For the Beaumont-Port Arthur, Dallas-Fort Worth, El Paso, and
Houston-Galveston-Brazoria areas, as defined in §115.10 of this
title (relating to Definitions) and Gregg, Nueces, and Victoria Counties,
compliance with the requirements in this division must be determined
by applying the following test methods, as appropriate:
(1) Methods 1 - 4 (40 Code of Federal Regulations (CFR)
Part 60, Appendix A) for determining flow rates, as necessary;
(2) Method 18 (40 CFR Part 60, Appendix A) for determining
gaseous organic compound emissions by gas chromatography;
(3) Method 21 (40 CFR Part 60, Appendix A-7) for determining
volatile organic compounds concentrations for the purposes of determining
the presence of leaks and determining breakthrough on a carbon adsorption
system or carbon adsorber. If the owner or operator chooses to conduct
a test to verify a vapor-tight requirement, Method 21 is acceptable;
(4) Method 22 (40 CFR Part 60, Appendix A) for determination
of visible emissions from flares;
(5) Method 25 (40 CFR Part 60, Appendix A) for determining
total gaseous nonmethane organic emissions as carbon;
(6) Methods 25A or 25B (40 CFR Part 60, Appendix A)
for determining total gaseous organic concentrations using flame ionization
or nondispersive infrared analysis;
(7) test method described in 40 CFR §60.113a(a)(1)(ii)
(effective April 8, 1987) for measurement of storage tank seal gap;
(8) true vapor pressure must be determined using standard
reference texts or ASTM International Test Method D323, D2879, D4953,
D5190, D5191, or D6377 for the measurement of Reid vapor pressure,
adjusted for actual storage temperature in accordance with American
Petroleum Institute Publication 2517. For the purposes of temperature
correction, the owner or operator shall use the actual storage temperature.
Actual storage temperature of an unheated storage tank may be determined
using the maximum local monthly average ambient temperature as reported
by the National Weather Service. Actual storage temperature of a heated
storage tank must be determined using either the measured temperature
or the temperature set point of the storage tank;
(9) mass flow meter, positive displacement meter, or
similar device for measuring the volumetric flow rate of flash, working,
breathing, and standing emissions from crude oil and condensate over
a 24-hour period representative of normal operation. For crude oil
and natural gas production sites, volumetric flow rate measurements
must be made while the producing wells are operational;
(10) test methods referenced in paragraphs (2), (5),
and (6) of this section or Gas Processors Association Method 2286,
Tentative Method of Extended Analysis for Natural Gas and Similar
Mixtures by Temperature Programmed Gas Chromatography, to measure
the concentration of volatile organic compounds in flashed gases from
crude oil and condensate storage;
(11) test methods other than those specified in this
section may be used if validated by 40 CFR Part 63, Appendix A, Test
Method 301 and approved by the executive director; or
(12) minor modifications to these test methods approved
by the executive director.
|
