafter, unless otherwise exempted.

b. If the secondary containment cannot be certified to be in compliance with the applicable requirements of 40 CFR Part 112, the Uniform Statewide Building Code and its referenced model codes and standards, and 29 CFR 1910.106, the operator must upgrade, repair, or replace the secondary containment to meet the applicable requirements listed in subdivision 2 a of this subsection unless the board accepts the certification with qualifications.

c. The operator of a facility shall have the evaluation and certification performed every 10 years by a professional engineer (PE) licensed in the Commonwealth of Virginia or other state having reciprocity with Virginia or by a person approved by the board unless otherwise exempted.

d. The professional engineer shall not certify the secondary containment until all of the applicable requirements of 40 CFR Part 112, the Uniform Statewide Building Code and its referenced model codes and standards, and 29 CFR 1910.106 have been met. In the event the professional engineer certifies the secondary containment with qualifications, such qualifications will be subject to review and approval by the board. If the certification contains qualifications that may impact the ability of the secondary containment to contain a discharge of oil as required by subdivision 2 a of this subsection, the deficiencies must be corrected and the secondary containment must be reevaluated and recertified by a professional engineer.

e. At a minimum, the certification statement for the secondary containment must contain the following statement: "Based on my evaluation, I hereby certify that each secondary containment structure for (insert the facility name and tank identification information) is in compliance with the applicable requirements of 40 CFR Part 112, the Uniform Statewide Building Code and its referenced model codes and standards, and 29 CFR 1910.106."

f. The certification must be signed and sealed by a professional engineer licensed in the Commonwealth of Virginia or other state having reciprocity or by a person approved by the board.

g. Operators of facilities existing on June 24, 1998, and exempted under § 62.1-44.34:17 D of the Code of Virginia (i.e., exempted facilities not engaged in the resale of oil) shall have had this evaluation completed on or before June 24, 2003, and every 10 years thereafter.

h. Operators of a newly installed AST shall have this evaluation completed prior to being placed into service and every 10 years thereafter.

i. Operators of an existing AST with a current engineering certification statement on November 1, 2015, may maintain their existing engineering certification statement until their next required certification, or 10 years, whichever is sooner. At such time, the certification statements must contain the statement required in 9VAC25-91-130 B 2 e.

3. Safe fill and shutdown procedures.

a. Each operator shall institute safe fill, shutdown, and transfer procedures, or equivalent measures approved by the board, that will ensure that spills resulting from tank overfills or other product transfer operations do not occur. Written safe fill, shutdown, and transfer procedures shall be maintained by the operator for use by facility personnel.

All receipts of oil shall be authorized by the operator or facility personnel trained by the operator who shall ensure the volume available in the tank is greater than the volume of oil to be transferred to the tank before the transfer operation commences. The operator shall ensure the transfer operation is monitored continually, either by manual or automatic means, until complete. The operator shall ensure that all tank fill valves not in use are secured and that only the tank designated is receiving oil.

b. All oil transfer areas where filling connections are made with vehicles shall be equipped with a spill containment system capable of containing and collecting those spills and overfills. The containment system shall be designed to hold at least the capacity as required by 40 CFR Part 112.

c. If installed, an automatic shutdown system utilized during transfer of oil shall include the capability to direct the flow of oil to another tank capable of receiving the transferred oil or the capability to shut down the pumping or transfer system. This automatic shutdown system shall be tested prior to each receipt of oil and records of testing shall be maintained at the facility.

d. All ASTs shall be equipped with a gauge that is readily visible and indicates the level of oil or quantity of oil in the tank. In addition, the storage capacity, product stored and tank identification number shall be clearly marked on the tank at the location of the gauge. These gauges shall be calibrated annually.

4. Pressure testing of piping. All piping shall be pressure tested as specified in this subsection or using an equivalent method or measure approved by the board at intervals not to exceed five years. The operator of a facility or AST existing on June 24, 1998, shall have completed the initial test on or before June 30, 1998, except operators of existing facilities or ASTs for which compliance was exempted under § 62.1-44.34:17 D of the Code of Virginia (i.e., exempted facilities not engaged in the resale of oil). These excepted operators shall have completed the initial test on or before June 24, 2003. All newly installed or repaired piping shall be tested before being placed into service.

a. A pressure test may be a hydrostatic test at 150% maximum allowable working pressure (MAWP) or an inert gas test at 110% MAWP.

b. A test conducted and certified by an American Petroleum Institute (API) authorized piping inspector to be in conformity with the API 570 Piping Inspection Code is deemed an equivalent method of testing approved by the board.

c. The board may consider on a case-by-case basis requests for approval of other equivalent methods or measures which conform to industry recommended practices, standards and codes. The operator shall submit a request for approval of a proposed equivalent method or measure to the board as specified in 9VAC25-91-160.

5. Visual daily inspection and weekly inspections.

a. The operator or a duly authorized representative shall conduct a daily visual inspection for each day in which normal operation occurs, but no less frequently than once every 14 days in the areas of the facility where this chapter applies. The facility person conducting the inspection shall document completion of this inspection by making and signing an appropriate notation in the facility records. This visual inspection shall include the following:

(1) A complete walk-through of the facility property in the areas where this chapter applies to ensure that no hazardous conditions exist;

(2) An inspection of ground surface for signs of leakage, spillage, or stained or discolored soils;

(3) A check of the berm or dike area for excessive accumulation of water and to ensure the dike or berm manual drain valves are secured;

(4) A visual inspection of the exterior tank shell to look for signs of leakage or damage; and

(5) An evaluation of the condition of the aboveground storage tank and appurtenances.

b. The operator or a duly authorized representative shall conduct a weekly inspection each week in which normal operation occurs, but no less frequently than once every 14 days, of the facility in the areas where this chapter applies, using a checklist that contains at least the items found in subdivision 5 c of this subsection. The checklist is not inclusive of all safety or maintenance procedures but is intended to provide guidance to the requirements within this chapter. The weekly checklist shall be maintained at the facility and provided to the board upon request. This checklist shall be signed and dated by the facility person or persons conducting the inspection and shall become part of the facility record.

(1) The operator of a new AST/facility shall develop the checklist within 90 days after the date of installation.

(2) The operator of each facility existing on June 24, 1998, and exempted under § 62.1-44.34:17 D of the Code of Virginia (i.e., exempted facilities not engaged in the resale of oil) shall have developed the checklist by September 28, 1998.

(3) Operators of facilities existing on June 24, 1998, and not exempted under § 62.1-44.34:17 D of the Code of Virginia (i.e., exempted facilities not engaged in the resale of oil) and who have developed a checklist by September 28, 1993, shall be deemed to be in compliance with this checklist requirement as of June 24, 1998.

c. Sample—weekly inspection checklist for aboveground storage tank systems:

____ (1) Containment dike or berm in satisfactory condition.

____ (2) Containment area free of excess standing water or oil.

____ (3) Gate valves used for emptying containment areas secured.

____ (4) Containment area/base of tank free of high grass, weeds, and debris.

____ (5) Tank shell surface, including any peeling areas, welds, rivets/bolts, seams, and foundation, visually inspected for areas of rust and other deterioration.

____ (6) Ground surface around tanks and containment structures and transfer areas checked for signs of leakage.

____ (7) Leak detection equipment in satisfactory condition.

____ (8) Separator or drainage tank in satisfactory condition.

____ (9) Tank water bottom drawoffs not in use are secured.

____ (10) Tank fill valves not in use are secured.

____ (11) Valves inspected for signs of leakage or deterioration.

____ (12) Inlet and outlet piping and flanges inspected for leakage.

____ (13) All tank gauges have been inspected and are operational.

	Signature of Inspector		Date		Time

d. The operator shall promptly remedy unsatisfactory facility and equipment conditions observed in the daily and weekly inspections. The operator shall make repairs, alterations, and retrofits in accordance with American Petroleum Institute (API) Standard 653, Fourth Edition (April 2009), with Addendum 1 (August 2010) and Addendum 2 (January 2012), Steel Tank Institute (STI) standard STI-SP001, Fifth Edition (September 2011), industry standards, or methods approved by the board.

6. Training of individuals. To ensure proper training of individuals conducting inspections required by subdivision 5 of this subsection, the operator of a facility shall train personnel based on the following requirements:

a. Each facility operator shall establish a training program for those facility personnel conducting the daily visual and weekly inspections of the facility. Facility records shall contain the basic information and procedures required by subdivision 6 c of this subsection. The required training may be conducted by the operator or by a third party. The training program established shall be maintained to reflect current conditions of the facility.

(1) The operator of a new facility shall establish the training program within six months after being brought into use.

(2) The operator of each facility exempted under § 62.1-44.34:17 D of the Code of Virginia (i.e., exempted facilities not engaged in the resale of oil) shall have established the training program by December 24, 1998.

(3) Operators of facilities not exempted under § 62.1-44.34:17 D of the Code of Virginia (i.e., exempted facilities not engaged in the resale of oil) and who developed a training program by December 31, 1993, shall be deemed to be in compliance with this training program requirement as of June 24, 1998, so long as that program reflects current conditions of the facility.

b. The required training shall be conducted for facility personnel as applicable. Personnel not receiving this initial training and who will be conducting these inspections shall receive the training prior to conducting any inspection.

(1) The operator of a new facility shall conduct the personnel training within 12 months after being brought into use and prior to personnel conducting any inspection.

(2) The operator of each facility exempted under § 62.1-44.34:17 D of the Code of Virginia (i.e., exempted facilities not engaged in the resale of oil) shall have conducted the personnel training by June 24, 1999.

(3) Operators of facilities not exempted under § 62.1-44.34:17 D of the Code of Virginia (i.e., exempted facilities not engaged in the resale of oil) and who have conducted the personnel training by June 30, 1994, shall be deemed to be in compliance with this personnel training requirement as of June 24, 1998, so long as the training provided reflects current conditions of the facility and all inspections are current.

c. Training for personnel performing daily and weekly inspections shall address at a minimum:

(1) Basic information regarding occupational safety, hazard recognition, personnel protection, and facility operations;

(2) The procedures to be followed in conducting the daily visual and weekly facility inspections;

(3) The procedures to be followed upon recognition of a hazard or the potential for a hazard; and

(4) The procedure for evaluating the condition of the aboveground storage tank and appurtenances.

d. The operator of a facility shall train facility personnel upon any changes to the contents of the initial training program or every three years and shall document this training in the facility records.

7. Leak detection. The operator shall operate, maintain, monitor and keep records of the system established for early detection of a discharge to groundwater (i.e., a method of leak detection) as required by 9VAC25-91-170 A 18 and contained in the facility's approved ODCP. These activities shall be inspected and approved by the board.

C. Requirements for aboveground storage tanks at facilities for one million gallons or more. In addition to the requirements of subsection B of this section, the following requirements apply to existing aboveground storage tanks at facilities with an aggregate aboveground storage capacity of one million gallons or more of oil or for an existing individual aboveground storage tank with a storage capacity of one million or more gallons of oil, unless otherwise exempted.

1. Formal inspections.

a. Each AST shall undergo formal external and internal tank inspections. The initial formal internal and external inspections for an AST existing on June 24, 1998, shall have been completed on or before June 30, 1998, unless otherwise specified within this chapter.

(1) All newly installed ASTs shall have initial formal inspections within five years after the date of installation.

(2) Operators of facilities existing on June 24, 1998, and exempted under § 62.1-44.34:17 D of the Code of Virginia (i.e., exempted facilities not engaged in the resale of oil) shall have completed the initial formal inspections on or before June 24, 2003.

(3) An AST with a storage capacity of less than 12,000 gallons shall not be subject to the formal internal inspection unless the integrity of the AST is in question and an inspection is deemed necessary by the board.

b. Inspections shall be conducted in accordance with the provisions of American Petroleum Institute (API) Standard 653, Fourth Edition (April 2009), with Addendum 1 (August 2010) and Addendum 2 (January 2012); Steel Tank Institute (STI) standard STI-SP001, Fifth Edition (September 2011); or procedure approved by the board. If construction practices allow external access to the tank bottom, a formal external inspection utilizing accepted methods of nondestructive testing or procedure approved by the board may be allowed in lieu of the internal inspection.

c. An API Standard 653 inspection conducted between January 1, 1991, and June 24, 1998, may be accepted by the board if the operator provides supporting documentation to the board for review and approval.

d. All formal inspections and testing required by subdivisions 1 and 2 of this subsection shall be conducted by a person certified to conduct the inspection or test. This certification shall be accomplished in accordance with the provisions of API Standard 653, STI-SP001, or a procedure approved by the board. Proof of this certification shall be maintained in the facility records. The results of all tests and inspections required by subdivisions 1 and 2 of this subsection shall be maintained at the facility or at a location approved by the board for the life of the tank, but for no less than five years.

2. Formal reinspections.

a. Each AST shall undergo an external reinspection every five years. Inspections shall be conducted in accordance with the provisions of API Standard 653, STI-SP001, or other procedure accepted by the board after the initial formal external inspection has been conducted.

b. Each AST with a storage capacity of 12,000 gallons of oil or greater shall undergo an internal reinspection in accordance with the provisions of API Standard 653 or STI-SP001 every 10 years after the initial formal internal inspection has been conducted.

(1) The board may require the internal reinspection sooner than 10 years if there is an indication that the corrosion rate established by the initial internal inspection or a subsequent reinspection has increased.

(2) The internal reinspection period may be extended beyond 10 years if the operator can demonstrate to the board that an extension of the reinspection period is warranted. The operator shall provide supporting documentation to the board for review and approval at least six months prior to the date the reinspection is due.

c. An AST with a storage capacity of less than 12,000 gallons shall not be subject to the formal internal reinspection unless the integrity of the AST is in question and an inspection is deemed necessary by the board.

3. Safe fill and shutdown procedures - high level alarm. If unattended during transfer operations, the AST shall be equipped with a high level alarm or other appropriate mechanism approved by the board that will immediately alert the operator to prevent an overfill event. Activation of the high level alarm or other appropriate mechanism shall initiate an immediate and controlled emergency shutdown of the transfer, either by manual or automatic means. Each operator shall include this emergency shutdown procedure in the facility records and shall ensure that all facility personnel involved in the transfer operation are trained in this procedure. The alarm shall consist of a visual and audible device capable of alerting the operator, both by sight and hearing, to prevent an overfill situation. If the operator is in a control station, this alarm shall activate a warning light and audible signal in that station. In addition, this system shall alarm on failure, malfunction, or power loss. This high level alarm shall be tested prior to each receipt of oil. Records of testing shall be maintained at the facility.

4. Cathodic protection of piping. The requirement for cathodic protection of piping shall apply to buried piping only. Cathodic protection shall be installed and maintained in accordance with the following applicable publications: American Petroleum Institute Standard (API) 1632, Third Edition (2002), the Uniform Statewide Building Code and its referenced model codes and standards, or National Association of Corrosion Engineers (NACE) SP0285-2011. All piping above ground shall be protected from corrosion using methods and procedures referenced in the Uniform Statewide Building Code and its referenced model codes and standards, or a procedure approved by the board. Piping that passes through the wall of the containment berm or dike or under road crossings shall be protected from corrosion and damage using practices recommended in the publications listed in this subdivision.

Historical Notes

Derived from Volume 14, Issue 18, eff. June 24, 1998; Errata, 14:23 VA.R. 3682 August 3, 1998; amended, Virginia Register Volume 31, Issue 26, eff. November 1, 2015.

Statutory Authority

§§ 62.1-44.15, 62.1-44.34:15, 62.1-44.34:15.1 and 62.1-44.34:19.1 of the Code of Virginia.