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Texas SIP: 30 TAC 115.352-115.359: Fugitive Emission Control in Petroleum Refining and Petrochemical Processes; SIP effective 2008.03.28 TXd89 to 2008.09.14

Regulatory Text: 
Chapter 115.  Control of Air Pollution from Volatile Organic Compounds.

SUBCHAPTER D : PETROLEUM REFINING, NATURAL GAS PROCESSING, AND PETROCHEMICAL PROCESSES
 
5D3 DIVISION 3: FUGITIVE EMISSION CONTROL IN PETROLEUM REFINING, NATURAL GAS/GASOLINE PROCESSING, AND PETROCHEMICAL PROCESSES IN OZONE NONATTAINMENT AREAS
As approved by EPA February 27, 2008 (73 FR 10383) effective March 28, 2008 (TXd89)

Outline:
§115.352.  Control Requirements. 5-80, TXd89
§115.353.  Alternate Control Requirements. 5-71, TXd89
§115.354.  Monitoring and Inspection Requirements. 5-80, TXd89
§115.355.  Approved Test Methods. 5-80, TXd89
§115.356.  Recordkeeping Requirements. 5-80, TXd89
§115.357.  Exemptions. 5-80, TXd89
§115.359.  Counties and Compliance Schedules. 5-80, TXd89


§115.352.  Control Requirements.
5-80:  As adopted by TCEQ December 1, 2004 effective December 23, 2004 (5-80).
Approved by EPA February 27, 2008 (73 FR 10383) effective March 28, 2008 (TXd89).

     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), no person shall operate a petroleum refinery; a synthetic organic chemical, polymer, resin, or methyl-tert-butyl ether manufacturing process; or a natural gas/gasoline processing operation, as defined in §115.10 of this title, without complying with the following requirements.

          (1)  Except as provided in paragraph (2) of this section, no component may be allowed to have a volatile organic compound (VOC) leak for more than 15 calendar days after the leak is found that exceeds the following:

               (A)  for all components except pump seals and compressor seals, a screening concentration greater than 500 parts per million by volume (ppmv) above background as methane, or the dripping or exuding of process fluid based on sight, smell, or sound; and

               (B)  for pump seals and compressor seals, a screening concentration greater than 10,000 ppmv above background as methane, or the dripping or exuding of process fluid based on sight, smell, or sound.

          (2)  A first attempt at repair must be made no later than five calendar days after the leak is found and the component must be repaired no later than 15 calendar days after the leak is found, unless the repair of the component would require a unit shutdown that would create more emissions than the repair would eliminate.  A component in gas/vapor or light liquid service is considered to be repaired when it is monitored with an instrument using United States Environmental Protection Agency Test Method 21 in 40 Code of Federal Regulations (CFR) Part 60, Appendix A (October 17, 2000) and shown to no longer have a leak after adjustments or alterations to the component.  A component in heavy liquid service is considered to be repaired when it is inspected by audio, visual, and olfactory means and shown to no longer have a leak after adjustments or alterations to the component.  If the repair of a component within 15 days after the leak is detected would require a process unit shutdown that would create more emissions than the repair would eliminate, the repair may be delayed until the next scheduled process unit shutdown.

               (A)  Delay of repair beyond a process unit shutdown will be allowed for a component if that component is isolated from the process and does not remain in VOC service.

               (B)  Valves that can be safely repaired without a process unit shutdown may not be placed on the shutdown list. 

               (C)  Delay of repair will be allowed for pumps, compressors, or agitators if the repair is completed as soon as practicable, but not later than six months after the leak was detected, and the repair requires replacing the existing seal design with:

                    (i)  a dual mechanical seal system that includes a barrier fluid system;

                    (ii)  a system that is designed with no externally actuated shaft penetrating the housing; or

                    (iii)  a closed-vent system and control device that meets the requirements of §115.122(a)(2) of this title (relating to Control Requirements).

          (3)  All leaking components, as defined in paragraph (1) of this section, that cannot be repaired until a process unit shutdown must be identified for such repair by tagging.  The executive director, at his discretion, may require an early process unit shutdown or other appropriate action based on the number and severity of tagged leaks awaiting a process unit shutdown.

          (4)  No valves may be installed or operated at the end of a pipe or line containing VOC unless the pipe or line is sealed with a second valve, a blind flange, or a tightly-fitting plug or cap.  The sealing device may be removed only while a sample is being taken or during maintenance operations, and when closing the line, the upstream valve must be closed first.

          (5)  Construction of new and reworked piping, valves, and pump and compressor systems must conform to applicable American National Standards Institute, American Petroleum Institute, American Society of Mechanical Engineers, or equivalent codes.

          (6)  New and reworked underground process pipelines must contain no buried valves such that fugitive emission monitoring is rendered impractical.

          (7)  To the extent that good engineering practice will permit, new and reworked components must be so located to be reasonably accessible for leak-checking during plant operation.  A difficult-to-monitor component is a component that cannot be inspected without elevating the monitoring personnel more than two meters above a permanent support surface or that requires a permit for confined space entry as defined in 29 CFR §1910.146 (December 1, 1998).  Difficult-to-monitor components must be identified in a list to be made available upon request as specified in §115.356(4) of this title (relating to Recordkeeping Requirements).

          (8)  New and reworked piping connections must be welded, flanged, or consist of pressed and permanently formed metal-to-metal seals.  Screwed connections are permissible only on new piping smaller than two inches in diameter. 

          (9)  For pressure relief valves installed in series with a rupture disk, pin, second relief valve, or other similar leak-tight pressure relief component, a pressure gauge or an equivalent device or system must be installed between the relief valve and the other pressure relief component to monitor for leakage past the first component.  When leakage is detected past the first component, that component must be repaired or replaced at the earliest opportunity, but no later than the next process unit shutdown.  Equivalent devices or systems must be identified in a list to be made available upon request as specified in §115.356(4) of this title and must have been approved by the methods required by §115.353 of this title (relating to Alternate Control Requirements).

          (10)  Any petroleum refinery; synthetic organic chemical, polymer, resin, or methyl-tert-butyl ether manufacturing process; or natural gas/gasoline processing operation in the Houston/Galveston/Brazoria area in which a highly-reactive volatile organic compound, as defined in §115.10 of this title, is a raw material, intermediate, final product, or in a waste stream is subject to the requirements of Subchapter H of this chapter (relating to Highly-Reactive Volatile Organic Compounds) in addition to the applicable requirements of this division (relating to Fugitive Emission Control in Petroleum Refining, Natural Gas/Gasoline Processing, and Petrochemical Processes in Ozone Nonattainment Areas).

Adopted December 1, 2004, Effective December 23, 2004 (5-80).
***end tx 115.352***5-80***EPA-R06-OAR-2005-TX-0015***TX021***TXd89***k36***


§115.353.  Alternate Control Requirements.
5-71:  As adopted by TNRCC April 26, 2002 effective May 16, 2002 (5-71).
Approved by EPA February 27, 2008 (73 FR 10383) effective March 28, 2008 (TXd89).

     For all affected persons in the Beaumont/Port Arthur, Dallas/Fort Worth, El Paso, and Houston/Galveston areas, any alternate methods of demonstrating and documenting continuous compliance with the applicable control requirements or exemption criteria in this division (relating to Fugitive Emission Control in Petroleum Refining, Natural Gas/Gasoline Processing, and Petrochemical Processes in Ozone Nonattainment Areas) may be approved by the executive director in accordance with §115.910 of this title (relating to Availability of Alternate Means of Control) if emission reductions are demonstrated to be substantially equivalent.

Adopted April 26, 2002, Effective May 16, 2002 (5-71).
***end tx 115.353***5-71***EPA-R06-OAR-2005-TX-0015***TX021***TXd89***k36***


§115.354.  Montoring and Inspection Requirements.
5-80:  As adopted by TCEQ December 1, 2004 effective December 23, 2004 (5-80).
Approved by EPA February 27, 2008 (73 FR 10383) effective March 28, 2008 (TXd89).

     All affected persons in the Beaumont/Port Arthur, Dallas/Fort Worth, El Paso, and Houston/Galveston/Brazoria areas must conduct a monitoring and inspection program consistent with the following provisions.

          (1)  Monitor yearly (with a hydrocarbon gas analyzer) the emissions from all:

               (A)  process drains that receive or contact affected volatile organic compound wastewater streams as defined in Subchapter B, Division 4 of this chapter (relating to Industrial Wastewater);

               (B)  difficult-to-monitor components as identified in §115.352(7) of this title (relating to Control Requirements) that would otherwise be subject to more frequent monitoring under paragraph (2) of this section; and

               (C)  unsafe-to-monitor components that would otherwise be subject to more frequent monitoring.  An unsafe-to-monitor component is a component that the owner or operator determines is unsafe to monitor because monitoring personnel would be exposed to an immediate danger as a consequence of conducting the monitoring.  Components that are unsafe to monitor must be identified in a list made available upon request as specified in §115.356(4) of this title (relating to Recordkeeping Requirements).  If an unsafe-to-monitor component is not considered safe to monitor within a calendar year, then it must be monitored as soon as possible during times that are safe to monitor.

          (2)  Monitor each calendar quarter (with a hydrocarbon gas analyzer) the screening concentration from all:

               (A)  compressor seals;

               (B)  pump seals;

               (C)  accessible valves; and

               (D)  pressure relief valves in gaseous service.

          (3)  Inspect weekly, by visual, audio, and/or olfactory means, all flanges, excluding flanges that are monitored at least once each calendar year using United States Environmental Protection Agency Test Method 21 in 40 Code of Federal Regulations Part 60, Appendix A (October 17, 2000) and excluding flanges that are unsafe to inspect.  Flanges that are unsafe to inspect must be identified in a list made available upon  request.  If an unsafe-to-inspect flange is not considered safe to inspect within the required weekly time frame, then it must be inspected as soon as possible during a time that it is safe to inspect.

          (4)  Monitor (with a hydrocarbon gas analyzer) emissions from any relief valve that has vented to the atmosphere within 24 hours of the release, excluding relief valves that are unsafe to monitor or difficult to monitor.  Relief valves that are unsafe to monitor must be monitored as soon as possible after relieving during times that are safe to monitor.  Relief valves that are difficult to monitor must be monitored within 15 days after a release.

          (5)  Upon the detection of a leaking component, affix to the leaking component a weatherproof and readily visible tag, bearing an identification number and the date the leak was detected.  This tag must remain in place until the leaking component is repaired.  Tagging of difficult-to-monitor leaking components may be done by reference tagging.  The reference tag should be located as close as possible to the leaking component and should clearly identify the leaking component and its location.

          (6)  The monitoring schedule of paragraphs (1) - (3) of this section may be modified to require an increase in the frequency of monitoring in a given process area if the executive director determines that there is an excessive number of leaks in that process area.

          (7)  After completion of the required quarterly valve monitoring for a period of at least two years, the operator of a petroleum refinery; synthetic organic chemical, polymer, resin, or methyl-tert-butyl ether manufacturing process; or a natural gas/gasoline processing operation may request in writing to the executive director that the valve monitoring schedule be revised based on the percent of valves leaking.  The percent of valves leaking must be determined by dividing the sum of valves leaking during the current monitoring period and valves for which repair has been delayed (including valves that have been classified as non-repairable under §115.357(8) of this title (relating to Exemptions)) by the total number of valves subject to the requirements.  This request must include all data that have been developed to justify the following modifications in the monitoring schedule.

               (A)  After two consecutive quarterly leak detection periods with the percent of valves leaking equal to or less than 2.0%, an owner or operator may begin to skip one of the quarterly leak detection periods for the valves in gas/vapor and light liquid service.

               (B)  After five consecutive quarterly leak detection periods with the percent of valves leaking equal to or less than 2.0%, an owner or operator may begin to skip three of the quarterly leak detection periods for the valves in gas/vapor and light liquid service.

          (8)  Alternate monitoring schedules approved before November 15, 1996, under §§115.324(a)(8)(A), 115.334(3)(A), and 115.344(3)(A) of this title (relating to Inspection Requirements), as in effect December 3, 1993, are approved monitoring schedules for the purposes of paragraph (7) of this section.

          (9)  All component monitoring must occur when the component is in contact with process material and the process unit is in service.  If a unit is not operating during the required monitoring period but a component in that unit is in contact with process fluid that is circulating or under pressure, then that component is considered to be in service and is required to be monitored.  Valves must be in gaseous or light liquid service to be considered in the total valve count for alternate valve monitoring schedules of paragraph (7) of this section.

          (10)  Monitored screening concentrations must be recorded for each component in gaseous or light liquid service.  Notations such as “pegged,” “off scale,” “leaking,” “not leaking,” or “below leak definition” may not be substituted for hydrocarbon gas analyzer results.  For readings that are higher than the upper end of the scale (i.e., pegged) even when using the highest scale setting or a dilution probe, record a default pegged value of 100,000 parts per million by volume.

          (11)  All new connectors must be checked for leaks within 30 days of being placed in volatile organic compound service by monitoring with a hydrocarbon gas analyzer for components in light liquid and gas service and by using visual, audio, and/or olfactory means for components in heavy liquid service.  Components that are unsafe to monitor or inspect are exempt from this requirement if they are monitored or inspected as soon as possible during times that are safe to monitor.

          (12)  All exemptions for valves with a nominal size of two inches or less expired on July 31, 1992 (final compliance date).

Adopted December 1, 2004, Effective December 23, 2004 (5-80).
***end tx 115.354***5-80***EPA-R06-OAR-2005-TX-0015***TX021***TXd89***k36***


§115.355.  Approved Test Methods.
5-80:  As adopted by TCEQ December 1, 2004 effective December 23, 2004 (5-80).
Approved by EPA February 27, 2008 (73 FR 10383) effective March 28, 2008 (TXd89).

     For all affected persons in the Beaumont/Port Arthur, Dallas/Fort Worth, El Paso, and Houston/Galveston/Brazoria areas, compliance with this division (relating to Fugitive Emission Control in Petroleum Refining, Natural Gas/Gasoline Processing, and Petrochemical Processes in Ozone Nonattainment Areas) must be determined by applying the following test methods, as appropriate:

          (1)  Test Method 21 (40 Code of Federal Regulations Part 60, Appendix A (October 17, 2000)) for determining volatile organic compound leaks;

          (2)  determination of true vapor pressure using American Society for Testing and Materials Test Methods D323-89, D2879, D4953, D5190, or D5191 for the measurement of Reid vapor pressure, adjusted for 68 degrees Fahrenheit (20 degrees Celsius) in accordance with American Petroleum Institute Publication 2517, Third Edition, 1989;

          (3)  minor modifications to these test methods approved by the executive director; or

          (4)  equivalent determinations using published vapor pressure data or accepted engineering calculations.

Adopted December 1, 2004, Effective December 23, 2004 (5-80).
***end tx 115.355***5-80***EPA-R06-OAR-2005-TX-0015***TX021***TXd89***k36***


§115.356.  Recordkeeping Requirements.
5-80:  As adopted by TCEQ December 1, 2004 effective December 23, 2004 (5-80).
Approved by EPA February 27, 2008 (73 FR 10383) effective March 28, 2008 (TXd89).

     All affected persons in the Beaumont/Port Arthur, Dallas/Fort Worth, El Paso, and Houston/Galveston/Brazoria areas shall maintain the following, either electronically or in hard copy form:

          (1)  records identifying each process unit subject to fugitive monitoring in accordance with this division (relating to Fugitive Emission Control in Petroleum Refining, Natural Gas/Gasoline Processing, and Petrochemical Processes in Ozone Nonattainment Areas) including, at a minimum, the following information:

               (A)  the name of each process unit;

               (B)  a scale plot plan showing the location of each process unit;

               (C)  process flow diagrams for each process unit showing the general process streams and major equipment on which the components are located; and

               (D)  the expected volatile organic compound emissions if the process unit is shut down for repair of components or other equipment, including:

                    (i)  the total emissions;

                    (ii)  the calculations used; and

                    (iii)  engineering assumptions applied;

          (2)  records on components and process areas that contain, at a minimum, the following data:

               (A)  the name of the process unit where the component is located;

               (B)  the type of component (e.g., pump, compressor, valve, pressure relief valve, etc.);

               (C)  all data collected in accordance with the monitoring and inspection requirements of §115.354 of this title (relating to Monitoring and Inspection Requirements) for each component required to be monitored with a hydrocarbon gas analyzer;

               (D)  the calibration of the monitoring instrument;

               (E)  if a component is found leaking, if applicable:

                    (i)  the component identification and method of leak determination (Test Method 21 in 40 Code of Federal Regulations Part 60, Appendix A (October 17, 2000), sight/sound/smell, or inert gas or hydraulic testing);

                    (ii)  the date that a leaking component is discovered;

                    (iii)  the date that a first attempt at repair was made to a leaking component;

                    (iv)  the date that a leaking component is repaired;

                    (v)  the date and instrument reading of the recheck procedure after a leaking component is repaired;

                    (vi)  the date that the leaking component is placed on the shutdown list; and

                    (vii)  the date that the leaking component was taken out of service; and

               (F)  maintain records of any audio, visual, and olfactory inspections of connectors, but only if a leak is detected;

          (3)  records by process unit identifying and justifying each:

               (A)  unsafe-to-monitor component and unsafe-to-inspect flange;

               (B)  difficult-to-monitor component; and

               (C)  each exemption by component claimed under §115.357 of this title (relating to Exemptions).  The components may be identified by one or more of the following methods:

                    (i)  a plant site plan;

                    (ii)  color coding;

                    (iii)  a written or electronic database;

                    (iv)  designation of process unit boundaries;

                    (v)  some form of weatherproof identification; or

                    (vi)  process flow diagrams that exhibit sufficient detail to identify major pieces of equipment, including major process flows to, from, and within a process unit.  Major equipment includes, but is not limited to, columns, reactors, pumps, compressors, drums, tanks, and exchangers; and

          (4)  all monitoring records for at least five years and make them available for review upon request by authorized representatives of the executive director, United States Environmental Protection Agency, or local air pollution control agencies with jurisdiction, except that the five-year record retention requirement does not apply to records generated before December 31, 2000.

Adopted December 1, 2004, Effective December 23, 2004 (5-80).
***end tx 115.356***5-80***EPA-R06-OAR-2005-TX-0015***TX021***TXd89***k36***


§115.357.  Exemptions.
5-80:  As adopted by TCEQ December 1, 2004 effective December 23, 2004 (5-80).
Approved by EPA February 27, 2008 (73 FR 10383) effective March 28, 2008 (TXd89).

     For all affected persons in the Beaumont/Port Arthur, Dallas/Fort Worth, El Paso, and Houston/Galveston/Brazoria areas, the following exemptions apply.

          (1)  Components that contact a process fluid containing volatile organic compounds (VOCs) having a true vapor pressure equal to or less than 0.044 pounds per square inch, absolute (psia) (0.3 kiloPascals) at 68 degrees Fahrenheit (20 degrees Celsius) are exempt from the instrument monitoring (with a hydrocarbon gas analyzer) requirements of §115.354(1) and (2) of this title (relating to Monitoring and Inspection Requirements) if the components are inspected by visual, audio, and/or olfactory means according to the inspection schedules specified in §115.354(1) and (2) of this title.

          (2)  Conservation vents or other devices on atmospheric storage tanks that are actuated either by a vacuum or a pressure of no more than 2.5 pounds per square inch, gauge (psig), pressure relief valves equipped with a rupture disk or venting to a control device, components in continuous vacuum service, and valves that are not externally regulated (such as in-line check valves) are exempt from the requirements of this division (relating to Fugitive Emission Control in Petroleum Refining, Natural Gas/Gasoline Processing, and Petrochemical Processes in Ozone Nonattainment Areas), except that each pressure relief valve equipped with a rupture disk must comply with §115.352(9) and §115.356(3)(C) of this title (relating to Control Requirements and Recordkeeping Requirements).

          (3)  Compressors in hydrogen service are exempt from the requirements of §115.354 of this title if the owner or operator demonstrates that the percent hydrogen content can be reasonably expected to always exceed 50.0% by volume.

          (4)  All pumps and compressors that are equipped with a shaft sealing system that prevents or detects emissions of VOC from the seal are exempt from the monitoring requirement of §115.354 of this title.  These seal systems may include, but are not limited to, dual pump seals with barrier fluid at higher pressure than process pressure, seals degassing to vent control systems kept in good working order, or seals equipped with an automatic seal failure detection and alarm system.  Submerged pumps or sealless pumps (including, but not limited to, diaphragm, canned, or magnetic driven pumps) may be used to satisfy the requirements of this paragraph.

          (5)  Reciprocating compressors and positive displacement pumps used in natural gas/gasoline processing operations are exempt from the requirements of this division except §115.356(3)(C) of this title.

          (6)  Components at a petroleum refinery or synthetic organic chemical, polymer, resin, or methyl-tert-butyl ether manufacturing process, that contact a process fluid that contains less than 10% VOC by weight and components at a natural gas/gasoline processing operation that contact a process fluid that contains less than 1.0% VOC by weight are exempt from the requirements of this division except §115.356(3)(C) of this title.

          (7)  Plant sites covered by a single account number with less than 250 components in VOC service are exempt from the requirements of this division except §115.356(3)(C) of this title.

          (8)  Components in ethylene, propane, or propylene service, not to exceed 5.0% of the total components, may be classified as non-repairable beyond the second repair attempt at 500 parts per million by volume (ppmv).  These components will remain in the fugitive monitoring program and be repaired no later than 15 calendar days after the concentration of VOC detected via United States Environmental Protection Agency Test Method 21 in 40 Code of Federal Regulations (CFR) Part 60, Appendix A (October 17, 2000) exceeds 10,000 ppmv.  For the purposes of this division, components that contact a process fluid with greater than 85% ethylene, propane, or propylene by weight are considered in ethylene, propane, or propylene service, respectively.

          (9)  The following valves are exempt from the requirements of §115.352(4) of this title:

               (A)  pressure relief valves;

               (B)  open-ended valves or lines in an emergency shutdown system that are designed to open automatically in the event of an emissions event;

               (C) open-ended valves or lines containing materials that would autocatalytically polymerize or would present an explosion, serious overpressure, or other safety hazard if capped or equipped with a double block and bleed system; and

               (D)  valves rated greater than 10,000 psig.

          (10)  Instrumentation systems, as defined in 40 CFR §63.161 (January 17, 1997), that meet 40 CFR §63.169 (June 20, 1996) are exempt from the requirements of this division except §115.356(3)(C) of this title.
          (11)  Sampling connection systems, as defined in 40 CFR §63.161 (January 17, 1997), that meet the requirements of 40 CFR §63.166(a) and (b) (June 20, 1996) are exempt from the requirements of this division except §115.356(3)(C) of this title.

          (12)  Components that are insulated, making them inaccessible to monitoring with a hydrocarbon gas analyzer, are exempt from the monitoring requirements of §115.354(1), (2), and (4) of this title.

          (13)  Components/systems that contact a process fluid containing VOC having a true vapor pressure equal to or less than 0.002 psia at 68 degrees Fahrenheit are exempt from the requirements of this division except §115.356(3)(C) of this title.

          (14)  In the Houston/Galveston/Brazoria area, the requirements of Subchapter H of this chapter (relating to Highly-Reactive Volatile Organic Compounds) may apply to components that qualify for one or more of the exemptions in paragraphs (1) - (11) of this section at any petroleum refinery; synthetic organic chemical, polymer, resin, or methyl-tert-butyl ether manufacturing process; or natural gas/gasoline processing operation in which a highly-reactive volatile organic compound, as defined in §115.10 of this title (relating to Definitions), is a raw material, intermediate, final product, or in a waste stream.

Adopted December 1, 2004, Effective December 23, 2004 (5-80).
***end tx 115.357***5-80***EPA-R06-OAR-2005-TX-0015***TX021***TXd89***k36***


§115.359.  Counties and Compliance Schedules.
5-80:  As adopted by TCEQ December 1, 2004 effective December 23, 2004 (5-80).
Approved by EPA February 27, 2008 (73 FR 10383) effective March 28, 2008 (TXd89).

     The owner or operator of each affected source in Brazoria, Chambers, Collin, El Paso, Dallas, Denton, Fort Bend, Galveston, Hardin, Harris, Jefferson, Liberty, Montgomery, Orange, Tarrant, and Waller Counties must:

          (1)  continue to comply with this division (relating to Fugitive Emission Control in Petroleum Refining, Natural Gas/Gasoline Processing, and Petrochemical Processes in Ozone Nonattainment Areas) as required by §115.930 of this title (relating to Compliance Dates);

          (2)  comply with §115.356(2)(C) of this title (relating to Recordkeeping Requirements) as soon as practicable, but no later than March 31, 2004; and

          (3)  develop and make available upon request to the executive director, United States Environmental Protection Agency, and any local air pollution control agency having jurisdiction the recordkeeping required by §115.356(1) and (3) of this title as soon as practicable, but no later than March 31, 2004.

Adopted December 1, 2004, Effective December 23, 2004 (5-80).
***end tx 115.359***5-80***EPA-R06-OAR-2005-TX-0015***TX021***TXd89***k36***
**************end texas chapter 115 subchapter d division 3***TXd89***k36***
********************end texas chapter 115 subchapter d********TXd89***k36***