adeq minor source air permit · adeq minor source air permit permit no. : 672-ar-7 ... 40 cfr part...

ADEQ MINOR SOURCE

AIR PERMIT

Permit No. : 672-AR-7

IS ISSUED TO:

Magellan Terminals Holdings, L.P. - North Little Rock - South Terminal

2725 Central Airport Road North Little Rock, AR 72117

Pulaski County AFIN: 60-00574

THIS PERMIT IS THE ABOVE REFERENCED PERMITTEE’S AUTHORITY TO CONSTRUCT, MODIFY, OPERATE, AND/OR MAINTAIN THE EQUIPMENT AND/OR FACILITY IN THE MANNER AS SET FORTH IN THE DEPARTMENT’S MINOR SOURCE AIR PERMIT AND THE APPLICATION. THIS PERMIT IS ISSUED PURSUANT TO THE PROVISIONS OF THE ARKANSAS WATER AND AIR POLLUTION CONTROL ACT (ARK. CODE ANN. SEC. 8-4-101 ET SEQ.) AND THE REGULATIONS PROMULGATED THEREUNDER, AND IS SUBJECT TO ALL LIMITS AND CONDITIONS CONTAINED HEREIN. Signed: Michael Bonds Date Chief, Air Division

Error! Reference source not found. Permit #: Error! Reference source not found. AFIN: Error! Reference source not found. Table of Contents Section I: FACILITY INFORMATION........................................................................................ 4 Section II: INTRODUCTION........................................................................................................ 5

Summary of Permit Activity....................................................................................................... 5 Process Description..................................................................................................................... 5 Regulations ................................................................................................................................. 5 Total Allowable Emissions ......................................................................................................... 7

Section III: PERMIT HISTORY ................................................................................................... 8 Section IV: EMISSION UNIT INFORMATION.......................................................................... 9

Specific Conditions..................................................................................................................... 9 NSPS Conditions ...................................................................................................................... 15

Section V: INSIGNIFICANT ACTIVITIES ................................................................................24 Section VI: GENERAL CONDITIONS ...................................................................................... 25 Appendix A Appendix B

2

Error! Reference source not found. Permit #: Error! Reference source not found. AFIN: Error! Reference source not found. List of Acronyms and Abbreviations

A.C.A. Arkansas Code Annotated

AFIN ADEQ Facility Identification Number

CFR Code of Federal Regulations

CO Carbon Monoxide

HAP Hazardous Air Pollutant

lb/hr Pound Per Hour

No. Number

NOx Nitrogen Oxide

PM Particulate Matter

PM10 Particulate Matter Smaller Than Ten Microns

SO2 Sulfur Dioxide

Tpy Tons Per Year

UTM Universal Transverse Mercator

VOC Volatile Organic Compound

3

Error! Reference source not found. Permit #: Error! Reference source not found. AFIN: Error! Reference source not found.

Section I: FACILITY INFORMATION

PERMITTEE: Magellan Terminals Holdings, L.P. - North Little Rock -

South Terminal

AFIN: 60-00574

PERMIT NUMBER: 672-AR-7

FACILITY ADDRESS: 2725 Central Airport Road North Little Rock, AR 72117

MAILING ADDRESS: Environmental Department P.O. Box 22186 MD 27-3

Tulsa, OK 74121-2186

COUNTY: Pulaski

CONTACT POSITION: Stacy Colpitt

TELEPHONE NUMBER: (918) 574-7726

REVIEWING ENGINEER: Ann Sudmeyer

UTM North South (Y): Zone 15: 3848.4

UTM East West (X): Zone 15: 475.4

4


Section II: INTRODUCTION

Summary of Permit Activity Magellan Terminals Holdings, L.P. – North Little Rock – South Terminal located at 2725 Central Airport Road, North Little Rock, Pulaski County, Arkansas, operates a bulk fuel storage and distribution facility. This de minimis permit modification is necessary to make piping modifications to the existing loading rack supply lines, install one new diesel loading arm at the loading rack, relocate the gasoline meters to provide options for each grade of gasoline at the existing gasoline loading bays, and provide for additional red dye (additive) injection capability at the diesel loading arms. This modification will add eleven additional valves and 41 additional flange sets. With this modification, the facility is subject to 40 CFR Part 60, Subpart XX – Standards of Performance for Bulk Gasoline Terminals. The total permitted emission rate increase of 0.01 tons per year ethyl benzene is due to rounding. In addition, this permitting action updates the permit to include the NSPS Subpart Kb requirements for SN-10, and the requirements of §19.1005(D)(1).

Process Description

Various grades of gasoline and distillate are delivered to the facility by the Texas Eastern Product Pipeline Company pipeline. Each product is bottom fed into one of six bulk, above ground liquid fuel storage tanks (SNs 02-05, 07, and 10). Prior to distribution, additives can be blended with the fuels. The products are pumped to the loading rack (SN-01) through below ground piping. At the loading rack, tank trucks are bottom filled. The off gases are routed to the vapor disposal unit for destruction. A transmix tank (SN-06) is used for storing the interface between the pipeline products that are received at the facility. The facility operates an oil water separator to process rainwater and any petroleum that is spilled at the loading rack. Petroleum contaminated water is removed and held in a fixed roof holding tank (SN-08), while the water is discharged outside the berm through a permitted NPDES outfall. Because spills occur infrequently, the emissions from spills have been assumed to be negligible.

Regulations The storage tanks (SN-02 through SN-08) are not subject to 40 CFR Part 60 Subpart K-Standards of Performance for Petroleum Liquids for Which Construction, Reconstruction, or Modification Commenced after June 11, 1973, and Prior to May 19, 1978; 40 CFR Part 60 Ka - Standards of Performance for Storage Vessels for Petroleum Liquids for Which Construction, Reconstruction, or Modification Commenced after May 19, 1978, and Prior to July 23, 1984; or 40 CFR Part 60 Kb - Standards of Performance for Volatile Organic Liquid Storage Vessels (Including Petroleum Liquid Storage Vessels) for Which Construction, Reconstruction, or Modification Commenced after July 23, 1984, because these tanks were constructed prior to June 11, 1973.

5

Error! Reference source not found. Permit #: Error! Reference source not found. AFIN: Error! Reference source not found. Tank 508 (SN-10) is subject to 40 CFR Part 60 Kb - Standards of Performance for Volatile Organic Liquid Storage Vessels (Including Petroleum Liquid Storage Vessels) for Which Construction, Reconstruction, or Modification Commenced after July 23, 1984. This tank has a capacity greater than 151 m3 and stores organic liquids with a vapor pressure less than 76.6 kPa. The loading rack (SN-01) at this facility is subject to 40 CFR Part 60, Subpart XX - Standards of Performance for Bulk Gasoline Terminals because the loading rack will be modified by the addition of one new diesel loading arm. This new diesel loading arm has the potential to deliver to gasoline tank trucks as defined by this regulation. This facility is exempt from 40 CFR Part 63, Subpart R - National Emission Standard for Gasoline Distribution Facilities (Bulk Gasoline Terminals and Pipeline Breakout Stations) pursuant to Section 63.420(a)(2). This facility will be regulated under the Air Code, State Implementation Plan (SIP), New Source Performance Standards (NSPS). The following table contains the regulations applicable to this permit.

Regulations

Arkansas Air Pollution Control Code, Regulation 18, effective February 15, 1999 Regulations of the Arkansas Plan of Implementation for Air Pollution Control, Regulation 19, effective February 15, 1999 40 CFR Part 60, Subpart Kb - Standards of Performance for Volatile Organic Liquid Storage Vessels (Including Petroleum Liquid Storage Vessels) for Which Construction, Reconstruction, or Modification Commenced after July 23, 1984 40 CFR Part 60, Subpart XX - Standards of Performance for Bulk Gasoline Terminals

6

Error! Reference source not found. Permit #: Error! Reference source not found. AFIN: Error! Reference source not found. The following table is a summary of emissions from the facility. This table, in itself, is not an enforceable condition of the permit.

Total Allowable Emissions

TOTAL ALLOWABLE EMISSIONS

Emission Rates Pollutant

lb/hr tpy

VOC 53.7 75.2

CO 18.1 24.9

NOx 7.3 10.0

Benzene 0.71 0.84

Ethyl Benzene 0.13 0.15

Hexane 1.01 1.32

Toluene 0.79 1.04 2,2,4

Trimethylpentane 0.43 0.61

Xylene 0.35 0.44

7


Section III: PERMIT HISTORY Permit #672-A was issued to Chevron U.S.A. Products Company on May 22, 1981. Permit #672-AR-1 was issued to Chevron U.S.A. Products Company on May 11, 1993. Permit #672-AR-2 was issued to North Little Rock Terminaling Company on July 9, 1993. This permit was issued because of the transfer of ownership from Chevron U.S.A. Products Company. Permit #672-AR-3 was issued to COZ Terminaling, Inc. - North Little Rock South on October 17, 1996, to allow the facility to increase the throughput of gasoline and diesel. Permit #672-AR-4 was issued to TransMontaigne Terminaling Inc., South Products Terminal (TransMontaigne) on September 3, 1997, to replace the existing McGill Vapor Recovery Unit (VRU) with a more efficient Zinc Vapor Disposal Unit (VDU) and to increase the throughput volumes. Permit #672-AR-5 was issued to TransMontaigne Terminaling Inc., South Products Terminal (TransMontaigne) on December 7, 1998, to allow for installation of a new 120,000 barrel internal floating roof tank (SN-10) to store gasoline or lower vapor pressure products. Geodesic domes were installed on Tank 501 (SN-02), Tank 502 (SN-03), and Tank 503 (SN-04). The emissions from each tank were revised with the updated Tanks Version 3.1. The overall facility throughputs were not changed. Permit #672-AR-6 was issued on June 25, 2002. The facility formally changed its name from TransMontaigne Terminaling Inc., South Products Terminal to Williams Terminals Holdings, L.P. - South Terminal. Also, in this permit modification the potential to emit was revised based upon current emission calculation methodologies and the requirement to track the parameters for determining the emissions screening factor (ET) in Specific Condition 11 of the previous permit by using § 63.420(a)(2) instead of § 63.420(a)(1) of 40 CFR 63, Subpart R. Additionally, the permit was updated to reflect the current permitting format of the Department. Tank 503 (SN-04) was permitted to also allow the storage of gasoline or lower RVP products. The permitted emissions for the criteria pollutants at this facility were 75.2 tpy VOC, 24.9 tpy CO, and 10.0 tpy NOX.

8


Section IV: EMISSION UNIT INFORMATION Specific Conditions 1. The permittee shall not exceed the emission rates set forth in the following table.

[Regulation 19, §19.501 et seq., effective February 15, 1999 and A.C.A. §8-4-203 as referenced by A.C.A. §8-4-304 and §8-4-311]

SN Description Pollutant lb/hr tpy

01

Loading Rack Area (Vapor Combustion

Unit (VCU) formerly known as the

Vapor Disposal Unit (VDU))

VOC CO

NOX

39.0 18.1 7.3

53.6 24.9 10.0

05 Distillate Tank 504

(Fixed Roof, No Control Equipment)

VOC 1.6 1.3

06

Transmix Tank 505 (Internal Floating Roof with Primary

and Secondary Tank Seals)

VOC 0.4 0.9

08 Holding Tank 507 (Fixed Roof, No

Control Equipment) VOC 2.6 1.0

09 Fugitive Equipment Leaks VOC 0.1 0.3

Total Annual Emissions for SN’s 02, 03, 04, 07, and 10 VOC --- 18.1

02

Gasoline or Lower RVP Products Tank

501 (External Floating

Roof with Dome and Primary and

Secondary Tank Seals)

VOC 1.1 ---

9



03





VOC 1.2 ---

04





VOC 1.8 ---

07


506 (Internal Floating Roof with Primary


VOC 2.0 ---

10

Gasoline or Lower RVP

Products Tank 508 (Internal Floating Roof with Primary


VOC 3.9 ---

2. The permittee shall not exceed the emission rates set forth in the following table.

[Regulation 18, §18.801, effective February 15, 1999, and A.C.A. §8-4-203 as referenced by A.C.A. §8-4-304 and §8-4-311]


01

Loading Rack Area (Vapor Combustion

Unit (VCU) formerly known as the

Vapor Disposal Unit (VDU))

Benzene Ethyl Benzene

Hexane Toluene

2,2,4 Trimethylpentane Xylene

0.36 0.04 0.63 0.51 0.32 0.20

0.49 0.06 0.86 0.70 0.43 0.27

10



05 Distillate Tank 504

(Fixed Roof, No Control Equipment)


Hexane Toluene Xylene

0.11 0.01 0.09 0.06 0.03

0.08 0.01 0.09 0.05 0.03

06

Transmix Tank 505 (Internal Floating Roof with Primary



Hexane Toluene


0.02 0.01 0.02 0.01 0.01 0.01

0.04 0.01 0.03 0.02 0.01 0.01

08 Holding Tank 507 (Fixed Roof, No

Control Equipment)


Hexane Toluene


0.11 0.01 0.10 0.07 0.01 0.04

0.04 0.01 0.04 0.03 0.01 0.01

09 Fugitive Equipment Leaks


Hexane Toluene


0.01 0.01 0.01 0.01 0.01 0.01

0.01 0.01 0.01 0.01 0.01 0.01

Total Annual Emissions for SN’s 02, 03, 04, 07, and 10


Hexane Toluene


---

0.18 0.05 0.29 0.23 0.15 0.11

02






Hexane Toluene


0.01 0.01 0.02 0.01 0.01 0.01

---

11



03






Hexane Toluene


0.01 0.01 0.02 0.02 0.01 0.01

---

04






Hexane Toluene


0.02 0.01 0.03 0.02 0.01 0.01

---

07


506 (Internal Floating Roof with Primary



Hexane Toluene


0.02 0.01 0.03 0.03 0.02 0.01

---

10

Gasoline or Lower RVP

Products Tank 508 (Internal Floating Roof with Primary



Hexane Toluene


0.04 0.01 0.06 0.05 0.03 0.02

---

3. The permittee shall not cause or permit the emission of air contaminants, including odors

or water vapor and including an air contaminant whose emission is not otherwise prohibited by Regulation #18, if the emission of the air contaminant constitutes air pollution within the meaning of A.C.A. §8-4-303. [Regulation 18, §18.901 and A.C.A. §8-4-203 as referenced by A.C.A. §8-4-304 and §8-4-311]

4. The permittee shall not conduct operations in such a manner as to unnecessarily cause air contaminants and other pollutants to become airborne. [Regulation 18, §18.801 and A.C.A. §8-4-203 as referenced by A.C.A. §8-4-304 and §8-4-311]

12

Error! Reference source not found. Permit #: Error! Reference source not found. AFIN: Error! Reference source not found. 5. The throughput of gasoline (average vapor pressure of 8.69 psia) or a product with a

documented lower vapor pressure at this facility shall not exceed a total of 595,980,000 gallons during any consecutive 12 month period. [§19.705 of Regulation 19 and A.C.A. §8-4-203 as referenced by §8-4-304 and §8-4-311]

6. The permittee shall maintain monthly records which demonstrate compliance with Specific Condition #5. Records shall be updated by the fifteenth day of the month following the month to which the records pertain. These records shall be kept on site, and shall be made available to Department personnel upon request. [§19.705 of Regulation 19 and A.C.A. §8-4-203 as referenced by §8-4-304 and §8-4-311]

7. The throughput of diesel or a product with a documented lower vapor pressure at this facility shall not exceed 160,020,000 gallons during any consecutive 12 month period. [§19.705 of Regulation 19 and A.C.A. §8-4-203 as referenced by §8-4-304 and §8-4-311]


9. The throughput for the transmix tanks (SN-06) at this facility shall not exceed 6,000,000 gallons during any consecutive 12 month period. [§19.705 of Regulation 19 and A.C.A. §8-4-203 as referenced by §8-4-304 and §8-4-311]


11. In order to ensure compliance with the VOC limitations of this permit, only gasoline (average vapor pressure of 8.69 psia) or a product with a documented lower vapor pressure can be stored in storage tanks SN-02, SN-03, SN-04, SN-07, and SN-10. Gasoline may not be stored in any other tank at this facility. (Note: Gasoline is a component of the contents for transmix Tank 505 (SN-06) and holding tank 507 (SN-08), but since it is included as a mixed product in these tanks, it is not included in the limits of this condition.) Any deviation from this arrangement must be approved by the Department in advance. [§19.705 of Regulation 19 and A.C.A. §8-4-203 as referenced by §8-4-304 and §8-4-311]

12. Gasoline vapors from the vapor control system (SN-01) shall not exceed 10 milligrams per liter of gasoline loaded. [§19.705 of Regulation 19 and A.C.A. §8-4-203 as referenced by §8-4-304 and §8-4-311]

13. Gasoline vapors from the vapor control system (SN-01) shall not exceed 80 milligrams per liter of gasoline loaded. Note: The facility has elected to take a lower limit as specified in Specific Condition #12. [§19.1005(A)(3) of Regulation 19 and A.C.A. §8-4-203 as referenced by §8-4-304 and §8-4-311]

13

Error! Reference source not found. Permit #: Error! Reference source not found. AFIN: Error! Reference source not found. 14. The permittee shall demonstrate compliance with Specific Condition #12 through

compliance with Specific Condition #15. [§19.705 of Regulation 19 and A.C.A. §8-4-203 as referenced by §8-4-304 and §8-4-311]

15. The permittee shall conduct compliance testing for the Vapor Combustion Unit (SN-01). The permittee shall submit a report containing the test results to the address listed below: Arkansas Department of Environmental Quality

Air Division ATTN: Compliance Inspector Supervisor Post Office Box 8913 Little Rock, AR 72219

Testing shall be conducted for VOCs using EPA Reference Method 25a. The VCU was tested for VOC on September 13 and 14, 2000. Testing of the VCU shall be repeated and reported to the Department every three calendar years thereafter. [§19.702 of Regulation 19 and A.C.A. §8-4-203 as referenced by §8-4-304 and §8-4-311]

16. All seals necessary to meet the requirements of (1)(b) and (c) of §19.1005(B) are to be maintained in good operating condition. [§19.705 and §19.1005(B)(2) of Regulation 19 and A.C.A. §8-4-203 as referenced by §8-4-304 and §8-4-311 ]

17. All openings, except stub drains and those related to safety, are to be sealed with suitable closures when not in use. [§19.705 and §19.1005(B)(3) of Regulation 19 and A.C.A. §8-4-203 as referenced by §8-4-304 and §8-4-311]

18. The permittee shall not allow a gasoline tank truck to be filled or emptied at this facility unless the tank truck sustains a pressure change of no more than 750 pascals (3 inches of H2O) in five minutes when pressurized to a gauge pressure of 4,500 pascals (18 inches of H2O) or evacuated to a gauge pressure of 1,500 pascals (6 inches of H2O) during annual testing conducted using a test method approved by the Director and consistent with the test procedures described in Appendix A or C of the OAQPS Guideline Series document, “Control of Organic Compounds Leaks from Gasoline Tank Trucks and Vapor Collection Systems,” EPA-450/2-78-051. The provisions of §19.1005(D)(1)(c) shall not apply to this facility provided the facility does not allow any gasoline tank truck to fill or empty on its premises without providing proof of current certification under the testing requirements of §19.1005(D)(1)(a) and (b). [§19.705 and §19.1005(D)(1) of Regulation 19 and A.C.A. §8-4-203 as referenced by §8-4-304 and §8-4-311]

19. The Vapor Combustion Unit (VCU) and all emissions control equipment associated with this facility shall be maintained and operated in serviceable condition as prescribed by the manufacturer during loading of the tank trucks. Failure to use the VCU during loading of the tank trucks shall be in violation of this permit. [§19.303 of Regulation 19 and A.C.A. §8-4-203 as referenced by §8-4-304 and §8-4-311]

20. The permittee shall operate the Vapor Combustion Unit (VCU) in a manner that prevents gauge pressure from exceeding 4,500 pascals (18 inches of water) and vacuum from exceeding 1,500 Pascals (6 inches of water) in the gasoline tank truck. [§19.705 and §19.1005(D)(2)(a)(i) of Regulation 19 and A.C.A. §8-4-203 as referenced by §8-4-304 and §8-4-311]

14

Error! Reference source not found. Permit #: Error! Reference source not found. AFIN: Error! Reference source not found. 21. The permittee shall operate the Vapor Combustion Unit (VCU) in a manner that prevents

a reading equal or greater than 100% of the lower explosive limit (LEL, measured as propane) at 2.5 centimeters from all points on the perimeter of the potential leak source when measured using the specified method referenced in §19.1004(F)(3) during loading and unloading operations at the terminal. In the event that the vapor recovery system exceeds this limit, the equipment shall be repaired and retested within 15 days. [§19.705 and §19.1005(D)(2)(a)(ii) of Regulation 19 and A.C.A. §8-4-203 as referenced by §8-4-304 and §8-4-311]

22. The Vapor Combustion Unit (VCU) shall be operated in a manner that prevents visible liquid leaks during loading and unloading operations at the terminal. [§19.303 and §19.1005(D)(2)(a)(iii) of Regulation 19 and A.C.A. §8-4-203 as referenced by §8-4-304 and §8-4-311]

NSPS Conditions

22. The permittee shall meet all applicable requirements of 40 CFR Part 60, Subpart XX – Standards of Performance for Bulk Gasoline Terminals. [§19.304 of Regulation 19 and 40 CFR Part 60, Subpart XX]

23. Each affected facility shall be equipped with a vapor collection system designed to collect the total organic compounds vapors displaced from tank trucks during product loading. [§19.304 of Regulation 19 and 40 CFR §60.502(a)]

24. The emissions to the atmosphere from the vapor collection system due to the loading of liquid product into gasoline tank trucks are not to exceed 35 milligrams of total organic compounds per liter of gasoline loaded. [§19.304 of Regulation 19 and 40 CFR §60.502(b)]

25. Each vapor collection system shall be designed to prevent any total organic compounds vapors collected at one loading rack from passing to another loading rack. [§19.304 of Regulation 19 and 40 CFR §60.502(d)]

26. Loadings of liquid product into gasoline tank trucks shall be limited to vapor-tight gasoline tank trucks using the following procedures:

(1) The owner or operator shall obtain the vapor tightness documentation described in 40 CFR §60.505(b) for each gasoline tank truck which is to be loaded at the affected facility.

(2) The owner or operator shall require the tank identification number to be recorded as each gasoline tank truck is loaded at the affected facility.

(3) (i) The owner or operator shall cross-check each tank identification number obtained in paragraph (2) of this specific condition with the file of tank vapor tightness documentation within 2 weeks after the corresponding tank is loaded, unless either of the following conditions is maintained:

15


(A) If less than an average of one gasoline tank truck per month over the last 26 weeks is loaded without vapor tightness documentation then the documentation cross-check shall be performed each quarter; or

(B) If less than an average of one gasoline tank truck per month over the last 52 weeks is loaded without vapor tightness documentation then the documentation cross-check shall be performed semiannually.

(ii) If either the quarterly or semiannual cross-check provided in paragraphs (3)(i) (A) through (B) of this specific condition reveals that these conditions were not maintained, the source must return to biweekly monitoring until such time as these conditions are again met.

(4) The terminal owner or operator shall notify the owner or operator of each non-vapor-tight gasoline tank truck loaded at the affected facility within 1 week of the documentation cross-check in paragraph (3) of this specific condition.

(5) The terminal owner or operator shall take steps assuring that the nonvapor-tight gasoline tank truck will not be reloaded at the affected facility until vapor tightness documentation for that tank is obtained.

(6) Alternate procedures to those described in paragraphs (1) through (5) of this specific condition for limiting gasoline tank truck loadings may be used upon application to, and approval by, the Administrator. [§19.304 of Regulation 19 and 40 CFR §60.502(e)]

26. The owner or operator shall act to assure that loadings of gasoline tank trucks at the affected facility are made only into tanks equipped with vapor collection equipment that is compatible with the terminal's vapor collection system. [§19.304 of Regulation 19 and 40 CFR §60.502(f)]

27. The owner or operator shall act to assure that the terminal's and the tank truck's vapor collection systems are connected during each loading of a gasoline tank truck at the affected facility. Examples of actions to accomplish this include training drivers in the hookup procedures and posting visible reminder signs at the affected loading racks. [§19.304 of Regulation 19 and 40 CFR §60.502(g)]

28. The vapor collection and liquid loading equipment shall be designed and operated to prevent gauge pressure in the delivery tank from exceeding 4,500 pascals (450 mm of water) during product loading. This level is not to be exceeded when measured by the procedures specified in 40 CFR §60.503(d). [§19.304 of Regulation 19 and 40 CFR §60.502(h)]

29. No pressure-vacuum vent in the bulk gasoline terminal's vapor collection system shall begin to open at a system pressure less than 4,500 pascals (450 mm of water). [§19.304 of Regulation 19 and 40 CFR §60.502(i)]

16

Error! Reference source not found. Permit #: Error! Reference source not found. AFIN: Error! Reference source not found. 30. Each calendar month, the vapor collection system, the vapor processing system, and each

loading rack handling gasoline shall be inspected during the loading of gasoline tank trucks for total organic compounds liquid or vapor leaks. For purposes of this paragraph, detection methods incorporating sight, sound, or smell are acceptable. Each detection of a leak shall be recorded and the source of the leak repaired within 15 calendar days after it is detected. [§19.304 of Regulation 19 and 40 CFR §60.502(j)]

31. In conducting the performance tests required in 40 CFR §60.8, the owner or operator shall use as reference methods and procedures the test methods in appendix A of 40 CFR Part 60 or other methods and procedures as specified in 40 CFR §60.503, except as provided in 40 CFR §60.8(b). The three-run requirement of 40 CFR §60.8(f) does not apply to 40 CFR Part 60, Subpart XX. [§19.304 of Regulation 19 and 40 CFR §60.503(a)]

32. Immediately before the performance test required to determine compliance with 40 CFR §60.502 (b), (c), and (h), the owner or operator shall use Method 21 to monitor for leakage of vapor all potential sources in the terminal's vapor collection system equipment while a gasoline tank truck is being loaded. The owner or operator shall repair all leaks with readings of 10,000 ppm (as methane) or greater before conducting the performance test. [§19.304 of Regulation 19 and 40 CFR §60.503(b)]

33. The owner or operator shall determine compliance with the standards in 40 CFR §60.502 (b) and (c) as follows:

(1) The performance test shall be 6 hours long during which at least 300,000 liters of gasoline is loaded. If this is not possible, the test may be continued the same day until 300,000 liters of gasoline is loaded or the test may be resumed the next day with another complete 6-hour period. In the latter case, the 300,000-liter criterion need not be met. However, as much as possible, testing should be conducted during the 6-hour period in which the highest throughput normally occurs.

(2) If the vapor processing system is intermittent in operation, the performance test shall begin at a reference vapor holder level and shall end at the same reference point. The test shall include at least two startups and shutdowns of the vapor processor. If this does not occur under automatically controlled operations, the system shall be manually controlled.

(3) The emission rate (E) of total organic compounds shall be computed using the following equation:

where: E=emission rate of total organic compounds, mg/liter of gasoline loaded. Vesi=volume of air-vapor mixture exhausted at each interval “i”, scm. Cei=concentration of total organic compounds at each interval “i”, ppm. L=total volume of gasoline loaded, liters.

17


n=number of testing intervals. i=emission testing interval of 5 minutes. K=density of calibration gas, 1.83×106 for propane and 2.41×106 for butane, mg/scm.

(4) The performance test shall be conducted in intervals of 5 minutes. For each interval “i”, readings from each measurement shall be recorded, and the volume exhausted (Vesi) and the corresponding average total organic compounds concentration (Cei) shall be determined. The sampling system response time shall be considered in determining the average total organic compounds concentration corresponding to the volume exhausted.

(5) The following methods shall be used to determine the volume (Vesi) air-vapor mixture exhausted at each interval:

(i) Method 2B shall be used for combustion vapor processing systems. (ii) Method 2A shall be used for all other vapor processing systems.

(6) Method 25A or 25B shall be used for determining the total organic compounds concentration (Cei) at each interval. The calibration gas shall be either propane or butane. The owner or operator may exclude the methane and ethane content in the exhaust vent by any method (e.g., Method 18) approved by the Administrator.

(7) To determine the volume (L) of gasoline dispensed during the performance test period at all loading racks whose vapor emissions are controlled by the processing system being tested, terminal records or readings from gasoline dispensing meters at each loading rack shall be used. [§19.304 of Regulation 19 and 40 CFR §60.503(c)]

34. The owner or operator shall determine compliance with the standard in 40 CFR §60.502(h) as follows:

(1) A pressure measurement device (liquid manometer, magnehelic gauge, or equivalent instrument), capable of measuring up to 500 mm of water gauge pressure with ±2.5 mm of water precision, shall be calibrated and installed on the terminal's vapor collection system at a pressure tap located as close as possible to the connection with the gasoline tank truck.

(2) During the performance test, the pressure shall be recorded every 5 minutes while a gasoline truck is being loaded; the highest instantaneous pressure that occurs during each loading shall also be recorded. Every loading position must be tested at least once during the performance test. [§19.304 of Regulation 19 and 40 CFR §60.503(d)]

35. The tank truck vapor tightness documentation required under 40 CFR §60.502(e)(1) shall be kept on file at the terminal in a permanent form available for inspection. [§19.304 of Regulation 19 and 40 CFR §60.505(a)]

36. The documentation file for each gasoline tank truck shall be updated at least once per year to reflect current test results as determined by Method 27. This documentation shall

18


include, as a minimum, the following information:

(1) Test title: Gasoline Delivery Tank Pressure Test—EPA Reference Method 27. (2) Tank owner and address. (3) Tank identification number. (4) Testing location. (5) Date of test. (6) Tester name and signature. (7) Witnessing inspector, if any: Name, signature, and affiliation. (8) Test results: Actual pressure change in 5 minutes, mm of water (average for 2 runs). [§19.304 of Regulation 19 and 40 CFR §60.505(b)]

37. A record of each monthly leak inspection required under 40 CFR §60.502(j) shall be kept on file at the terminal for at least 2 years. Inspection records shall include, as a minimum, the following information:

(1) Date of inspection. (2) Findings (may indicate no leaks discovered; or location, nature, and severity of each leak). (3) Leak determination method. (4) Corrective action (date each leak repaired; reasons for any repair interval in excess of 15 days). (5) Inspector name and signature. [§19.304 of Regulation 19 and 40 CFR §60.505(c)]

38. The terminal owner or operator shall keep documentation of all notifications required under 40 CFR §60.502(e)(4) on file at the terminal for at least 2 years. [§19.304 of Regulation 19 and 40 CFR §60.505(d)]

39. As an alternative to keeping records at the terminal of each gasoline cargo tank test result as required in Specific Conditions #35, #37, and #38, an owner or operator may comply with the requirements in either paragraph (1) or (2) of this specific condition.

(1) An electronic copy of each record is instantly available at the terminal.

(i) The copy of each record in paragraph (1) of this specific condition is an exact duplicate image of the original paper record with certifying signatures.

(ii) The permitting authority is notified in writing that each terminal using this alternative is in compliance with paragraph (1) of this specific condition.

(2) For facilities that utilize a terminal automation system to prevent gasoline cargo tanks that do not have valid cargo tank vapor tightness documentation from loading (e.g., via a card lock-out system), a copy of the documentation is made available (e.g., via facsimile) for inspection by permitting authority representatives during the course of a site visit, or within a mutually agreeable time frame.

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(i) The copy of each record in paragraph (2) of this specific condition is an exact duplicate image of the original paper record with certifying signatures.

(ii) The permitting authority is notified in writing that each terminal using this alternative is in compliance with paragraph (2) of this specific condition.

[§19.304 of Regulation 19 and 40 CFR §60.505(e)]

40. SN-10 shall meet all applicable requirements of 40 CFR Part 60, Subpart Kb – Standards of Performance for Volatile Organic Liquid Storage Vessels (Including Petroleum Liquid Storage Vessels) for Which Construction, Reconstruction, or Modification Commenced After July 23, 1984. These requirements include, but are not limited to the following: [§19.304 of Regulation 19 and 40 CFR Part 60, Subpart Kb]

a. SN-10 shall have a fixed roof in combination with an internal floating roof. The internal floating roof shall rest or float on the liquid surface (but not necessarily in complete contact with it) inside a storage vessel that has a fixed roof. The internal floating roof shall be floating on the liquid surface at all times, except during initial fill and during those intervals when the storage vessel is completely emptied or subsequently emptied and refilled. When the roof is resting on the leg supports, the process of filling, emptying, or refilling shall be continuous and shall be accomplished as rapidly as possible. [40 CFR §60.112b(a)(1)(i)]

b. The internal floating roof shall be equipped with two seals mounted one above the other so that each forms a continuous closure that completely covers the space between the wall of the storage vessel and the edge of the internal floating roof. The lower seal may be vapor-mounted, but both must be continuous. [40 CFR §60.112b(a)(1)(ii)(B)]

c. Each opening in a noncontact internal floating roof except for automatic bleeder vents (vacuum breaker vents) and the rim space vents is to provide a projection below the liquid surface. [40 CFR §60.112b(a)(1)(iii)]

d. Each opening in the internal floating roof except for leg sleeves, automatic bleeder vents, rim space vents, column wells, ladder wells, sample wells, and stub drains is to be equipped with a cover or lid which is to be maintained in a closed position at all times (i.e., no visible gap) except when the device is in actual use. The cover or lid shall be equipped with a gasket. Covers on each access hatch and automatic gauge float well shall be bolted except when they are in use. [40 CFR §60.112b(a)(1)(iv)]

e. Automatic bleeder vents shall be equipped with a gasket and are to be closed at all times when the roof is floating except when the roof is being floated off or is being landed on the roof leg supports. [40 CFR §60.112b(a)(1)(v)]

f. Rim space vents shall be equipped with a gasket and are to be set to open only when the internal floating roof is not floating or at the manufacturer's recommended setting. [40 CFR §60.112b(a)(1)(vi)]

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g. Each penetration of the internal floating roof for the purpose of sampling shall be a sample well. The sample well shall have a slit fabric cover that covers at least 90 percent of the opening. [40 CFR §60.112b(a)(1)(vii)]

h. Each penetration of the internal floating roof that allows for passage of a column supporting the fixed roof shall have a flexible fabric sleeve seal or a gasketed sliding cover. [40 CFR §60.112b(a)(1)(viii)]

i. Each penetration of the internal floating roof that allows for passage of a ladder shall have a gasketed sliding cover. [40 CFR §60.112b(a)(1)(ix)]

j. After installing the control equipment required to meet §60.112b(a)(1), the permittee shall visually inspect the internal floating roof, the primary seal, and the secondary seal, prior to filling the storage vessel with VOL. If there are holes, tears, or other openings in the primary seal, the secondary seal, or the seal fabric or defects in the internal floating roof, or both, the owner or operator shall repair the items before filling the storage vessel. [40 CFR §60.113b(a)(1)]

k. The permittee shall: [40 CFR §60.113b(a)(3)]

i. Visually inspect the vessel as specified in §60.113b(a)(4) at least every 5 years; or

ii. Visually inspect the vessel as specified in §60.113b(a)(2).

l. Visually inspect the internal floating roof, the primary seal, the secondary seal, gaskets, slotted membranes and sleeve seals (if any) each time the storage vessel is emptied and degassed. If the internal floating roof has defects, the primary seal has holes, tears, or other openings in the seal or the seal fabric, or the secondary seal has holes, tears, or other openings in the seal or the seal fabric, or the gaskets no longer close off the liquid surfaces from the atmosphere, or the slotted membrane has more than 10 percent open area, the owner or operator shall repair the items as necessary so that none of the conditions specified in this paragraph exist before refilling the storage vessel with VOL. In no event shall inspections conducted in accordance with this provision occur at intervals greater than 10 years in the case of vessels conducting the annual visual inspection as specified in §60.113b(a)(2) and §60.113b(a)(3)(ii) and at intervals no greater than 5 years in the case of vessels specified in §60.113b(a)(3)(i). [40 CFR §60.113b(a)(4)]

21


m. Notify the Administrator in writing at least 30 days prior to the filling or refilling of each storage vessel for which an inspection is required by §60.113b(a)(1) and §60.113b(a)(4) to afford the Administrator the opportunity to have an observer present. If the inspection required by §60.113b(a)(4) is not planned and the owner or operator could not have known about the inspection 30 days in advance or refilling the tank, the owner or operator shall notify the Administrator at least 7 days prior to the refilling of the storage vessel. Notification shall be made by telephone immediately followed by written documentation demonstrating why the inspection was unplanned. Alternatively, this notification including the written documentation may be made in writing and sent by express mail so that it is received by the Administrator at least 7 days prior to the refilling. [40 CFR §60.113b(a)(5)]

n. The owner or operator shall keep records and furnish reports as required by §60.115b(a). The owner or operator shall keep copies of all reports and records required by §60.115b(a) for at least 2 years. [40 CFR §60.115b]

o. After installing control equipment in accordance with §60.112b(a)(1) (fixed roof and internal floating roof), the owner or operator shall meet the following requirements.

i. Furnish the Administrator with a report that describes the control equipment and certifies that the control equipment meets the specifications of §60.112b(a)(1) and §60.113b(a)(1). This report shall be an attachment to the notification required by §60.7(a)(3). [40 CFR §60.115b(a)(1)]

ii. Keep a record of each inspection performed as required by §60.113b (a)(1), (a)(2), (a)(3), and (a)(4). Each record shall identify the storage vessel on which the inspection was performed and shall contain the date the vessel was inspected and the observed condition of each component of the control equipment (seals, internal floating roof, and fittings). [40 CFR §60.115b(a)(2)]

iii. If any of the conditions described in §60.113b(a)(2) are detected during the annual visual inspection required by §60.113b(a)(2), a report shall be furnished to the Administrator within 30 days of the inspection. Each report shall identify the storage vessel, the nature of the defects, and the date the storage vessel was emptied or the nature of and date the repair was made. [40 CFR §60.115b(a)(3)]

iv. After each inspection required by §60.113b(a)(3) that finds holes or tears in the seal or seal fabric, or defects in the internal floating roof, or other control equipment defects listed in §60.113b(a)(3)(ii), a report shall be furnished to the Administrator within 30 days of the inspection. The report shall identify the storage vessel and the reason it did not meet the specifications of §60.112b(a)(1) or §60.113b(a)(3) and list each repair made. [40 CFR §60.115b(a)(4)]

22


p. The owner or operator shall keep copies of all records required by §60.116b, except for the record required by §60.116b(b), for at least 2 years. The record required by §60.116b(b) will be kept for the life of the source. [40 CFR §60.116b(a)]

q. The permittee shall keep readily accessible records showing the dimension of the storage vessel and an analysis showing the capacity of the storage vessel. [40 CFR §60.116b(b)]

r. The permittee shall maintain a record of the VOL stored, the period of storage, and the maximum true vapor pressure of that VOL during the respective storage period. The maximum true vapor pressure is to be determined in accordance with §60.116b(e). [40 CFR §60.116b(c)]

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Section V: INSIGNIFICANT ACTIVITIES The Department deems the following types of activities or emissions as insignificant on the basis of size, emission rate, production rate, or activity in accordance with Group A of the Insignificant Activities list found in Regulation 18 and 19 Appendix A. Insignificant activity emission determinations rely upon the information submitted by the permittee in an application dated March 26, 1998.

Description Category 3 Gasoline and Distillate Additive Tanks - Storage tanks less than

or equal to 10,000 gallons storing organic liquids having a true vapor pressure less than or equal to 0.5 psia, provided that the

aggregate pollutant specific emissions from all such liquid storage tanks listed as insignificant do not exceed 5 tpy of any combination

of HAPs and 10 tpy of any other pollutant.

A-3

The oil/water separator shall be considered insignificant because no enforceable permit conditions are necessary to insure compliance

with any applicable law and that the emissions are less than 5 tpy of any pollutant regulated under this regulation or less than 1 tpy of a

single HAP or 2.5 tpy of any combination of HAPs.

A-13

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Section VI: GENERAL CONDITIONS

1. Any terms or conditions included in this permit that specify and reference Arkansas Pollution Control & Ecology Commission Regulation 18 or the Arkansas Water and Air Pollution Control Act (A.C.A. §8-4-101 et seq.) as the sole origin of and authority for the terms or conditions are not required under the Clean Air Act or any of its applicable requirements, and are not federally enforceable under the Clean Air Act. Arkansas Pollution Control & Ecology Commission Regulation 18 was adopted pursuant to the Arkansas Water and Air Pollution Control Act (A.C.A. §8-4-101 et seq.). Any terms or conditions included in this permit that specify and reference Arkansas Pollution Control & Ecology Commission Regulation 18 or the Arkansas Water and Air Pollution Control Act (A.C.A. §8-4-101 et seq.) as the origin of and authority for the terms or conditions are enforceable under this Arkansas statute.

2. This permit does not relieve the owner or operator of the equipment and/or the facility

from compliance with all applicable provisions of the Arkansas Water and Air Pollution Control Act and the regulations promulgated under the Act. [A.C.A. §8-4-203 as referenced by A.C.A. §8-4-304 and §8-4-311]

3. The permittee will notify the Department in writing within thirty (30) days after

commencement of construction, completion of construction, first operation of equipment and/or facility, and first attainment of the equipment and/or facility target production rate. [Regulation 19, §19.704 and/or A.C.A. §8-4-203 as referenced by A.C.A. §8-4-304 and §8-4-311]

4. Construction or modification must commence within eighteen (18) months from the date

of permit issuance. [Regulation 19, §19.410(B) and/or Regulation 18, §18.309(B) and A.C.A. §8-4-203 as referenced by A.C.A. §8-4-304 and §8-4-311]

5. The permittee must keep records for five years to enable the Department to determine

compliance with the terms of this permit such as hours of operation, throughput, upset conditions, and continuous monitoring data. The Department may use the records, at the discretion of the Department, to determine compliance with the conditions of the permit. [Regulation 19, §19.705 and/or Regulation 18, §18.1004 and A.C.A. §8-4-203 as referenced by A.C.A. §8-4-304 and §8-4-311]

6. A responsible official must certify any reports required by any condition contained in this

permit and submit any reports to the Department at the address below. [Regulation 19, §19.705 and/or Regulation 18, §18.1004 and A.C.A. §8-4-203 as referenced by A.C.A. §8-4-304 and §8-4-311]

Arkansas Department of Environmental Quality Air Division ATTN: Compliance Inspector Supervisor Post Office Box 8913

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Little Rock, AR 72219 7. The permittee will test any equipment scheduled for testing, unless stated in the Specific

Conditions of this permit or by any federally regulated requirements, within the following time frames: (1) newly constructed or modified equipment within sixty (60) days of achieving the maximum production rate, but no later than 180 days after initial start up of the permitted source or (2) existing equipment already operating according to the time frames set forth by the Department. The permittee must notify the Department of the scheduled date of compliance testing at least fifteen (15) days in advance of such test. The permittee must submit compliance test results to the Department within thirty (30) days after the completion of testing. [Regulation 19, §19.702 and/or Regulation 18, §18.1002 and A.C.A. §8-4-203 as referenced by A.C.A. §8-4-304 and §8-4-311]

8. The permittee will provide: [Regulation 19 , §19.702 and/or Regulation 18 , §18.1002

and A.C.A. §8-4-203 as referenced by A.C.A. §8-4-304 and §8-4-311]

a. Sampling ports adequate for applicable test methods b. Safe sampling platforms c. Safe access to sampling platforms d. Utilities for sampling and testing equipment

9. The permittee will operate equipment, control apparatus and emission monitoring

equipment within their design limitations. The permittee will maintain in good condition at all times equipment, control apparatus and emission monitoring equipment. [Regulation 19, §19.303 and/or Regulation 18, §18.1104 and A.C.A. §8-4-203 as referenced by A.C.A. §8-4-304 and §8-4-311]

10. If the permittee exceeds an emission limit established by this permit, the permittee will be

deemed in violation of said permit and will be subject to enforcement action. The Department may forego enforcement action for emissions exceeding any limits established by this permit provided the following requirements are met: [Regulation 19, §19.601 and/or Regulation 18, §18.1101 and A.C.A. §8-4-203 as referenced by A.C.A. §8-4-304 and §8-4-311]

a. The permittee demonstrates to the satisfaction of the Department that the

emissions resulted from an equipment malfunction or upset and are not the result of negligence or improper maintenance, and the permittee took all reasonable measures to immediately minimize or eliminate the excess emissions.

b. The permittee reports the occurrence or upset or breakdown of equipment (by telephone, facsimile, or overnight delivery) to the Department by the end of the next business day after the occurrence or the discovery of the occurrence.

c. The permittee must submit to the Department, within five business days after the occurrence or the discovery of the occurrence, a full, written report of such occurrence, including a statement of all known causes and of the scheduling and nature of the actions to be taken to minimize or eliminate future occurrences,

26


including, but not limited to, action to reduce the frequency of occurrence of such conditions, to minimize the amount by which said limits are exceeded, and to reduce the length of time for which said limits are exceeded. If the information is included in the initial report, the information need not be submitted again.

11. The permittee shall allow representatives of the Department upon the presentation of

credentials: [A.C.A. §8-4-203 as referenced by A.C.A. §8-4-304 and §8-4-311]

a. To enter upon the permittee's premises, or other premises under the control of the permittee, where an air pollutant source is located or in which any records are required to be kept under the terms and conditions of this permit;

b. To have access to and copy any records required to be kept under the terms and conditions of this permit, or the Act;

c. To inspect any monitoring equipment or monitoring method required in this permit;

d. To sample any emission of pollutants; and e. To perform an operation and maintenance inspection of the permitted source.

12. The Department issued this permit in reliance upon the statements and presentations

made in the permit application. The Department has no responsibility for the adequacy or proper functioning of the equipment or control apparatus. [A.C.A. §8-4-203 as referenced by A.C.A. §8-4-304 and §8-4-311]

13. The Department may revoke or modify this permit when, in the judgment of the

Department, such revocation or modification is necessary to comply with the applicable provisions of the Arkansas Water and Air Pollution Control Act and the regulations promulgated the Arkansas Water and Air Pollution Control Act. [Regulation 19, §19.410(A) and/or Regulation 18, §18.309(A) and A.C.A. §8-4-203 as referenced by A.C.A. §8-4-304 and §8-4-311]

14. This permit may be transferred. An applicant for a transfer must submit a written request

for transfer of the permit on a form provided by the Department and submit the disclosure statement required by Arkansas Code Annotated '8 1 106 at least thirty (30) days in advance of the proposed transfer date. The permit will be automatically transferred to the new permittee unless the Department denies the request to transfer within thirty (30) days of the receipt of the disclosure statement. The Department may deny a transfer on the basis of the information revealed in the disclosure statement or other investigation or, deliberate falsification or omission of relevant information. [Regulation 19, §19.407(B) and/or Regulation 18, §18.307(B) and A.C.A. §8-4-203 as referenced by A.C.A. §8-4-304 and §8-4-311]

15. This permit shall be available for inspection on the premises where the control apparatus

is located. [A.C.A. §8-4-203 as referenced by A.C.A. §8-4-304 and §8-4-311]

27

Error! Reference source not found. Permit #: Error! Reference source not found. AFIN: Error! Reference source not found. 16. This permit authorizes only those pollutant emitting activities addressed herein. [A.C.A.

§8-4-203 as referenced by A.C.A. §8-4-304 and §8-4-311] 17. This permit supersedes and voids all previously issued air permits for this facility.

[Regulation 18 and 19 and A.C.A. §8-4-203 as referenced by A.C.A. §8-4-304 and §8-4-311]

18. The permittee must pay all permit fees in accordance with the procedures established in

Regulation No. 9. [A.C.A §8-1-105(c)]

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adeq minor source air permit · adeq minor source air permit permit no. : 672-ar-7 ... 40 cfr part...

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