Regulatory Text: 
Louisiana Administrative Code, Title 33 ENVIRONMENTAL QUALITY, Part III Air (LAC 33:III)

Chapter 21.  Control of Emission of Organic Compounds

Subchapter A.  General

Section 2104.  Crude Oil and Condensate. [new section]
As adopted in the Louisiana Register November 20, 1997 (AQ151) with revisions 
adopted in the Louisiana Register April 20, 2004 (AQ236).
Approved by EPA July 5, 2011 (76 FR 38977) effective August 4, 2011 (LAd34) LA021
Regulations.gov docket ID:  EPA-R06-OAR-2007-0924

AQ236   §2104.A;LAd34;LA021.10;AQ236;LR30:0745(4/20/2004)
   A. Applicability. This Section applies to any oil and gas 
production facility (SIC Code 1311), natural gas processing 
plant (SIC Code 1321), or natural gas transmission facility 
(SIC Code 4922) that has a potential to emit 25 Tons Per 
Year (TPY) or more of flash gas to the atmosphere in the 
parishes of Ascension, East Baton Rouge, Iberville, 
Livingston, and West Baton Rouge; 50 TPY or more of flash 
gas to the atmosphere in the parish of Calcasieu; or 100 TPY 
or more of flash gas to the atmosphere in any other parish.

AQ151   §2104.B;LAd34;LA021.09;AQ151;LR23:1497(11/20/1997)
   B. Definitions
      Flash Gas -- VOC emissions from depressurization of 
crude oil or condensate when it is transferred from a higher 
pressure to a lower pressure tank, reservoir, or other container. 
Flash gas emitted to the atmosphere from tanks, reservoirs, 
process vessels, separators, or other process equipment is 
subject to this Section. Emissions from sampling and 
maintenance activities are nm included.

AQ151   §2104.C;LAd34;LA021.09;AQ151;LR23:1497(11/20/1997)
   C. Control Requirements. Any facility to which this 
Section is applicable under Subsection A of this Section shall 
install a vapor recovery system. The vapor recovery system 
shall direct vapors to a fuel gas system, a sales gas system, an 
underground gas injection system, or a control device.

AQ151   §2104.C.1;LAd34;LA021.09;AQ151;LR23:1497(11/20/1997)
      1. For facilities in any parish with a potential to emit 
250 tons or more per year of flash gas, aggregated facility 
flash gas emissions shall be reduced by a minimum of 95 
percent.

AQ236   §2104.C.2;LAd34;LA021.10;AQ236;LR30:0745(4/20/2004)
      2. For facilities in the parishes of Ascension, East 
Baton Rouge, Iberville, Livingston, and West Baton Rouge 
with a potential to emit less than 250 tons per year of flash 
gas, aggregated facility flash gas emissions shall be reduced 
by a minimum of 95 percent or reduced to a potential to emit 
of less than 25 TPY by means of a federally enforceable 
permit revision that permanently restricts production, hours 
of operation, and/or capacity utilization or other equivalent 
control and requires the maintenance of records to 
demonstrate compliance with the permit restrictions.

AQ236   §2104.C.3;LAd34;LA021.10;AQ236;LR30:0745(4/20/2004)
      3. For facilities in the parish of Calcasieu with a 
potential to emit less than 250 tons per year of flash gas, 
aggregated facility flash gas emissions shall be reduced by a 
minimum of 95 percent or reduced to a potential to emit of 
less than 50 TPY by means of a federally enforceable permit 
revision that permanently restricts production, hours of 
operation, and/or capacity utilization or other equivalent 
control and requires the maintenance of records to 
demonstrate compliance with the permit restrictions.

AQ236   §2104.C.4;LAd34;LA021.10;AQ236;LR30:0745(4/20/2004)
      4. For facilities in parishes other than Ascension, 
Calcasieu, East Baton Rouge, Iberville, Livingston, and West 
Baton Rouge with a potential to emit less than 250 tons per 
year of flash gas, aggregated facility flash gas emissions 
shall be reduced by a minimum of 95 percent or reduced to a 
potential to emit of less than 100 TPY by means of a 
federally enforceable permit revision that permanently 
restricts production, hours of operation, and/or capacity 
utilization or other equivalent control and requires the 
maintenance of records. to demonstrate compliance with the 
permit restrictions.

AQ151   §2104.D;LAd34;LA021.09;AQ151;LR23:1497(11/20/1997)
   D. Exemptions. The following are exempt from the 
requirements of this Section:
      1. facilities that are required by the NESHAP for oil and 
natural gas production (40 CFR part 61 subpart HH) to install 
controls for flash gas emissions;
      2. tanks that have installed controls to comply with 
requirements of the New Source Performance Standards for 
storage vessels for petroleum liquid; and
      3. temporary tanks associated with well testing 
operations for a period of up to 90 days following initial 
production from that well.

AQ236   §2104.E;LAd34;LA021.10;AQ236;LR30:0745(4/20/2004)
   E. Compliance Schedule. For equipment located in the 
parishes of Ascension, East Baton Rouge, Iberville, 
Livingston, and West Baton Rouge, compliance shall be 
achieved as soon as practicable, but no later than September 
1, 1998. For equipment located in the parish of Calcasieu 
with a potential to emit less than 100 TPY, compliance shall 
be achieved as soon as practicable, but no later than August 
20, 2003. For all other facilities compliance shall be 
achieved as soon as practicable, but no later than May 1, 
1999. A facility that has become subject to this regulation as 
a result of a revision of the regulation shall comply with the 
requirements of this Section as soon as practicable, but in no 
event later than one year from the promulgation of the 
regulation revision.

AQ151   §2104.F to F.2.d;LAd34;LA021.09;AQ151;LR23:1498(11/20/1997)
   F. Test Methods
      1. Flares. Flares will be considered in compliance with 
Subsection C of this Section if the heat content of the gas is 
above 300 BTU/scf and the flare is equipped with an 
automatic flare relighting device, is equipped with a heat 
sensing device, or is visually checked daily to detect the 
presence of a flame.
      2. Other Control Devices. The following test methods 
shall be used, where appropriate, to measure control device 
compliance. A fuel gas system, a sales gas system, or an 
underground injection system shall not be subject to this 
testing requirement:
         a. test methods 1-4 (40 CFR part 60, appendix A, as 
incorporated by reference in LAC:III.3003) for 
determining flow rates, as necessary;
         b. test method 18 (40 CFR part 60, appendix A, as 
incorporated by reference in LAC:III.3003) for measuring 
gaseous organic compound emissions by gas chromatographic 
analysis;
         c. test method 21 (40 CFR part 60, appendix A, as 
incorporated by reference in LAC:III.3003) far 
determination of volatile organic compound leaks;
         d. test method 25 (40 CFR part 60, appendix A, as 
incorporated by reference in LAC:III.3003) for 
determining total gaseous nonmethanc organic emissions, 
such as carbon; and

PARAGRAPH F.1.e NOT IN SIP -- NOT LISTED IN FEDERAL 
REGISTER AMENDATORY LANGUAGE
         e. additional performance test procedures, or
equivalent test methods, approved by the administrative
authority. 

AQ151   §2104.G to G.5;LAd34;LA021.09;AQ151;LR23:1498(11/20/1997) 
   G. Monitoring/Recordkeeping/Reporting. The owner/ 
operator of any oil and gas production facility shall maintain 
records to verify compliance with or exemption from this 
Section. The records shall be maintained on the premises, or
at an alternative location approved by the administrative 
authority, for at least five years and will include, but not be 
limited to, the following:
      1. the potential to emit flash gas from emission points 
that vent to the atmosphere, determined by using generally 
acceptable engineering calculation techniques or test methods. 
The method of calculation or testing must be approved by the 
administrative authority;
      2. the following information for control devices 
required under Subsection C of this Section:
         a. for flares:
            i. the heat content of the gas;
            ii. documentation of daily visual observations to 
detect the presence of a flame, if required by Subsection F.l 
of this Section; and
            iii. documentation of any failure to make a daily 
observation, including the mitigating circumstances, such as 
severe weather;
         b. for other control devices:
            i. daily measurements of the inlet and outlet gas 
temperature of a chiller or catalytic incinerator; or
            ii. results of monitoring outlet VOC concentration 
of carbon adsorption bed to detect breakthrough;
      3. the date and reason for any maintenance and repair of 
the applicable vapor recovery system and the estimated 
quantity and duration of volatile organic compound em iss ions 
during such activities. This requirement applies to vapors 
directed to a fuel gas system, sales gas system, underground 
gas injection system, control device, or any other system used 
to comply with Subsection C of this Section;
      4. the results of any testing conducted in accordance 
with the provisions specified in Subsection F of this Section; 
and
      5. all operating parameters required to verify the 
validity of the flash gas emissions as calculated in Subsection 
G.l of this Section.