40 C.F.R. § 49.164 – Air quality permit by rule for new or modified true minor source gasoline dispensing facilities in Indian country.

(a) Abbreviations and acronyms:
AST Aboveground Storage Tank CAA or the Act Federal Clean Air Act CFR Code of Federal Regulations EPA United States Environmental Protection Agency GDF Gasoline Dispensing Facility NAAQS National Ambient Air Quality Standards NSR New Source Review ppm parts per million PSD Prevention of Significant Deterioration PV Pressure/Vacuum VOC Volatile Organic Compounds
(b) Definitions for the purposes of this permit by rule.
1. (1) Cause means with respect to the reviewing authority's ability to terminate a permitted source's coverage under a permit that:
  1. (i) The permittee is not in compliance with the provisions of this permit by rule;
  2. (ii) The reviewing authority determines that the emissions resulting from the construction or modification of the permitted source significantly contribute to NAAQS violations, which are not adequately addressed by the requirements in this permit by rule;
  3. (iii) The reviewing authority has reasonable cause to believe that the permittee obtained coverage under the permit by rule by fraud or misrepresentation; or
  4. (iv) The permittee failed to disclose a material fact required by the Notification of Coverage or the requirements applicable to the permitted source of which the applicant had or should have had knowledge at the time the permittee submitted the Notification of Coverage.
2. (2) Construction means any physical change or change in the method of operation including fabrication, erection, installation, demolition, or modification of an affected emissions unit that would result in a change of emissions.
3. (3) Dual-point vapor balance system means a type of vapor balance system in which the storage tank is equipped with an entry port for a gasoline fill pipe and a separate exit port for a vapor connection.
4. (4) Emergency engine means any stationary reciprocating internal combustion engine that meets all of the criteria in paragraphs (b)(4)(i) through (iii) of this section. All emergency engines must comply with the requirements specified in 40 CFR 63.6640(f) in order to be considered emergency engines. If the engine does not comply with the requirements specified, then it is not considered to be an emergency engine.
  1. (i) The engine is operated to provide electrical power or mechanical work during an emergency situation. Examples include engines used to produce power for critical networks or equipment (including power supplied to portions of a facility) when electric power from the local utility (or the normal power source, if the facility runs on its own power production) is interrupted, or an engine used to pump water in the case of fire or flood, etc.
  2. (ii) The engine is operated under limited circumstances for situations not included in paragraph (b)(4)(i) of this section, as specified in 40 CFR 63.6640(f).
  3. (iii) The engine operates as part of a financial arrangement with another entity in situations not included in paragraph (b)(4)(i) of this definition only as allowed in 40 CFR 63.6640(f).
5. (5) Notification of Coverage means the permit notification that contains all the information required in the standard notification form for this permit by rule.
6. (6) Permittee means the owner or operator of a permitted source.
7. (7) Permitted source means each gasoline dispensing facility for which a permitted source submits a complete Notification of Coverage.
8. (8) Responsible official means one of the following:
  1. (i) For a corporation: a president, secretary, treasurer, or vice-president of the corporation in charge of a principal business function, or any other person who performs similar policy or decision-making functions for the corporation, or a duly authorized representative of such person if the representative is directly responsible for the overall operation of the permitted source;
  2. (ii) For a partnership or sole proprietorship: a general partner or the proprietor, respectively; or
  3. (iii) For a public agency: Either a principal executive officer or ranking elected official, such as a chief executive officer having responsibility for the overall operations of a principal geographic unit of the agency.
9. (9) Submerged filling means the filling of a gasoline storage tank through a submerged fill pipe whose discharge is no more than 6 inches from the bottom of the tank. Bottom filling of gasoline storage tanks is covered under this submerged filling definition.
10. (10) Ullage means the volume of a container not occupied by liquid. For example, the ullage of a tank designed primarily for containing liquid is the volume of the tank minus the volume of the liquid it contains.
11. (11) Vapor balance system means a combination of pipes and hoses that create a closed system between the vapor spaces of an unloading gasoline cargo tank and a receiving storage tank such that vapors displaced from the storage tank are transferred to the gasoline cargo tank being unloaded.
12. (12) Vapor tight means equipment that allows no loss of vapors. Compliance with vapor-tight requirements can be determined by checking to ensure that the concentration at a potential leak source is not equal to or greater than 100 percent of the lower explosive limit when measured with a combustible gas detector, calibrated with propane, at a distance of 1 inch from the potential leak source.
(c) Information about this permit by rule—(1) Applicability. Pursuant to the provisions of the CAA, subchapter I, part D and 40 CFR part 49, subpart C, this permit authorizes the construction or modification and the operation of each stationary gasoline dispensing facility (GDF) for which a reviewing authority receives a completed Notification of Coverage (permitted source).
(2) Eligibility. To be eligible for coverage under this permit by rule, the permitted source must qualify as a true minor source as defined in 40 CFR 49.152 and satisfied the requirements in 40 CFR 49.156(f)(6)(iii). In addition, coverage under this Permit by Rule is not available in areas located within the geographic boundaries of California.
(3) Notification of Coverage. Requirements for submitting a Notification of Coverage are contained in paragraph (d)(1) of this permit by rule. The information contained in each permitted source's Notification of Coverage is hereby enforceable under this permit by rule.
(4) Termination. Paragraph (d)(6) of this permit by rule addresses a reviewing authority's ability to revise, revoke and reissue, or terminate coverage under this permit by rule. It also addresses the reviewing authority's ability to terminate an individual permitted source's coverage under this permit by rule.
(5) Definitions. The terms used herein shall have the meaning as defined in 40 CFR 49.152, unless otherwise defined in paragraph (b) of this permit by rule. If a term is not defined, it shall be interpreted in accordance with normal business use.
(d) Permit by rule terms and conditions. The following applies to each permittee and permitted source with respect to only the affected emissions units and any associated air pollution control technologies in that permitted source's Notification of Coverage.
(1) General provisions—(i) Obtaining coverage under this permit by rule. To obtain coverage under this permit by rule, an applicant must submit a completed Notification of Coverage to the appropriate reviewing authority for the area in which the permitted source is or will be located (the Notification of Coverage Form can be found at: http://www.epa.gov/air/tribal/tribalnsr.html). Table 1 of paragraph (f) contains a list of reviewing authorities and their area of coverage. You must also submit a copy of the Notification of Coverage to the Indian governing body for any area in which the permitted source will operate. Coverage under this permit by rule is not available in areas within the geographical boundaries of California.
(ii) Construction and operation. The permittee shall construct or modify and shall operate the affected emissions units and any associated air pollution control technologies in compliance with this permit by rule and all other applicable federal air quality regulations; and in a manner consistent with representations made by the permittee in the Notification of Coverage.
(iii) Locations. This permit by rule only authorizes the permittee to construct or modify and to operate the permitted source in the location(s) listed in the Notification of Coverage for that permitted source.
(iv) Liability. This permit by rule does not release the permittee from any liability for compliance with other applicable federal and tribal environmental laws and regulations, including the CAA.
(v) Severability. The provisions of this permit by rule are severable. If any portion of this permit by rule is held invalid, the remaining terms and conditions of this permit by rule shall remain valid and in force.
(vi) Compliance. The permittee must comply with all provisions of this permit by rule, including emission limitations that apply to the affected emissions units at the permitted source. Noncompliance with any permit provision is a violation of this permit by rule and may constitute a violation of CAA; is grounds for an enforcement action; and is grounds for the reviewing authority to revoke and terminate the permitted source's coverage under this permit by rule.
(vii) National Ambient Air Quality Standards (NAAQS)/Prevention of Significant Deterioration (PSD) Protection. The permitted source must not cause or contribute to a NAAQS violation or, in an attainment area, must not cause or contribute to a PSD increment violation.
(viii) Unavailable defense. It is not a defense for the permittee in an enforcement action that it would have been necessary to halt or reduce the permitted activity in order to maintain compliance with the provisions of this permit by rule.
(ix) Property rights. This permit by rule does not convey any property rights of any sort or any exclusive privilege.
(x) Information requests. You, as the permittee, shall furnish to the reviewing authority, within 30 days unless another timeframe is specified by the EPA, any information that the reviewing authority may request in writing to determine whether cause exists for revising, revoking and reissuing, or terminating coverage under the permit by rule or to determine compliance with the permit by rule. For any such information claimed to be confidential, the permittee must submit a claim of confidentiality in accordance with 40 CFR part 2 subpart B.
(xi) Inspection and entry. Upon presentation of proper credentials, the permittee must allow a representative of the reviewing authority to:
1. (A) Enter upon the premises where a permitted source is located or emissions-related activity is conducted or where records are required to be kept under the conditions of the permit by rule;
2. (B) Have access to and copy, at reasonable times, any records that are required to be kept under the conditions of the permit by rule;
3. (C) Inspect, during normal business hours or while the permitted source is in operation, any facilities, equipment (including monitoring and air pollution control equipment), practices or operations regulated or required under the permit by rule;
4. (D) Sample or monitor, at reasonable times, substances or parameters for the purpose of assuring compliance with the permit by rule or other applicable requirements; and
5. (E) Record any inspection by use of written, electronic, magnetic and photographic media.
(xii) Posting of coverage. The most current Notification of Coverage for the permitted source, must be posted prominently at the facility, and each affected emissions unit and any associated air pollution control technology must be labeled with the identification number listed in the Notification of Coverage for that permitted source.
(xiii) Duty to obtain source-specific permit. If the reviewing authority intends to terminate a permitted source's coverage under this permit by rule for cause as provided in § 49.164(d)(6), then the permittee shall apply for and obtain a source-specific as required by the reviewing authority.
(xiv) Credible evidence. For the purpose of establishing whether the permittee violated or is in violation of any requirement of this permit by rule, nothing shall preclude the use, including the exclusive use, of any credible evidence or information relevant to whether a permitted source would have been in compliance with applicable requirements if the permittee had performed the appropriate performance or compliance test or procedure.
(2) Emission limitations and standards.
1. (i) The permittee shall install, maintain, and operate each affected emissions unit, including any associated air pollution control equipment, in a manner consistent with good air pollution control practices for minimizing emissions of NSR regulated pollutants and considering the manufacturer's recommended operating procedures at all times, including periods of startup, shutdown, maintenance and malfunction. The reviewing authority will determine whether the permittee is using acceptable operating and maintenance procedures based on information available to the reviewing authority which may include, but is not limited to, monitoring results, opacity observations, review of operating and maintenance procedures, and inspection of the permitted source.
2. (ii) GDFs located in an ozone attainment, unclassifiable or attainment/unclassifiable area or a marginal or moderate ozone nonattainment area shall limit throughput of gasoline to less than 25,000,000 gallons per year based on a 12-month rolling total.
3. (iii) GDFs located in a serious, severe or extreme ozone nonattainment area shall limit throughput of gasoline to less than 8,000,000 gallons per year based on a 12-month rolling total.
4. (iv) You must ensure gasoline is handled in a manner that will minimize vapor releases to the atmosphere. The measures to be taken include:
  1. (A) Minimizing gasoline spills;
  2. (B) Cleaning up spills as expeditiously as practicable. The spill bucket shall be free from standing liquid and debris;
  3. (C) Covering all open gasoline containers and all gasoline storage tank fill-pipes with a gasketed seal when not in use (all portable gasoline containers that meet the requirements of 40 CFR part 59, subpart F meet this requirement);
  4. (D) Minimizing gasoline sent to open waste collection systems that collect and transport gasoline to reclamation and recycling devices, such as oil/water separators; and
  5. (E) To the extent practicable, any other actions necessary to minimize vapor releases to the atmosphere.
5. (v) Except as specified in paragraph (d)(2)(v)(B) of this section, you must only load gasoline into storage tanks at your facility by utilizing submerged filling, and as specified in this condition. The applicable distances shall be measured from the point in the opening of the submerged fill pipe that is the greatest distance from the bottom of the storage tank.
  1. (A) Submerged fill pipes must be no more than 6 inches from the bottom of the tank.
  2. (B) Submerged fill pipes not meeting the specifications paragraph (d)(2)(v)(A) of this section are allowed if the owner or operator can demonstrate that the liquid level in the tank is always above the entire opening of the fill pipe. Documentation providing such demonstration must be made available onsite for inspection by the reviewing authority.
6. (vi) Except as provided in paragraph (d)(2)(viii) of this section, each new or modified gasoline storage tank constructed must be equipped with a Stage I dual-point vapor balance system.
7. (vii) Except as provided in paragraph (d)(2)(viii) of this section, each Stage I dual-point vapor balance system on your gasoline storage tank must meet the design criteria and management practices in paragraph (e) of this section, as applicable.
8. (viii) The affected emissions units listed below are not required to comply with the control requirements in paragraphs (d)(2)(vi) and (vii) of this section, but must comply with the requirements in paragraph (d)(2)(v) of this section.
  1. (A) Gasoline storage tanks with a capacity of less than 250 gallons.
  2. (B) Gasoline storage tanks with a capacity of less than 2,000 gallons.
  3. (C) Gasoline storage tanks equipped with floating roofs, or the equivalent.
9. (ix) Cargo tanks unloading at GDFs must not unload gasoline into a storage tank at a GDF unless the following management practices are met:
  1. (A) All hoses in the vapor balance system are properly connected;
  2. (B) The adapters or couplers that attach to the vapor line on the storage tank have closures that seal upon disconnect;
  3. (C) All vapor return hoses, couplers, and adapters used in gasoline delivery are vapor-tight;
  4. (D) All tank truck vapor return equipment is compatible in size and forms a vapor-tight connection with the vapor balance equipment on the GDF storage tank;
  5. (E) All hatches on the tank truck are closed and securely fastened; and
  6. (F) The filling of storage tanks at GDF shall be limited to unloading from vapor-tight gasoline cargo tanks.
10. (x) Each emergency engine shall:
  1. (A) Be equipped with a non-resettable hour meter;
  2. (B) If using fuel oil, use diesel or biodiesel containing no more than 15 ppm (0.0015 percent) sulfur;
  3. (C) Meet the following certification requirement for compression ignition emergency engines: for model year 2006 and later engines, the engine shall be certified to the standards in 40 CFR part 89.
  4. (D) Meet the following certification requirements for spark ignition emergency engines manufactured on or after January 1, 2009:
  5. (1) Engines greater than 50 hp and less than 130 hp shall be certified to the Phase I standards in 40 CFR 90.103; and
  6. (2) Engines greater than or equal to 130 hp shall be certified to the standards in 40 CFR 1048.
  7. (E) If not required to be certified to the standards in paragraph (d)(2)(x)(C) or (D) of this section:
    (1) Follow the manufacturer's emission-related operation and maintenance instructions or develop your own maintenance plan which must provide to the extent practicable for the maintenance and operation of the engine in a manner consistent with good air pollution control practice for minimizing emissions;
    (2) Change oil and filter and inspect every hose and belt every 500 hours of operation or annually, whichever comes first; and
    (3) Inspect air cleaner or spark plugs, as applicable, every 1,000 hours of operation, or annually, whichever comes first.
(3) Monitoring and testing requirements.
1. (i) For each vapor balance system, the permittee shall perform an initial performance test as prescribed in paragraph (e) of this section and every 3 years thereafter. The performance test shall be conducted within 60 days after achieving the maximum production rate at which the permitted source will operate the affected vapor balance system, but not later than 180 days after the first day of operation after the reviewing authority receives the completed Notification of Coverage.
2. (ii) The permittee shall monitor monthly gasoline throughput in gallons.
3. (iii) The permittee shall perform weekly inspections of the vapor control recovery system(s), all pumps, compressors, pipes, hoses, mechanical seals, or other equipment storing, handling, conveying, or controlling VOCs. For sources located in extreme ozone nonattainment areas, these equipment inspections shall be performed daily. The inspections shall be used to determine whether all equipment is in good working order according to any available manufacturer's recommendations and good engineering practices.
(4) Recordkeeping requirements.
1. (i) The permittee shall maintain all records required to be kept onsite by this permit by rule for at least 5 years from the date of origin, unless otherwise stated.
2. (ii) The Notification of Coverage and all documentation supporting that application shall be maintained by the permittee for the duration of time the affected emissions unit(s) is covered under this permit by rule.
3. (iii) The permittee shall maintain records of each inspection required by paragraph (d)(3)(iii) of this section. The records shall include a log of:
  1. (A) Identification of the devices inspected;
  2. (B) The date of the inspection;
  3. (C) The results of each inspection;
  4. (D) Any corrective actions taken as a result of the inspection; and
  5. (E) The results of any corrective actions taken.
4. (iv) For each emergency engine, the permittee shall maintain a log of all maintenance activities conducted and a log of the hours of operation including the date, time, duration, and reason for use.
5. (v) The permittee shall maintain records on a monthly basis of the fuel throughput and the 12-month rolling total. The 12-month rolling total is defined as the sum of the fuel throughput during the current month and the fuel throughput for the previous 11 months.
6. (vi) The results of each performance test conducted pursuant to § 49.164(d)(3)(i) shall be recorded. At a minimum, the permittee shall maintain records of:
  1. (A) The date of each test;
  2. (B) Each test plan;
  3. (C) Any documentation required to approve an alternate test method;
  4. (D) Test conditions;
  5. (E) The results of each test; and
  6. (F) The name of the company or entity conducting the analysis.
(5) Notification and reporting requirements—(i) Notification of construction or modification, and operations. The permittee shall submit a written or electronic notice to the reviewing authority within 30 days from when the permittee begins actual construction, and within 30 days from when the permittee begins initial operations or resumes operation after a modification.
(ii) Notification of change in ownership or operator. If the permitted source changes ownership or operator, then the new owner must submit a written or electronic notice to the reviewing authority within 90 days before or after the change in ownership is effective. In the notice, the new permittee must provide the reviewing authority a written agreement containing a specific date for transfer of ownership, and an effective date on which the new owner assumes partial and/or full coverage and liability under this permit by rule. The submittal must identify the previous owner, and update the name, street address, mailing address, contact information, and any other information about the permitted source if it would change as a result of the change of ownership. The current owner shall ensure that the permitted source remains in compliance with the permit by rule until any such transfer of ownership is effective.
(iii) Notification of closure. The permittee must submit a report of any permanent or indefinite closure to the reviewing authority in writing within 90 days after the cessation of all operations at the permitted source. The notification must identify the owner, the current location, and the last operating location of the permitted source. It is not necessary to submit a report of closure for regular, seasonal closures.
(iv) Annual reports. The permittee shall submit an annual report on or before March 15 of each calendar year to the reviewing authority. The annual report shall cover the period from January 1 to December 31 of the previous calendar year and shall include:
1. (A) An evaluation of the permitted source's compliance status with the emission limitations and standards in paragraph (d)(2) of this section;
2. (B) Summaries of the required monitoring and recordkeeping in paragraphs (d)(3) and (4) of this section; and
3. (C) Summaries of deviation reports submitted pursuant to paragraph (d)(5)(v) of this section.
(v) Deviation reports. The permittee shall promptly report to the reviewing authority any deviations as defined at 40 CFR 71.6(a)(3)(iii)(C) from the permit by rule requirements including deviations attributable to upset conditions. (For the purposes of this permit by rule, promptly shall be defined to mean: at the time the annual report in paragraph (d)(5)(iv) of this section is submitted.) Deviation reports shall include:
1. (A) The identity of affected emissions unit where the deviation occurred;
2. (B) The nature of the deviation;
3. (C) The length of time of the deviation;
4. (D) The probable cause of the deviation; and
5. (E) Any corrective actions or preventive measures taken as a result of the deviation to minimize emissions from the deviation and to prevent future deviations.
(vi) Performance test reports. The permittee shall submit a test report to the reviewing authority within 45 days after the completion of any required performance test. At a minimum, the test report shall include:
1. (A) A description of the affected emissions unit and sampling location(s);
2. (B) The time and date of each test;
3. (C) A summary of test results, reported in units consistent with the applicable standard;
4. (D) A description of the test methods and quality assurance procedures used;
5. (E) A summary of any deviations from the proposed test plan and justification for why the deviation(s) was necessary;
6. (F) Operating parameters of the affected emissions unit and control equipment during each test run;
7. (G) Sample calculations of equations used to determine test results in the appropriate units; and
8. (H) The name of the company or entity performing the analysis.
(vii) Reporting and notification address.The permittee shall send all required reports to the reviewing authority at the mailing address specified in paragraph (f) of this section.
(viii) Signature verifying truth, accuracy and completeness. All reports required by this permit by rule shall be signed by a responsible official as to the truth, accuracy and completeness of the information. The report must state that, based on information and belief formed after reasonable inquiry, the statements and information are true, accurate, and complete. If the permittee discovers that any reports or notification submitted to the reviewing authority contain false, inaccurate, or incomplete information, the permittee shall notify the reviewing authority immediately and correct or amend the report as soon as practicable.
(6) Changes to this permit by rule—(i) Revising, reopening, revoking and reissuing, or terminating for cause. The permit by rule may be revised, reopened, revoked and reissued, or terminated for cause. The filing of a request by the permittee for a permit revision, revocation and re-issuance, or termination, or of a notification of planned changes or anticipated noncompliance does not stay any permit by rule condition. This provision also applies to the documents incorporated by reference.
(ii) Terminating coverage under this permit by rule. The reviewing authority may terminate coverage under this permit by rule, and thereby terminate that permittee's authorization to construct or modify, and that permitted source's authorization to operate under this permit by rule for cause as defined in paragraph (b) of this section. The reviewing authority may provide the permittee with notice of the intent to terminate, and delay the effective date of the termination to allow the permittee to obtain a source specific permit as required by the reviewing authority.
(iii) Permit becomes invalid. Authority to construct and operate under this permit by rule becomes invalid if the permittee does not commence construction within 18 months after the Notification of Coverage is received by the reviewing authority, if the permittee discontinues construction for a period of 18 months or more, or if the permittee does not complete construction within a reasonable time. The reviewing authority may extend the 18-month period upon a satisfactory showing that an extension is justified according to 40 CFR 49.156(e)(8).
(e) Vapor balance system design criteria, management practices, and performance testing.
1. (1) Design criteria and management practices for each vapor balance system:
  1. (i) All vapor connections and lines on the storage tank(s) shall be equipped with closures that seal upon disconnect.
  2. (ii) The vapor line from the gasoline storage tank to the gasoline cargo tank shall be vapor-tight.
  3. (iii) The vapor balance system shall be designed such that the pressure in the tank truck does not exceed 18 inches water pressure or 5.9 inches water vacuum during product transfer.
  4. (iv) The vapor recovery and product adaptors, and the method of connection with the delivery elbow, shall be designed so as to prevent the over-tightening or loosening of fittings during normal delivery operations.
  5. (v) If a gauge well separate from the fill tube is used, it shall be provided with a submerged drop tube that extends no more than 6 inches from the bottom of the storage tank.
  6. (vi) Liquid fill connections for all systems shall be equipped with vapor-tight caps.
  7. (vii) Pressure/vacuum (PV) vent valves shall be installed on the storage tank vent pipes. The pressure specifications for PV vent valves shall be: a positive pressure setting of 2.5 to 6.0 inches of water and a negative pressure setting of 6.0 to 10.0 inches of water. The total leak rate of all PV vent valves at an affected facility, including connections, shall not exceed 0.17 cubic foot per hour at a pressure of 2.0 inches of water and 0.63 cubic foot per hour at a vacuum of 4 inches of water.
  8. (viii) The vapor balance system shall be capable of meeting the static pressure performance requirement of the following equation: Pf = 2e−500.887/v, where: Pf = minimum allowable final pressure, inches of water, v = total ullage affected by the test, gallons, e = dimensionless constant equal to approximately 2.718, 2 = the initial pressure, inches water.
  9. (ix) For aboveground storage tanks (ASTs) with a capacity greater than 250 gallons and located at a GDF in a serious, severe, or extreme ozone nonattainment area the permittee shall also:
    1. (A) Limit standing loss emissions to less than or equal to 0.57 lbs VOC per 1,000 gallons ullage per day (lbs/1,000 gallons/day), for newly installed tanks.
    2. (B) Limit standing loss emissions to less than or equal to 2.26 lbs VOC per 1,000 gallons ullage per day (lbs/1,000 gallons/day), for modified or reconstructed tanks.
2. (2) Vapor balance system performance testing:
  1. (i) The permittee shall conduct performance testing to demonstrate compliance with the leak rate and cracking pressure requirements, specified in paragraph (e)(1)(vii) of this section, for pressure-vacuum vent valves installed on your gasoline storage tanks as follows:
    1. (A) According to a test plan submitted at least 30 days in advance of the test date to the reviewing authority; and
    2. (B) Using California Air Resources Board Vapor Recovery Test Procedure TP-201.1E,—Leak Rate and Cracking Pressure of Pressure/Vacuum Vent Valves, adopted October 8, 2003 (see 40 CFR 63.14).
  2. (ii) The permittee shall conduct performance testing to demonstrate compliance with the static pressure performance requirement, specified in paragraph (e)(1)(viii) of this section, for each vapor balance system by conducting a static pressure test on each gasoline storage tank as follows:
    1. (A) According to a test plan submitted at least 30 days in advance of the test date to the reviewing authority;
    2. (B) Using California Air Resources Board Vapor Recovery Test Procedure TP-201.3,—Determination of 2-Inch WC Static Pressure Performance of Vapor Recovery Systems of Dispensing Facilities, adopted April 12, 1996, and amended March 17, 1999 (see 40 CFR 63.14) or Bay Area Air Quality Management District Source Test Procedure ST-30—Static Pressure Integrity Test—Underground Storage Tanks, adopted November 30, 1983, and amended December 21, 1994 (see 40 CFR 63.14); and
  3. (iii) For ASTs subject to § 49.164(e)(1)(ix), the ASTs shall be California Air Resources Board certified AST for Standing Loss Control per Vapor Recovery Test Procedures TP-206.1 or TP-206.2.

(f) List of reviewing authorities, and areas of coverage.

Table 1—List of Reviewing Authorities, and Areas of Coverage
EPA region	Address for notification of coverage	Address for all other notification and reports	Area covered	Phone number
Region I	EPA New England, 5 Post Office Square, Suite 100, Mail Code OEP05-2, Boston, MA 02109-3912	EPA New England, 5 Post Office Square, Suite 100, Mail Code OES04-2, Boston, MA 02109-3912	Connecticut, Maine, Massachusetts, New Hampshire, Rhode Island, and Vermont	888-372-7341617-918-1111
Region II	Chief, Air Programs Branch, Clean Air and Sustainability Division, EPA Region 2, 290 Broadway, 25th Floor, New York, NY 10007-1866	Chief, Air Compliance Branch, Division of Enforcement and Compliance Assistance, EPA Region 2, 290 Broadway, 21st Floor, New York, NY 10007-1866	New Jersey, New York, Puerto Rico, and Virgin Islands	877-251-4575
Region III	Office of Permits and Air Toxics, 3AP10, EPA Region 3, 1650 Arch Street, Philadelphia, PA 19103	Office of Air Enforcement and Compliance Assurance, 3AP20, EPA Region 3, 1650 Arch Street, Philadelphia, PA 19103	Delaware, District of Columbia, Maryland, Pennsylvania, Virginia, and West Virginia	800-438-2474215-814-5000
Region IV	Chief, Air Permits Section, EPA Region 4 APTMD, 61 Forsyth Street, Atlanta, GA 30303	Chief, Air & EPCRA Enforcement Branch, EPA Region 4 APTMD, 61 Forsyth Street, SW, Atlanta, GA 30303	Alabama, Florida, Georgia, Kentucky, Mississippi, North Carolina, South Carolina, and Tennessee	800-241-1754404-562-9000
Region V	Air Permits Section, Air Programs Branch (AR-18J), EPA Region 5, 77 West Jackson Blvd, Chicago, IL 60604	Air Enforcement and Compliance Assurance Branch (AE-17J), Air and Radiation Division, EPA Region 5, 77 West Jackson Blvd, Chicago, IL 60604	Illinois, Indiana, Michigan, Minnesota, Ohio, and Wisconsin	800-621-8431312-353-2000
Region VI	Air and Radiation Division, EPA Region 6, 1201 Elm Street, Suite 500, Mail Code 6AR Dallas, Texas 75270-2102	Compliance and Enforcement Correspondence: Enforcement and Compliance Assurance Division, 1201 Elm Street, Suite 500, Mail Code 6ECD, Dallas, Texas 75270-2102	Arkansas, Louisiana, New Mexico, Oklahoma, and Texas	800-887-6063 or 214-665-2760
Region VII	Chief, Air Permitting & Compliance Branch, EPA Region 7, 11201 Renner Blvd, Lenexa, KS 66219	Chief, Air Permitting & Compliance Branch, EPA Region 7, 11201 Renner Blvd, Lenexa, KS 66219	Iowa, Kansas, Missouri, and Nebraska	800-223-0425913-551-7003
Region VIII	U.S. Environmental Protection Agency, Region 8, Office of Partnerships and Regulatory Assistance, Tribal Air Permitting Program, 8P-AR, 1595 Wynkoop Street, Denver, CO 80202	U.S. Environmental Protection Agency, Region 8, Office of Enforcement, Compliance & Environmental Justice, Air Toxics and Technical Enforcement Program, 8ENF-AT, 1595 Wynkoop Street, Denver, CO 80202	Colorado, Montana, North Dakota, South Dakota, Utah, and Wyoming	800-227-8917303-312-6312
Region IX	Chief, Permits Office (Air-3), Air Division, EPA Region 9, 75 Hawthorne St, San Francisco, CA 94105	Enforcement Division Director, Attn: Air & TRI Section (ENF-2-1), EPA Region 9, 75 Hawthorne St, San Francisco, CA 94105	American Samoa, Arizona, California, Guam, Hawaii, Navajo Nation Nevada, and Northern Mariana Islands	866-EPA-9378415-947-8000
Region X	Tribal Air Permits Coordinator, U.S. EPA, Region 10, AWT-150, 1200 Sixth Avenue, Suite 900, Seattle, WA 98101	Tribal Air Permits Coordinator, U.S. EPA, Region 10, AWT-150, 1200 Sixth Avenue, Suite 900, Seattle, WA 98101	Alaska, Idaho, Oregon, and Washington	800-424-4372206-553-1200

[80 FR 25102, May 1, 2015, as amended at 84 FR 44227, Aug. 23, 2019]