Outdated Standard Exemptions 98-107, May 12, 1981

Exemption

Clicking on a highlighted number below links you to the standard exemption.

98 | 99 | 100 | 101 | 102 | 103 | 104 | 105 | 106 | 107

98. Any pressure vessel storing carbon compounds composed only of carbon, hydrogen or oxygen provided that:

99. Any pressure vessel storing carbon compounds provided that:

100. Anhydrous ammonia storage tanks and distribution facilities in accordance with the following conditions:

1. The tank is located at least 1/4 mile from any recreational area or residence or other structure not occupied or used solely by the owner of the facility or the owner of the property upon which the facility is located.
2. The capacity of the storage tanks is 30,000 gallons or less.
3. When transferring ammonia, all vapors shall be vented back to the host tank and never to the atmosphere.
4. When relieving pressure from connectors and hoses, all vapors shall be bled into an adequate volume of water and never directly to the atmosphere.
5. Before construction/installation of the facility begins, written site approval must be received from the Executive Director of the Texas Air Control Board.
6. Before construction begins the facility must be registered with Form PI-7.

101. All aqueous fertilizer storage tanks.

102. Any fixed roof or floating roof storage tank or change of chemical service in such tank, used to store chemicals shown in attached Table 102A provided that:

1. The plant tank is located at least 500 feet from any recreational area or residence or other structure not occupied or used solely by the owner of the facility or the owner of the property upon which the facility is located.
2. The total emission of non-methane, non-ethane carbon compounds is less than 25 tons per year for each tank.
3. The true vapor pressure of the compound to be stored is less than eleven (11.0) psia at the maximum storage temperature.
4. For those compounds that have a true vapor pressure greater than 0.5 psia and less than 11.0 psia at the maximum storage temperature, the storage vessel shall be equipped with an internal floating roof with a single seal or an external floating roof with two seals.
5. For any tank equipped with a floating roof the integrity of the floating roof seals shall be verified annually and records maintained to describe dates, seal integrity and corrective actions taken.
6. The floating roof design shall incorporate sufficient flotation to conform to the requirements of API Code 650, Appendix C or and equivalent degree of flotation.
7. Compounds with a true vapor pressure of 0.5 psia or less may be stored in a fixed roof tank which includes a submerged fill pipe or utilizes bottom loading.
8. Except where a dark color is required for product heating, all uninsulated tank exterior surfaces exposed to the sun shall be painted chalk white.
9. Emissions shall be calculated by methods outlined in Section 4.3 of EPA Publication AP-42, except that a seal factor (K_s) of 0.25 shall be used.
10. Before construction begins, storage tanks of 25,000 gallons capacity or greater and located in a designated non-attainment area for photochemical oxidants shall be registered with Form PI-7. The exemption registration shall include the following supplemental information:
    (a) Table 1 of Form PI-2 listing all tanks and calculated emissions for each carbon compound in tons per year for each tank.
    (b) Table 7 of Form PI-2 - One table for each different tank design.
11. Prior approval of the Executive Director of the Texas Air Control board shall be obtained before the chemical service of a storage tank is changed to store a chemical not listed on Table 102A. It will not be necessary to obtain reapproval for chemicals previously approved for service in a specific tank.
12. Table 102A Approved Product List for Standard Exemption No. 102

    Acetal, Acetone, Acetonitrile, Amyl Acetate, Amyl Alcohol

    Butyl Acetate, Butyl Alcohol, Butyl Ether, Butyl Formate, Butyronitrile

    Cellosolves, Cellosolve Acetates, Chlorobenzene, Crude Oil, Crude Oil Condensates, Cyclohexane, Cyclohexene, Cyclopentane, Cyclopentanol, Cyclopentanone, Cyclopentene

    Diethyl Ketone, Dipropyl Ketone

    Ethyl Acetate, Ethyl Alcohol, Ethyl Benzene, Ethyl Butyrates, Ethyl Cyclohexane, Ethyl Cyclopentane, Ethyl Formate, Ethyl Hexane, Ethyl Methacrylate, Ethyl Pentane, Ethyl Propionate

    Gasoline, Gasoline Additives (non-metallic)

    Heptane, Heptene, Hexane, Hexene, Hexanone

    Isobutyl Acetate, Isobutyl Alcohol, Isobutyl Isobutyrate, Isohexane, Iso Octane, Isopropyl Acetate, Isopropyl Alcohol, Isopropyl Ether

    Mesityl Oxide, Methyl Acetate, Methyl Alcohol, Methyl Amyl Alcohol, Methyl Butyrate, Methyl Cyclohexane, Methyl Cyclopentane, Methyl Ethyl Ketone, Methyl Heptane, Methyl Hexane, Methyl Isoamyl Ketone, Methyl Isobutyl Ketone, Methyl Isopropyl Ketone, Methyl Methacrylate, Methyl Pentane, Methyl Propionate, Methyl Propyl Ketone

    Naphtha, Natural Gas Condensate, Neohexane

    Octane, Octene

    Propyl Acetate, Propyl Alcohol, Propyl Formate, Propyl Propionate

    Refinery Petroleum Products containing less than 10 percent benzene

    Toluene

    Vinyl Acetate, Varsol

    Xylene

103. Any new or modified production tank battery processing sweet crude oil and condensate and consisting of one or more separators, salt water tanks, stock tanks and heater treaters provided that:

1. The plant is located at least 1/4 mile away from any recreational area or residence or other structure not occupied or used solely by the owner of the facility or the owner of the property upon which the facility is located.
2. Tanks located at production tank batteries are not subject to the additional requirements of Standard Exemption No. 102.
3. Gas-oil separators and combustion units at a tank battery shall meet the requirements of Standard Exemptions No. 73 and 74 respectively.
4. The total emissions of non-methane, non-ethane hydrocarbons are no more than 25 tons per year. Emissions may be determined as follows:
5. (a) The vents may be measured with an orifice well tester for a period of at least 24 hours. The average molecular weight and composition of the vent stream shall be determined by an analysis of the gas stream. The vent rates shall be measured when the oil or condensate production rate is at least 30 percent of the maximum production expected from the battery and the vent rates shall be corrected to the maximum expected production rate by multiplying by the appropriate factor as follows:
   V_max=V_meas x (P_max/P_meas)

   Where:
   V_max = maximum expected vent rate
   V_meas = measured vent rate
   P_max = maximum expected oil production rate
   P_meas = oil production rate during vent measurement

   (b) The vents may be measured as in method (a); however, instead of analyzing the composition of the vent stream, the average molecular weight can be assumed to be 50 lb/lb mole and the composition to be 75 weight percent non-methane, non-ethane hydrocarbons.
   (c) Emissions from tankage may be calculated by performing flash calculations based on analysis of the crude oil or condensate from the separator or heater treater plus appropriate temperature and pressure data.
   (d) For batteries with no more than 250 barrels per day of production and liquid volatility no more than 5 lb. Reid, the following equation can be used to estimate the vent rate from a tank.
   E = Wp M [0.0005 (P / (14.7 - P)) 0.68 D^1.73 + 0.00021 P Wo]

   Where:
   E = Emissions of non-methane, non-ethane hydrocarbons (tons/year)
   M = Average molecular weight of vapors (as determined by analysis or assumed to be 50)
   Wp = Weight fraction of non-methane, non-ethane hydrocarbons in the vent (as determined by analysis or assumed to be 0.75)
   P = True vapor pressure at the storage temperature (psia)
   D = Tank diameter (feet)
   Wo = Tank throughput (thousand barrels per year)

   Total emissions shall be determined by adding the calculated emissions from each tank. Emissions from gun-barrel separators must be measured as required in either (a), (b) or (c).

104. Any new or modified production tank battery processing sour crude oil and condensate provided that:

105. Any cryogenic natural gas-liquids separation plant provided that:

1. The plant is located at least 1/4 mile from any recreational area or residence or other structure not occupied or used solely by the owner of the facility or the owner of the property upon which the facility is located.
2. Emissions of non-methane, non-ethane organic compounds, including fugitive losses, are less than 25 tons per year. Emissions from storage tanks and loading operations shall be calculated using methods and factors from AP-42.
3. Emissions of sulfur dioxide are less than 25 tons per year and hydrogen sulfide emission are less than 4 pounds per hour. The height of the hydrogen sulfide emission point must meet condition (3) in Exemption No. 104 for tank batteries handling sour crude oil.
4. Compressors associated with this facility shall meet the requirements of Exemption No. 6.
5. The appropriate regional supervisor shall be notified prior to construction.

106. Pathological incinerators with a capacity equal to or less than 200 pounds per hour provided that:

1. The incinerator is a dual chamber design.
   
2. Adequately sized burners are located in each chamber and the burners are automatically operated when the unit is charged with waste.
   
3. Operating instructions are posted at the unit.
   
4. The incinerator will operate with no visible emissions.
   
5. Fuel shall be sweet natural gas or No. 2 fuel oil with less than 0.5% sulfur by weight.
6. Before construction begins the facility must be registered with Form PI-7.

107. Boilers and heaters burning fuel oil with a sulfur content of 0.5% by weight or less or sweet natural gas and the maximum heat input is 10 X 10⁶ BTU per hour or less.

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