s. Revising paragraph (g)(1) and paragraph (g)(2) introductory text;
	t. Revising paragraph (g)(2)(iii);
	u. Revising paragraph (g)(3); and
	v. Adding paragraph (h) to read as follows:
§63.772 Test methods, compliance procedures, and compliance demonstrations.
* * * * *
	(b) Determination of glycol dehydration unit flowrate,  benzene emissions, or BTEX emissions. The procedures of this paragraph shall be used by an owner or operator to determine glycol dehydration unit natural gas flowrate, benzene emissions, or BTEX emissions.
	(1) * * *
* * * * *
	(ii) The owner or operator shall document, to the Administrator's satisfaction, the actual annual average natural gas flowrate to the glycol dehydration unit.
* * * * *
	(2) The determination of actual average benzene or BTEX emissions from a glycol dehydration unit shall be made using the procedures of either paragraph (b)(2)(i) or (b)(2)(ii) of this section. Emissions shall be determined either uncontrolled, or with Federally enforceable controls in place.
	(i) The owner or operator shall determine actual average benzene or BTEX emissions using the model GRI-GLYCalc[TM] , Version 3.0 or higher, and the procedures presented in the associated GRI-GLYCalc[TM] Technical Reference Manual. Inputs to the model shall be representative of actual operating conditions of the glycol dehydration unit and may be determined using the procedures documented in the Gas Research Institute (GRI) report entitled "Atmospheric Rich/Lean Method for Determining Glycol Dehydrator Emissions" (GRI - 95/0368.1); or
	(ii) The owner or operator shall determine an average mass rate of benzene or BTEX emissions in kilograms per hour through direct measurement using the methods in §63.772(a)(1)(i) or (ii), or an alternative method according to §63.7(f). Annual emissions in kilograms per year shall be determined by multiplying the mass rate by the number of hours the unit is operated per year. This result shall be converted to megagrams per year.
* * * * *
	(d)   Test procedures and compliance demonstrations for small glycol dehydration units. This paragraph applies to the test procedures for small dehydration units.
	(1)  If the owner or operator is using a control device to comply with the emission limit in §63.765(b)(1)(iii), the requirements of paragraph (e) of this section apply. Compliance is demonstrated using the methods specified in paragraph (f) of this section.
	(2) If no control device is used to comply with the emission limit in §63.765(b)(1)(iii), the owner or operator must determine the glycol dehydration unit BTEX emissions as specified in paragraphs (d)(2)(i) through (iii) of this section. Compliance is demonstrated if the BTEX emissions determined as specified in paragraphs (d)(2)(i) through (iii) are less than the emission limit calculated using the equation in §63.765(b)(1)(iii).
	(i) Method 1 or 1A, 40 CFR part 60, appendix A, as appropriate, shall be used for selection of the sampling sites at the outlet of the glycol dehydration unit process vent. Any references to particulate mentioned in Methods 1 and 1A do not apply to this section.
	(ii) The gas volumetric flowrate shall be determined using Method 2, 2A, 2C, or 2D, 40 CFR part 60, appendix A, as appropriate.
	(iii)  The BTEX emissions from the outlet of the glycol dehydration unit process vent shall be determined using the procedures specified in paragraph (e)(3)(v) of this section. As an alternative, the mass rate of BTEX at the outlet of the glycol dehydration unit process vent may be calculated using the model GRI-GLYCalc[TM] , Version 3.0 or higher, and the procedures presented in the associated GRI-GLYCalc[TM] Technical Reference Manual. Inputs to the model shall be representative of actual operating conditions of the glycol dehydration unit and shall be determined using the procedures documented in the Gas Research Institute (GRI) report entitled "Atmospheric Rich/Lean Method for Determining Glycol Dehydrator Emissions" (GRI - 95/0368.1). When the BTEX mass rate is calculated for glycol dehydration units using the model GRI-GLYCalc[TM] , all BTEX measured by Method 18, 40 CFR part 60, appendix A, shall be summed.
	(e) Control device performance test procedures. This paragraph applies to the performance testing of control devices. The owners or operators shall demonstrate that a control device achieves the performance requirements of §63.771(d)(1), (e)(3)(ii) or (f)(1) using a performance test as specified in paragraph (e)(3) of this section. Owners or operators using a condenser have the option to use a design analysis as specified in paragraph (e)(4) of this section. The owner or operator may elect to use the alternative procedures in paragraph (e)(5) of this section for performance testing of a condenser used to control emissions from a glycol dehydration unit process vent. As an alternative to conducting a performance test under this section for combustion control devices, a control device that can be demonstrated to meet the performance requirements of §63.771(d)(1), (e)(3)(ii) or (f)(1) through a performance test conducted by the manufacturer, as specified in paragraph (h) of this section can be used.
	(1) * * *
	(i) Except as specified in paragraph (e)(2) of this section, a flare, as defined in §63.761, that is designed and operated in accordance with §63.11(b);
	(ii) Except for control devices used for small glycol dehydration units, a boiler or process heater with a design heat input capacity of 44 megawatts or greater;
	(iii) Except for control devices used for small glycol dehydration units, a boiler or process heater into which the vent stream is introduced with the primary fuel or is used as the primary fuel;
	(iv) Except for control devices used for small glycol dehydration units, a boiler or process heater burning hazardous waste for which the owner or operator has either been issued a final permit under 40 CFR part 270 and complies with the requirements of 40 CFR part 266, subpart H; or has certified compliance with the interim status requirements of 40 CFR part 266, subpart H;
	(v) Except for control devices used for small glycol dehydration units, a hazardous waste incinerator for which the owner or operator has been issued a final permit under 40 CFR part 270 and complies with the requirements of 40 CFR part 264, subpart O; or has certified compliance with the interim status requirements of 40 CFR part 265, subpart O.
* * * * *
	(2) An owner or operator shall design and operate each flare, as defined in §63.761, in accordance with the requirements specified in §63.11(b) and the compliance determination shall be conducted using Method 22 of 40 CFR part 60, appendix A, to determine visible emissions.
 	(3) For a performance test conducted to demonstrate that a control device meets the requirements of §63.771(d)(1), (e)(3)(ii) or (f)(1), the owner or operator shall use the test methods and procedures specified in paragraphs (e)(3)(i) through (v) of this section. The initial and periodic performance tests shall be conducted according to the schedule specified in paragraph (e)(3)(vi) of this section.
	(i) * * *
* * * * *	(B) To determine compliance with the enclosed combustion device total HAP concentration limit specified in §63.765(b)(1)(iii), or the BTEX emission limit specified in §63.771(f)(1) the sampling site shall be located at the outlet of the combustion device.
* * * * *

	(iv) * * *
* * * * *
	(C) * * *
	(1)  The emission rate correction factor for excess air, integrated sampling and analysis procedures of Method 3A or 3B, 40 CFR part 60, appendix A, shall be used to determine the oxygen concentration. The samples shall be taken during the same time that the samples are taken for determining TOC concentration or total HAP concentration.
* * * * *
	(v) To determine compliance with the BTEX emission limit specified in §63.771(f)(1) the owner or operator shall use one of the following methods: Method 18, 40 CFR part 60, appendix A;  ASTM D6420 - 99 (2004), as specified in §63.772(a)(1)(ii); or any other method or data that have been validated according to the applicable procedures in Method 301, 40 CFR part 63, appendix A. The following procedures shall be used to calculate BTEX emissions:
	(A) The minimum sampling time for each run shall be 1 hour in which either an integrated sample or a minimum of four grab samples shall be taken. If grab sampling is used, then the samples shall be taken at approximately equal intervals in time, such as 15-minute intervals during the run.
	(B) The mass rate of BTEX (Eo) shall be computed using the equations and procedures specified in paragraphs (e)(3)(v)(B)(1) and (2) of this section.
	(1) The following equation shall be used:

Where:
Eo= Mass rate of BTEX at the outlet of the control device, dry basis, kilogram per hour.
Coj= Concentration of sample component j of the gas stream at the outlet of the control device, dry basis, parts per million by volume.
Moj= Molecular weight of sample component j of the gas stream at the outlet of the control device, gram/gram-mole.
Qo= Flowrate of gas stream at the outlet of the control device, dry standard cubic meter per minute.
K2= Constant, 2.494x10[−6] (parts per million) (gram-mole per standard cubic meter) (kilogram/gram) (minute/hour), where standard temperature (gram-mole per standard cubic meter) is 20 degrees C.
n = Number of components in sample.

	(2) When the BTEX mass rate is calculated, only BTEX compounds measured by Method 18, 40 CFR part 60, appendix A, or ASTM D6420 - 99 (2004) as specified in §63.772(a)(1)(ii), shall be summed using the equations in paragraph (e)(3)(v)(B)(1) of this section.
	(vi) The owner or operator shall conduct performance tests according to the schedule specified in paragraphs (e)(3)(vi)(A) and (B) of this section.
	(A)  An initial performance test shall be conducted within 180 days after the compliance date that is specified for each affected source in §63.760(f)(7) through (8), except that the initial performance test for existing combustion control devices at existing major sources shall be conducted no later than 3 years after the date of publication of the final rule in the Federal Register. If the owner or operator of an existing combustion control device at an existing major source chooses to replace such device with a control device certified under §63.772(h), then the installed device shall comply with all provisions of this subpart no later than 3 years after the date of publication of the final rule in the Federal Register. The performance test results shall be submitted in the Notification of Compliance Status Report as required in §63.775(d)(1)(ii).
	(B) Periodic performance tests shall be conducted. The first periodic performance test shall be conducted no later than 60 months after the initial performance test required in paragraph (e)(3)(vi)(A) of this section. Subsequent period performance tests shall be conducted at intervals no longer than 5 years following the first periodic performance test or whenever a source desires to establish a new operating limit. The periodic performance test results must be submitted in the next Periodic Report as specified in §63.775(e)(2)(xi).
	(4) For a condenser design analysis conducted to meet the requirements of §63.771(d)(1), (e)(3)(ii), or (f)(1), the owner or operator shall meet the requirements specified in paragraphs (e)(4)(i) and (e)(4)(ii) of this section. Documentation of the design analysis shall be submitted as a part of the Notification of Compliance Status Report as required in §63.775(d)(1)(i).
	(i) The condenser design analysis shall include an analysis of the vent stream composition, constituent concentrations, flowrate, relative humidity, and temperature, and shall establish the design outlet organic compound concentration level, design average temperature of the condenser exhaust vent stream, and the design average temperatures of the coolant fluid at the condenser inlet and outlet. As an alternative to the condenser design analysis, an owner or operator may elect to use the procedures specified in paragraph (e)(5) of this section.
* * * * *
	(5) As an alternative to the procedures in paragraphs (e)(3) and (e)(4)(i) of this section, an owner or operator may elect to use the procedures documented in the GRI report entitled, "Atmospheric Rich/Lean Method for Determining Glycol Dehydrator Emissions" (GRI - 95/0368.1) as inputs for the model GRI-GLYCalc[TM] , Version 3.0 or higher, to generate a condenser performance curve.
	(f) Compliance demonstration for control device performance requirements. This paragraph applies to the demonstration of compliance with the control device performance requirements specified in §63.771(d)(1)(i), (e)(3) and (f)(1). Compliance shall be demonstrated using the requirements in paragraphs (f)(1) through (3) of this section. As an alternative, an owner or operator that installs a condenser as the control device to achieve the requirements specified in §63.771(d)(1)(ii), (e)(3) or (f)(1) may demonstrate compliance according to paragraph (g) of this section. An owner or operator may switch between compliance with paragraph (f) of this section and compliance with paragraph (g) of this section only after at least 1 year of operation in compliance with the selected approach. Notification of such a change in the compliance method shall be reported in the next Periodic Report, as required in §63.775(e), following the change.
* * * * *
	(2) The owner or operator shall calculate the daily average of the applicable monitored parameter in accordance with §63.773(d)(4) except that the inlet gas flow rate to the control device shall not be averaged.
	(3) Compliance with the operating parameter limit is achieved when the daily average of the monitoring parameter value calculated under paragraph (f)(2) of this section is either equal to or greater than the minimum or equal to or less than the maximum monitoring value established under paragraph (f)(1) of this section. For inlet gas flow rate, compliance with the operating parameter limit is achieved when the value is equal to or less than the value established under §63.772(h).
	(4) Except for periods of monitoring system malfunctions, repairs associated with monitoring system malfunctions, and required monitoring system quality assurance or quality control activities (including, as applicable, system accuracy audits and required zero and span adjustments), the CMS required in §63.773(d) must be operated at all times the affected source is operating. A monitoring system malfunction is any sudden, infrequent, not reasonably preventable failure of the monitoring system to provide valid data. Monitoring system failures that are caused in part by poor maintenance or careless operation are not malfunctions. Monitoring system repairs are required to be completed in response to monitoring system malfunctions and to return the monitoring system to operation as expeditiously as practicable.
	(5)  Data recorded during monitoring system malfunctions, repairs associated with monitoring system malfunctions, or required monitoring system quality assurance or control activities may not be used in calculations used to report emissions or operating levels. All the data collected during all other required data collection periods must be used in assessing the operation of the control device and associated control system.
	(6)  Except for periods of monitoring system malfunctions, repairs associated with monitoring system malfunctions, and required quality monitoring system quality assurance or quality control activities (including, as applicable, system accuracy audits and required zero and span adjustments), failure to collect required data is a deviation of the monitoring requirements.
	(g) Compliance demonstration with percent reduction or emission limit performance requirements -- condensers. This paragraph applies to the demonstration of compliance with the performance requirements specified in §63.771(d)(1)(ii),(e)(3) or (f)(1) for condensers. Compliance shall be demonstrated using the procedures in paragraphs (g)(1) through (3) of this section.
	(1) The owner or operator shall establish a site-specific condenser performance curve according to §63.773(d)(5)(ii). For sources required to meet the BTEX limit in accordance with §63.771(e) or (f)(1) the owner or operator shall identify the minimum percent reduction necessary to meet the BTEX limit.
	(2) Compliance with the requirements in §63.771(d)(1)(ii),(e)(3) or (f)(1) shall be demonstrated by the procedures in paragraphs (g)(2)(i) through (iii) of this section.
* * * * *
	(iii) Except as provided in paragraphs (g)(2)(iii)(A) and (B) of this section, at the end of each operating day, the owner or operator shall calculate the 365-day average HAP, or BTEX, emission reduction, as appropriate, from the condenser efficiencies as determined in paragraph (g)(2)(ii) of this section for the preceding 365 operating days. If the owner or operator uses a combination of process modifications and a condenser in accordance with the requirements of §63.771(e), the 365-day average HAP, or BTEX, emission reduction shall be calculated using the emission reduction achieved through process modifications and the condenser efficiency as determined in paragraph (g)(2)(ii) of this section, both for the previous 365 operating days.
	(A) After the compliance dates specified in §63.760(f), an owner or operator with less than 120 days of data for determining average HAP, or BTEX, emission reduction, as appropriate, shall calculate the average HAP, or BTEX emission reduction, as appropriate, for the first 120 days of operation after the compliance dates. For sources required to meet the overall 95.0 percent reduction requirement, compliance is achieved if the 120-day average HAP emission reduction is equal to or greater than 90.0 percent. For sources required to meet the BTEX limit under §63.765(b)(1)(iii), compliance is achieved if the average BTEX emission reduction is at least 95.0 percent of the required 365-day value identified under paragraph (g)(1) of this section (i.e., at least 76.0 percent if the 365-day design value is 80.0 percent).
	(B) After 120 days and no more than 364 days of operation after the compliance dates specified in §63.760(f), the owner or operator shall calculate the average HAP emission reduction as the HAP emission reduction averaged over the number of days between the current day and the applicable compliance date. For sources required to meet the overall 95.0 percent reduction requirement, compliance with the performance requirements is achieved if the average HAP emission reduction is equal to or greater than 90.0 percent. For sources required to meet the BTEX limit under §63.765(b)(1)(iii), compliance is achieved if the average BTEX emission reduction is at least 95.0 percent of the required 365-day value identified under paragraph (g)(1) of this section (i.e., at least 76.0 percent if the 365-day design value is 80.0 percent).
	(3) If the owner or operator has data for 365 days or more of operation, compliance is achieved based on the applicable criteria in paragraphs (g)(3)(i) or (ii) of this section.
	(i) For sources meeting the HAP emission reduction specified in §63.771(d)(1)(ii) or (e)(3) the average HAP emission reduction calculated in paragraph (g)(2)(iii) of this section is equal to or greater than 95.0 percent.
	(ii) For sources required to meet the BTEX limit under §63.771(e)(3) or (f)(1), compliance is achieved if the average BTEX emission reduction calculated in paragraph (g)(2)(iii) of this section is equal to or greater than the minimum percent reduction identified in paragraph (g)(1) of this section.
* * * * *
      (h)  Performance testing for combustion control devices - manufacturers' performance test.
      (1) This paragraph applies to the performance testing of a combustion control device conducted by the device manufacturer. The manufacturer shall demonstrate that a specific model of control device achieves the performance requirements in (h)(7) of this section by conducting a performance test as specified in paragraphs (h)(2) through (6) of this section.
      (2)  Performance testing shall consist of three 1-hour (or longer) test runs for each of the four following firing rate settings making a total of 12 test runs per test. Propene (propylene) gas shall be used for the testing fuel. All fuel analyses shall be performed by an independent third-party laboratory (not affiliated with the control device manufacturer or fuel supplier).
      (i)  90 - 100 percent of maximum design rate (fixed rate).
      (ii)  70 - 100 - 70 percent (ramp up, ramp down).
      (iii)  30 - 70 - 30 percent (ramp up, ramp down).
      (iv)  0 - 30 - 0 percent (ramp up, ramp down).
      (3)  All models employing multiple enclosures shall be tested simultaneously and with all burners operational. Results shall be reported for the each enclosure individually and for the average of the emissions from all interconnected combustion enclosures/chambers. Control device operating data shall be collected continuously throughout the performance test using an electronic Data Acquisition System and strip chart. Data shall be submitted with the test report in accordance with paragraph (h)(8)(iii) of this section.
      (4) Inlet testing shall be conducted as specified in paragraphs (h)(4)(i) through (iii) of this section.
      (i) The fuel flow metering system shall be located in accordance with Method 2A, 40 CFR part 60, appendix A-1, (or other approved procedure) to measure fuel flow rate at the control device inlet location. The fitting for filling fuel sample containers shall be located a minimum of 8 pipe diameters upstream of any inlet fuel flow monitoring meter.
      (ii)  Inlet flow rate shall be determined using Method 2A, 40 CFR part 60, appendix A-1. Record the start and stop reading for each 60-minute THC test. Record the gas pressure and temperature at 5-minute intervals throughout each 60-minute THC test.
      (iii)  Inlet fuel sampling shall be conducted in accordance with the criteria in paragraphs (h)(4)(iii)(A) and (B) of this section.
      (A)  At the inlet fuel sampling location, securely connect a Silonite-coated stainless steel evacuated canister fitted with a flow controller sufficient to fill the canister over a 1 hour period. Filling shall be conducted as specified in the following:
      (1)  Open the canister sampling valve at the beginning of the total hydrocarbon (THC) test, and close the canister at the end of the THC test.
      (2)  Fill one canister for each THC test run.
      (3)  Label the canisters individually and record on a chain of custody form.
      (B)  Each fuel sample shall be analyzed using the following methods. The results shall be included in the test report.
      (1)  Hydrocarbon compounds containing between one and five atoms of carbon plus benzene using ASTM D1945-03.
      (2)  Hydrogen (H2), carbon monoxide (CO), carbon dioxide (CO2), nitrogen (N2), oxygen (O2) using ASTM D1945-03.
      (3)  Carbonyl sulfide, carbon disulfide plus mercaptans using ASTM D5504.
      (4)  Higher heating value using ASTM D3588-98 or ASTM D4891-89.
      (5)  Outlet testing shall be conducted in accordance with the criteria in paragraphs (h)(5)(i) through (v) of this section.
      (i)  Sampling and flowrate measured in accordance with the following:
      (A) The outlet sampling location shall be a minimum of 4 equivalent stack diameters downstream from the highest peak flame or any other flow disturbance, and a minimum of one equivalent stack diameter upstream of the exit or any other flow disturbance. A minimum of two sample ports shall be used.
      (B)  Flow rate shall be measured using Method 1, 40 CFR part 60, Appendix 1, for determining flow measurement traverse point location; and Method 2, 40 CFR part 60, Appendix 1, shall be used to measure duct velocity. If low flow conditions are encountered (i.e., velocity pressure differentials less than 0.05 inches of water) during the performance test, a more sensitive manometer shall be used to obtain an accurate flow profile.
      (ii)  Molecular weight shall be determined as specified in paragraphs (h)(5)(ii)(A) and (B) of this section.
      (A)  An integrated bag sample shall be collected during the Method 4, 40 CFR part 60, Appendix A, moisture test. Analyze the bag sample using a gas chromatograph-thermal conductivity detector (GC-TCD) analysis meeting the following criteria:
      (1) Collect the integrated sample throughout the entire test, and collect representative volumes from each traverse location.
      (2) The sampling line shall be purged with stack gas before opening the valve and beginning to fill the bag.
      (3) The bag contents shall be kneaded or otherwise vigorously mixed prior to the GC analysis.
      (4) The GC-TCD calibration procedure in Method 3C, 40 CFR part 60, Appendix A, shall be modified by using EPA Alt-045 as follows: For the initial calibration, triplicate injections of any single concentration must agree within 5 percent of their mean to be valid. The calibration response factor for a single concentration re-check must be within 10 percent of the original calibration response factor for that concentration. If this criterion is not met, the initial calibration using at least three concentration levels shall be repeated.
      (B)  Report the molecular weight of: O2, CO2, Methane (CH4), and N2 and include in the test report submitted under §63.775(d).
      (iii)  Moisture shall be determined using Method 4, 40 CFR part 60, Appendix A. Traverse both ports with the Method 4, 40 CFR part 60, Appendix A, sampling train during each test run. Ambient air shall not be introduced into the Method 3C, 40 CFR part 60, Appendix A, integrated bag sample during the port change.
      (iv)  Carbon monoxide shall be determined using Method 10, 40 CFR part 60, Appendix A. The test shall be run at the same time and with the sample points used for the EPA Method 25A, 40 CFR part 60, Appendix A, testing. An instrument range of 0-10 per million by volume-dry (ppmvd) shall be used.
      (v)  Visible emissions shall be determined using Method 22, 40 CFR part 60, Appendix A. The test shall be performed continuously during each test run. A digital color photograph of the exhaust point, taken from the position of the observer and annotated with date and time, will be taken once per test run and the four photos included in the test report.
      (6)  Total hydrocarbons (THC) shall be determined as specified by the following criteria:
      (i) Conduct THC sampling using Method 25A, 40 CFR part 60, Appendix A, except the option for locating the probe in the center 10 percent of the stack shall not be allowed. The THC probe must be traversed to 16.7 percent, 50 percent, and 83.3 percent of the stack diameter during the testing.
      (ii) A valid test shall consist of three Method 25A, 40 CFR part 60, Appendix A, tests, each no less than 60 minutes in duration.
      (iii) A 0-10 parts per million by volume-wet (ppmvw) (as propane) measurement range is preferred; as an alternative a 0-30 ppmvw (as carbon) measurement range may be used.
      (iv) Calibration gases will be propane in air and be certified through EPA Protocol 1  -  "EPA Traceability Protocol for Assay and Certification of Gaseous Calibration Standards," September 1997, as amended August 25, 1999, EPA - 600/R - 97/121 (or more recent if updated since 1999).
      (v) THC measurements shall be reported in terms of ppmvw as propane.
      (vi)   THC results shall be corrected to 3 percent CO2, as measured by Method 3C, 40 CFR part 60, Appendix A.
      (vii) Subtraction of methane/ethane from the THC data is not allowed in determining results.
      (7) Performance test criteria:
      (i) The control device model tested must meet the criteria in paragraphs (h)(7)(i)(A) through (C) of this section:
      (A) Method 22, 40 CFR part 60, Appendix A, results under paragraph (h)(5)(v) of this section with no indication of visible emissions, and
      (B) Average Method 25A, 40 CFR part 60, Appendix A, results under paragraph (h)(6) of this section equal to or less than 10.0 ppmvw THC as propane corrected to 3.0 percent CO2, and
      (C) Average CO emissions determined under paragraph (h)(5)(iv) of this section equal to or less than 10 parts ppmvd, corrected to 3.0 percent CO2.
      (ii) The manufacturer shall determine a maximum inlet gas flow rate which shall not be exceeded for each control device model to achieve the criteria in paragraph (h)(7)(i) of this section.
      (iii)  A control device meeting the criteria in paragraph (h)(7)(i)(A) through (C) of this section will have demonstrated a destruction efficiency of 98.0 percent for HAP regulated under this subpart.
       (8) The owner or operator of a combustion control device model tested under this section shall submit the information listed in paragraphs (h)(8)(i) through (iii) in the test report required under §63.775(d)(1)(iii).
      (i) Full schematic of the control device and dimensions of the device components.
      (ii) Design net heating value of the device.
      (iii) The test parameters listed in (h)(8)(iii)(A) through (Q) of this section, as applicable for the tested model.
      (A) Fuel gas flow including the maximum allowable inlet gas flow rate.
      (B) Fuel gas delivery pressure and temperature.
      (C) Fuel gas moisture.
      (D) Air/ steam injection/ assist.
      (E) Purge gas usage.
      (F) Condensate (liquid fuel) separation.
      (G) Combustion zone temperature.
      (H) Excess combustion air.
      (I) Flame arrestor(s).
      (J) Burner manifold pressure.
      (K) Pilot flame sensor.
      (L) Pilot flame design fuel and fuel usage.
      (M) Tip velocity.
      (N) Momentum flux ratio.
      (O) Exit temperature.
      (P) Exit flow rate.
      (Q) Wind velocity and direction.
      (iv) The test report shall include all calibration quality assurance/quality control data, calibration gas values, gas cylinder certification, and strip charts annotated with test times and calibration values.
      (i) Compliance demonstration for combustion control devices - manufacturers' performance test. This paragraph applies to the demonstration of compliance for a combustion control device tested under the provisions in paragraph (h) of this section. Owners or operators shall demonstrate that a control device achieves the performance requirements of §63.771(d)(1), (e)(3)(ii) or (f)(1), by installing a device tested under paragraph (h) of this section and complying with the following criteria:
      (1) The inlet gas flow rate shall not exceed the maximum rate identified specified by the manufacturer. Flow rate shall be measured as specified in §63.773(d)(3)(i)(H)(1).
      (2) A pilot flame shall be present at all times of operation. The pilot flame shall be monitored in accordance with §63.773(d)(3)(i)(H)(2).
      (3) Devices shall be operated with no visible emissions, except for periods not to exceed a total of 5 minutes during any 2 consecutive hours. A visible emissions test using Method 22, 40 CFR part 60, Appendix A, shall be performed monthly. The observation period shall be 2 hours and shall be used according to Method 22.
      (4) Compliance with the operating parameter limit is achieved when the following criteria are met:
      (i) The inlet gas flow rate monitored under paragraph (i)(1) of this section is equal to or below the maximum established by the manufacturer; and
      (ii) The pilot flame is present at all times; and
      (iii) During the visible emissions test performed under paragraph (i)(3) of this section the duration of visible emissions does not exceed a total of 5 minutes during the observation period. Devices failing the visible emissions test shall follow the requirements in paragraphs (i)(4)(iii)(A) and (B) of this section.
      (A)  Following the first failure, the fuel nozzle(s) and burner tubes shall be replaced.
	(B)  If, following replacement of the fuel nozzle(s) and burner tubes as specified in paragraph (i)(4)(iii)(A), the visible emissions test is not passed in the next scheduled test, either a performance test shall be performed under paragraph (e) of this section, or the device shall be replaced with another control device whose model was tested, and met, the requirements in paragraph (h) of this section.
	19. Section 63.773 is amended by:
	a. Revising paragraph (d)(1) introductory text;
	b. Revising paragraph (d)(1)(ii) and adding paragraphs (d)(1)(iii) and (iv);
	c. Revising paragraphs (d)(2)(i) and (d)(2)(ii);
	d. Revising paragraphs (d)(3)(i)(A) and (B);
	e. Revising paragraphs (d)(3)(i)(D) and (E);
	f. Revising paragraphs (d)(3)(i)(F)(1) and (2);
	g. Revising paragraph (d)(3)(i)(G);
	h. Adding paragraph (d)(3)(i)(H);
	i. Revising paragraph (d)(4);
	j. Revising paragraph (d)(5)(i), introductory text;
	k. Revising paragraphs (d)(5)(i)(A) and (B);
	l. Adding paragraph (d)(5)(i)(C);
	m. Revising paragraphs (d)(5)(ii)(A) through (C);
	n. Revising paragraphs (d)(6)(ii) and (iii);
	o. Adding paragraph (d)(6)(vi);
	p. Revising paragraph (d)(8)(i)(A); and
	q. Revising paragraph (d)(8)(ii) to read as follows:
§63.773 Inspection and monitoring requirements.
* * * * *
	(d) Control device monitoring requirements. (1) For each control device, except as provided for in paragraph (d)(2) of this section, the owner or operator shall install and operate a continuous parameter monitoring system in accordance with the requirements of paragraphs (d)(3) through (9) of this section. Owners or operators that install and operate a flare in accordance with §63.771(d)(1)(iii) or (f)(1)(iii) are exempt from the requirements of paragraphs (d)(4) and (5) of this section. The continuous monitoring system shall be designed and operated so that a determination can be made on whether the control device is achieving the applicable performance requirements of §63.771(d), (e)(3) or (f)(1). Each continuous parameter monitoring system shall meet the following specifications and requirements:
* * * * *
	(ii) A site-specific monitoring plan must be prepared that addresses the monitoring system design, data collection, and the quality assurance and quality control elements outlined in paragraph (d) of this section and in §63.8(d). Each CPMS must be installed, calibrated, operated, and maintained in accordance with the procedures in your approved site-specific monitoring plan. Using the process described in §63.8(f)(4), you may request approval of monitoring system quality assurance and quality control procedures alternative to those specified in paragraphs (d)(1)(ii)(A) through (E) of this section in your site-specific monitoring plan.
	(A)  The performance criteria and design specifications for the monitoring system equipment, including the sample interface, detector signal analyzer, and data acquisition and calculations;
	(B) Sampling interface (e.g., thermocouple) location such that the monitoring system will provide representative measurements;
	(C) Equipment performance checks, system accuracy audits, or other audit procedures;
	(D) Ongoing operation and maintenance procedures in accordance with provisions in §63.8(c)(1) and (c)(3); and
	(E) Ongoing reporting and recordkeeping procedures in accordance with provisions in §63.10(c), (e)(1), and (e)(2)(i).
	(iii) The owner or operator must conduct the CPMS equipment performance checks, system accuracy audits, or other audit procedures specified in the site-specific monitoring plan at least once every 12 months.
	(iv) The owner or operator must conduct a performance evaluation of each CPMS in accordance with the site-specific monitoring plan.
	(2) * * *
	(i) Except for control devices for small glycol dehydration units, a boiler or process heater in which all vent streams are introduced with the primary fuel or is used as the primary fuel; or
	(ii) Except for control devices for small glycol dehydration units, a boiler or process heater with a design heat input capacity equal to or greater than 44 megawatts.
	(3) * * *
	(i) * * *
	(A) For a thermal vapor incinerator that demonstrates during the performance test conducted under §63.772(e) that the combustion zone temperature is an accurate indicator of performance, a temperature monitoring device equipped with a continuous recorder. The monitoring device shall have a minimum accuracy of +-1 percent of the temperature being monitored in degrees C ,or +-2.5 degrees C, whichever value is greater. The temperature sensor shall be installed at a location representative of the combustion zone temperature.
	(B) For a catalytic vapor incinerator, a temperature monitoring device equipped with a continuous recorder. The device shall be capable of monitoring temperature at two locations and have a minimum accuracy of +-1 percent of the temperature being monitored in degrees C, or +-2.5 degrees C, whichever value is greater. One temperature sensor shall be installed in the vent stream at the nearest feasible point to the catalyst bed inlet and a second temperature sensor shall be installed in the vent stream at the nearest feasible point to the catalyst bed outlet.
* * * * *
	(D) For a boiler or process heater a temperature monitoring device equipped with a continuous recorder. The temperature monitoring device shall have a minimum accuracy of +-1 percent of the temperature being monitored in degrees C, or +-2.5 degrees C, whichever value is greater. The temperature sensor shall be installed at a location representative of the combustion zone temperature.
	(E) For a condenser, a temperature monitoring device equipped with a continuous recorder. The temperature monitoring device shall have a minimum accuracy of +-1 percent of the temperature being monitored in degrees C, or +-2.8 degrees C, whichever value is greater. The temperature sensor shall be installed at a location in the exhaust vent stream from the condenser.
	(F) * * *
	(1) A continuous parameter monitoring system to measure and record the average total regeneration stream mass flow or volumetric flow during each carbon bed regeneration cycle. The flow sensor must have a measurement sensitivity of 5 percent of the flow rate or 10 cubic feet per minute, whichever is greater. The mechanical connections for leakage must be checked at least every month, and a visual inspection must be performed at least every 3 months of all components of the flow CPMS for physical and operational integrity and all electrical connections for oxidation and galvanic corrosion if your flow CPMS is not equipped with a redundant flow sensor; and
	(2) A continuous parameter monitoring system to measure and record the average carbon bed temperature for the duration of the carbon bed steaming cycle and to measure the actual carbon bed temperature after regeneration and within 15 minutes of completing the cooling cycle. The temperature monitoring device shall have a minimum accuracy of +-1 percent of the temperature being monitored in degrees C, or +-2.5 degrees C, whichever value is greater.
	(G) For a nonregenerative-type carbon adsorption system, the owner or operator shall monitor the design carbon replacement interval established using a performance test performed in accordance with §63.772(e)(3) shall be based on the total carbon working capacity of the control device and source operating schedule.
	(H) For a control device model tested under §63.772(h):
	(1) A continuous monitoring system that measures gas flow rate at the inlet to the control device. The monitoring instrument shall have an accuracy of plus or minus 2 percent or better.
	(2) A heat sensing monitoring device equipped with a continuous recorder that indicates the continuous ignition of the pilot flame.
* * * * *
	(4) Using the data recorded by the monitoring system, the owner or operator must calculate the daily average value for each monitored operating parameter for each operating day. If the emissions unit operation is continuous, the operating day is a 24-hour period. If the emissions unit operation is not continuous, the operating day is the total number of hours of control device operation per 24-hour period. Valid data points must be available for 75 percent of the operating hours in an operating day to compute the daily average.
	(5) For each operating parameter monitor installed in accordance with the requirements of paragraph (d)(3) of this section, the owner or operator shall comply with paragraph (d)(5)(i) of this section for all control devices, and when condensers are installed, the owner or operator shall also comply with paragraph (d)(5)(ii) of this section.
	(i) The owner or operator shall establish a minimum operating parameter value or a maximum operating parameter value, as appropriate for the control device, to define the conditions at which the control device must be operated to continuously achieve the applicable performance requirements of §63.771(d)(1), (e)(3)(ii) or (f)(1). Each minimum or maximum operating parameter value shall be established as follows:
	(A) If the owner or operator conducts performance tests in accordance with the requirements of §63.772(e)(3) to demonstrate that the control device achieves the applicable performance requirements specified in §63.771(d)(1), (e)(3)(ii) or (f)(1), then the minimum operating parameter value or the maximum operating parameter value shall be established based on values measured during the performance test and supplemented, as necessary, by a condenser design analysis or control device manufacturer recommendations or a combination of both.
	(B) If the owner or operator uses a condenser design analysis in accordance with the requirements of §63.772(e)(4) to demonstrate that the control device achieves the applicable performance requirements specified in §63.771(d)(1), (e)(3)(ii) or (f)(1), then the minimum operating parameter value or the maximum operating parameter value shall be established based on the condenser design analysis and may be supplemented by the condenser manufacturer's recommendations.
	(C) If the owner or operator operates a control device where the performance test was conducted under §63.772(h) to demonstrate that the control device achieves the applicable performance requirements specified in §63.771(d)(1), (e)(3)(ii) or (f)(1), then the maximum inlet gas flow rate shall be established based on the performance test and supplemented, as necessary, by the manufacturer recommendations.
	(ii) * * *
	(A) If the owner or operator conducts a performance test in accordance with the requirements of §63.772(e)(3) to demonstrate that the condenser achieves the applicable performance requirements in §63.771(d)(1), (e)(3)(ii) or (f)(1), then the condenser performance curve shall be based on values measured during the performance test and supplemented as necessary by control device design analysis, or control device manufacturer's recommendations, or a combination or both.
	(B) If the owner or operator uses a control device design analysis in accordance with the requirements of §63.772(e)(4)(i) to demonstrate that the condenser achieves the applicable performance requirements specified in §63.771(d)(1), (e)(3)(ii) or (f)(1), then the condenser performance curve shall be based on the condenser design analysis and may be supplemented by the control device manufacturer's recommendations.
	(C) As an alternative to paragraph (d)(5)(ii)(B) of this section, the owner or operator may elect to use the procedures documented in the GRI report entitled, "Atmospheric Rich/Lean Method for Determining Glycol Dehydrator Emissions" (GRI - 95/0368.1) as inputs for the model GRI-GLYCalc[TM] , Version 3.0 or higher, to generate a condenser performance curve.
* * * * *
	(6) * * *
* * * * *
	(ii) For sources meeting §63.771(d)(1)(ii), an excursion occurs when the 365-day average condenser efficiency calculated according to the requirements specified in §63.772(g)(2)(iii) is less than 95.0 percent. For sources meeting §63.771(f)(1), an excursion occurs when the 365-day average condenser efficiency calculated according to the requirements specified in §63.772(g)(2)(iii) is less than 95.0 percent of the identified 365-day required percent reduction.
	(iii) For sources meeting §63.771(d)(1)(ii), if an owner or operator has less than 365 days of data, an excursion occurs when the average condenser efficiency calculated according to the procedures specified in §63.772(g)(2)(iii)(A) or (B) is less than 90.0 percent. For sources meeting §63.771(d)(1)(ii), an excursion occurs when the 365-day average condenser efficiency calculated according to the requirements specified in §63.772(g)(2)(iii) is less than the identified 365-day required percent reduction.
* * * * *
	(vi) For control device models tested under §63.772(h) an excursion occurs when:
	(A) The inlet gas flow rate exceeds the maximum established during the test conducted under §63.772(h).
	(B) Failure of the monthly visible emissions test conducted under §63.772(i)(3) occurs.
* * * * *
	(8) * * *
	(i) * * *
	(A) During a malfunction when the affected facility is operated during such period in accordance with §63.6(e)(1); or
* * * * *
	(ii) For each control device, or combinations of control devices installed on the same emissions unit, one excused excursion is allowed per semiannual period for any reason. The initial semiannual period is the 6-month reporting period addressed by the first Periodic Report submitted by the owner or operator in accordance with §63.775(e) of this subpart.
* * * * *
	20. Section 63.774 is amended by:
	a. Revising paragraph (b)(3) introductory text;
	b. Deleting and reserving paragraph (b)(3)(ii);
	c. Revising paragraph (b)(4)(ii) introductory text;
	d. Adding paragraph (b)(4)(ii)(C);
	e. Adding paragraph (b)(7)(ix); and
	f. Adding paragraphs (g) and (h) to read as follows:
§63.774 Recordkeeping requirements.
* * * * *
	(b) * * *
* * * * *
	(3) Records specified in §63.10(c) for each monitoring system operated by the owner or operator in accordance with the requirements of §63.773(d). Notwithstanding the requirements of §63.10(c), monitoring data recorded during periods identified in paragraphs (b)(3)(i) through (b)(3)(iv) of this section shall not be included in any average or percent leak rate computed under this subpart. Records shall be kept of the times and durations of all such periods and any other periods during process or control device operation when monitors are not operating or failed to collect required data.
* * * * *
	(ii) [Reserved]
* * * * *
	(4) * * *
* * * * *
	(ii) Records of the daily average value of each continuously monitored parameter for each operating day determined according to the procedures specified in §63.773(d)(4) of this subpart, except as specified in paragraphs (b)(4)(ii)(A) through (C) of this section.
* * * * *
	(C) For control device model tested under §63.772(h), the records required in paragraph (h) of this section.
* * * * *	(7) * * *
	(ix)  Records identifying the carbon replacement schedule under §63.771(d)(5) and records of each carbon replacement.
* * * * *
	(g) The owner or operator of an affected source subject to this subpart shall maintain records of the occurrence and duration of each malfunction of operation (i.e., process equipment) or the air pollution control equipment and monitoring equipment. The owner or operator shall maintain records of actions taken during periods of malfunction to minimize emissions in accordance with §63.764(a), including corrective actions to restore malfunctioning process and air pollution control and monitoring equipment to its normal or usual manner of operation.
	(h) Record the following when using a control device tested under §63.772(h) to comply with §63.771(d), (e)(3)(ii) or (f)(1):
	(1) All visible emission readings and flowrate measurements made during the compliance determination required by §63.772(i); and
	(2) All hourly records and other recorded periods when the pilot flame is absent.
	21. Section 63.775 is amended by:
	a. Revising paragraph (b)(1);
	b. Revising paragraph (b)(6);
	c. Deleting and reserving paragraph (b)(7);
	d. Revising paragraph (c)(1);
	e. Revising paragraph (c)(6);
	f. Revising paragraph (c)(7)(i);
	g. Revising paragraph (d)(1) introductory text;
	h. Revising paragraph (d)(1)(i);
	i. Revising paragraph (d)(1)(ii) introductory text;
	j. Revising paragraph (d)(1)(iii);
	k. Adding paragraph (d)(1)(iv);
	l. Revising paragraph (d)(2)(ii);
	m. Adding paragraph (d)(5)(iv);
	n. Revising paragraph (d)(11);
	o. Adding paragraphs (d)(13) and (d)(14);
	p. Revising paragraphs (e)(2)(ii)(B) and (C);
	q. Adding paragraphs (e)(2)(ii)(E) and (F);
	r. Adding paragraphs (e)(2)(xi) and (xii); and
	s. Adding paragraph (g) to read as follows:
§63.775 Reporting requirements.
* * * * *
	(b) * * *
	(1) The initial notifications required for existing affected sources under §63.9(b)(2) shall be submitted as provided in paragraphs (b)(1)(i) and (ii) of this section.
	(i) Except as otherwise provided in paragraph (ii), the initial notifications shall be submitted by 1 year after an affected source becomes subject to the provisions of this subpart or by June 17, 2000, whichever is later. Affected sources that are major sources on or before June 17, 2000 and plan to be area sources by June 17, 2002 shall include in this notification a brief, nonbinding description of a schedule for the action(s) that are planned to achieve area source status.
	(ii) An affected source identified under §63.760(f)(7) or (9) shall submit an initial notification required for existing affected sources under §63.9(b)(2) within 1 year after the affected source becomes subject to the provisions of this subpart or by one year after publication of the final rule in the Federal Register, whichever is later. An affected source identified under §63.760(f)(7) or (9) that plans to be an area source by 3 years after publication of the final rule in the Federal Register, shall include in this notification a brief, nonbinding description of a schedule for the action(s) that are planned to achieve area source status.
* * * * *
	(6) If there was a malfunction during the reporting period, the Periodic Report specified in paragraph (e) of this section shall include the number, duration, and a brief description for each type of malfunction which occurred during the reporting period and which caused or may have caused any applicable emission limitation to be exceeded. The report must also include a description of actions taken by an owner or operator during a malfunction of an affected source to minimize emissions in accordance with §63.764(j), including actions taken to correct a malfunction.* * * * *
	(c) * * *
	(1) The initial notifications required under §63.9(b)(2) not later than January 3, 2008. In addition to submitting your initial notification to the addressees specified under §63.9(a), you must also submit a copy of the initial notification to the EPA's Office of Air Quality Planning and Standards. Send your notification via email to Oil and Gas<EMAIL_ADDRESS>or via U.S. mail or other mail delivery service to U.S. EPA, Sector Policies and Programs Division/Fuels and Incineration Group (E143 - 01), Attn: Oil and Gas Project Leader, Research Triangle Park, NC 27711.
* * * * *
	(6) If there was a malfunction during the reporting period, the Periodic Report specified in paragraph (e) of this section shall include the number, duration, and a brief description for each type of malfunction which occurred during the reporting period and which caused or may have caused any applicable emission limitation to be exceeded. The report must also include a description of actions taken by an owner or operator during a malfunction of an affected source to minimize emissions in accordance with §63.764(j), including actions taken to correct a malfunction.
	(7) * * *
	(i) Documentation of the source's location relative to the nearest UA plus offset and UC boundaries. This information shall include the latitude and longitude of the affected source; whether the source is located in an urban cluster with 10,000 people or more; the distance in miles to the nearest urbanized area boundary if the source is not located in an urban cluster with 10,000 people or more; and the name of the nearest urban cluster with 10,000 people or more and nearest urbanized area.
* * * * *
	(d) * * *
	(1) If a closed-vent system and a control device other than a flare are used to comply with §63.764, the owner or operator shall submit the information in paragraph (d)(1)(iv) of this section and the information in either paragraph (d)(1)(i), (ii) or (iii) of this section.	(i) The condenser design analysis documentation specified in §63.772(e)(4) of this subpart, if the owner or operator elects to prepare a design analysis.
	(ii) If the owner or operator is required to conduct a performance test, the performance test results including the information specified in paragraphs (d)(1)(ii)(A) and (B) of this section. Results of a performance test conducted prior to the compliance date of this subpart can be used provided that the test was conducted using the methods specified in §63.772(e)(3) and that the test conditions are representative of current operating conditions.
* * * * *
	(iii) If the owner or operator operates a combustion control device model tested under §63.772(h), an electronic copy of the performance test results shall be submitted via email to Oil and Gas<EMAIL_ADDRESS>	(iv) The results of the closed-vent system initial inspections performed according to the requirements in §63.773(c)(2)(i) and (ii).
	(2) * * *
* * * * *
	(ii) A statement of whether a flame, as defined in this subpart, was present at the pilot light over the full period of the compliance determination.
	(5) * * *
* * * * *
	(ii) An explanation of the rationale for why the owner or operator selected each of the operating parameter values established in §63.773(d)(5). This explanation shall include any data and calculations used to develop the value and a description of why the chosen value indicates that the control device is operating in accordance with the applicable requirements of §63.771(d)(1),  (e)(3)(ii) or (f)(1).
* * * * *
	(iv) For each carbon adsorber, the predetermined carbon replacement schedule as required in §63.771(d)(5)(i).
* * * * *
	(11) The owner or operator shall submit the analysis prepared under §63.771(e)(2) to demonstrate the conditions by which the facility will be operated to achieve the HAP emission reduction of 95.0 percent, or the BTEX limit in §63.765(b)(1)(iii), through process modifications or a combination of process modifications and one or more control devices.
* * * * *
	(13)  If the owner or operator installs a combustion control device model tested under the procedures in §63.772(h), the data listed under §63.772(h)(8).
      (14)  For each combustion control device model tested under §63.772(h), the information listed in paragraphs (d)(14)(i) through (vi) of this section.
      (i) Name, address and telephone number of the control device manufacturer.
      (ii) Control device model number.
      (iii) Control device serial number.
      (iv) Date of control device certification test.
      (v) Manufacturer's HAP destruction efficiency rating.
	(vi) Control device operating parameters, maximum allowable inlet gas flowrate.
	(e) * * *
* * * * *
	(2) * * *
* * * * *
	(ii) * * *
* * * * *
	(B) For each excursion caused when the 365-day average condenser control efficiency is less than the value specified in §63.773(d)(6)(ii), the report must include the 365-day average values of the condenser control efficiency, and the date and duration of the period that the excursion occurred.
	(C) For each excursion caused when condenser control efficiency is less than the value specified in §63.773(d)(6)(iii), the report must include the average values of the condenser control efficiency, and the date and duration of the period that the excursion occurred.
* * * * *
	(E) For each excursion caused when the inlet gas flow rate identified under §63.772(h) exceeds the maximum specified value, the report must include the values of the inlet gas identified and the date and duration of the period that the excursion occurred.
	(F) For each excursion caused when visible emissions determined under §63.772(i) exceed the maximum allowable duration, the report must include the date and duration of the period that the excursion occurred.
* * * * *
	(xi) The results of any periodic test as required in §63.772(e)(3) conducted during the reporting period.
	(xii) For each carbon adsorber used to meet the control device requirements of §63.771(d)(1), records of each carbon replacement that occurred during the reporting period.
* * * * *
	(g) Electronic Reporting. (1) As of January 1, 2012 and within 60 days after the date of completing each performance test, as defined in §63.2 and as required in this subpart, you must submit performance test data, except opacity data, electronically to the EPA's Central Data Exchange (CDX) by using the Electronic Reporting Tool (ERT) (see http://www.epa.gov/ttn/chief/ert/ert tool.html/). Only data collected using test methods compatible with ERT are subject to this requirement to be submitted electronically into the EPA's WebFIRE database.
	 (2) All reports required by this subpart not subject to the requirements in paragraphs (g)(1) of this section must be sent to the Administrator at the appropriate address listed in §63.13. If acceptable to both the Administrator and the owner or operator of a source, these reports may be submitted on electronic media. The Administrator retains the right to require submittal of reports subject to paragraph (g)(1) of this section in paper format.
* * * * *
	22. Appendix to subpart HH of part 63  -  Tables is amended by revising Table 2 to read as follows:
Appendix to Subpart HH of Part 63 -- Tables
* * * * *

Table 2 to Subpart HH of Part 63 -- Applicability of 40 CFR Part 63 General Provisions to Subpart HH

                         General provisions reference
                           Applicable to subpart HH
                                  Explanation
§63.1(a)(1)
Yes.

§63.1(a)(2)
Yes.

§63.1(a)(3)
Yes.

§63.1(a)(4)
Yes.

§63.1(a)(5)
No
Section reserved.
§63.1(a)(6)
Yes.

§63.1(a)(7) through
(a)(9)
No
Section reserved.
§63.1(a)(10)
Yes.

§63.1(a)(11)
Yes.

§63.1(a)(12)
Yes.

§63.1(b)(1)
No
Subpart HH specifies applicability.
§63.1(b)(2)
No
Section reserved.
§63.1(b)(3)
Yes.

§63.1(c)(1)
No
Subpart HH specifies applicability.
§63.1(c)(2)
Yes.
Subpart HH exempts area sources from the requirement to obtain a Title V permit unless otherwise required by law as specified in §63.760(h).
§63.1(c)(3) and (c)(4)
No
Section reserved.
§63.1(c)(5)
Yes.

§63.1(d)
No
Section reserved.
§63.1(e)
Yes.

§63.2
Yes
Except definition of major source is unique for this source category and there are additional definitions in subpart HH.
§63.3(a) through (c)
Yes.

§63.4(a)(1) through
(a)(2)
Yes.

§63.4(a)(3) through
(a)(5)
No
Section reserved.
§63.4(b)
Yes.

§63.4(c)
Yes.

§63.5(a)(1)
Yes.

§63.5(a)(2)
Yes.

§63.5(b)(1)
Yes.

§63.5(b)(2)
No
Section reserved.
§63.5(b)(3)
Yes.

§63.5(b)(4)
Yes.

§63.5(b)(5)
No
Section Reserved.
§63.5(b)(6)
Yes.

§63.5(c)
No
Section reserved.
§63.5(d)(1)
Yes.

§63.5(d)(2)
Yes.

§63.5(d)(3)
Yes.

§63.5(d)(4)
Yes.

§63.5(e)
Yes.

§63.5(f)(1)
Yes.

§63.5(f)(2)
Yes.

§63.6(a)
Yes.

§63.6(b)(1)
Yes.

§63.6(b)(2)
Yes.

§63.6(b)(3)
Yes.

§63.6(b)(4)
Yes.

§63.6(b)(5)
Yes.

§63.6(b)(6)
No
Section reserved.
§63.6(b)(7)
Yes.

§63.6(c)(1)
Yes.

§63.6(c)(2)
Yes.

§63.6(c)(3) through
(c)(4)
No
Section reserved.
§63.6(c)(5)
Yes.

§63.6(d)
No
Section reserved.
§63.6(e)
Yes.

§63.6(e)(1)(i)
No
See §63.764(j) for general duty requirement.
§63.6(e)(1)(ii)
No.

§63.6(e)(1)(iii)
Yes.

§63.6(e)(2)
No
Section reserved.
§63.6(e)(3)
No.

§63.6(f)(1)
No

§63.6(f)(2)
Yes.

§63.6(f)(3)
Yes.

§63.6(g)
Yes.

§63.6(h)
No
Subpart HH does not contain opacity or visible emission standards.
§63.6(i)(1) through
(i)(14)
Yes.

§63.6(i)(15)
No
Section reserved.
§63.6(i)(16)
Yes.

§63.6(j)
Yes.

§63.7(a)(1)
Yes.

§63.7(a)(2)
Yes
But the performance test results must be submitted within 180 days after the compliance date.
§63.7(a)(3)
Yes.

§63.7(b)
Yes.

§63.7(c)
Yes.

§63.7(d)
Yes.

§63.7(e)(1)
No.

§63.7(e)(2)
Yes.

§63.7(e)(3)
Yes.

§63.7(e)(4)
Yes.

§63.7(f)
Yes.

§63.7(g)
Yes.

§63.7(h)
Yes.

§63.8(a)(1)
Yes.

§63.8(a)(2)
Yes.

§63.8(a)(3)
No
Section reserved.
§63.8(a)(4)
Yes.

§63.8(b)(1)
Yes.

§63.8(b)(2)
Yes.

§63.8(b)(3)
Yes.

§63.8(c)(1)
No.

§63.8(c)(1)(i)
§63.8(c)(1)(ii)
§63.8(c)(1)(iii)
No.
Yes.
Pending

§63.8(c)(2)
Yes.

§63.8(c)(3)
Yes.

§63.8(c)(4)
Yes.

§63.8(c)(4)(i)
No
Subpart HH does not require continuous opacity monitors.
§63.8(c)(4)(ii)
Yes.

§63.8(c)(5) through
(c)(8)
Yes.

§63.8(d)
Yes.

§63.8(d)(3)
Yes.
Except for last sentence, which refers to an SSM plan. SSM plans are not required.
§63.8(e)
Yes
Subpart HH does not specifically require continuous emissions monitor performance evaluation, however, the Administrator can request that one be conducted.
§63.8(f)(1) through
(f)(5)
Yes.

§63.8(f)(6)
Yes.

§63.8(g)
No
Subpart HH specifies continuous monitoring system data reduction requirements.
§63.9(a)
Yes.

§63.9(b)(1)
Yes.

§63.9(b)(2)
Yes
Existing sources are given 1 year (rather than 120 days) to submit this notification. Major and area sources that meet §63.764(e) do not have to submit initial notifications.
§63.9(b)(3)
No
Section reserved.
§63.9(b)(4)
Yes.

§63.9(b)(5)
Yes.

§63.9(c)
Yes.

§63.9(d)
Yes.

§63.9(e)
Yes.

§63.9(f)
No
Subpart HH does not have opacity or visible emission standards.
§63.9(g)(1)
Yes.

§63.9(g)(2)
No
Subpart HH does not have opacity or visible emission standards.
§63.9(g)(3)
Yes.

§63.9(h)(1) through
(h)(3)
Yes
Area sources located outside UA plus offset and UC boundaries are not required to submit notifications of compliance status.
§63.9(h)(4)
No
Section reserved.
§63.9(h)(5) through
(h)(6)
Yes.

§63.9(i)
Yes.

§63.9(j)
Yes.

§63.10(a)
Yes.

§63.10(b)(1)
Yes
§63.774(b)(1) requires sources to maintain the most recent 12 months of data on-site and allows offsite storage for the remaining 4 years of data.
§63.10(b)(2)
Yes.

§63.10(b)(2)(i)
No.

§63.10(b)(2)(ii)
No
See §63.774(g) for recordkeeping of occurrence, duration, and actions taken during malfunctions.
§63.10(b)(2)(iii)
Yes.

§63.10(b)(2)(iv)
through (b)(2)(v)
No.

§63.10(b)(2)(vi)
through (b)(2)(xiv)
Yes.

§63.10(b)(3)
Yes
§63.774(b)(1) requires sources to maintain the most recent 12 months of data on-site and allows offsite storage for the remaining 4 years of data.
§63.10(c)(1)
Yes.

§63.10(c)(2) through
(c)(4)
No
Sections reserved.
§63.10(c)(5) through (8) (c)(8)
Yes.

§63.10(c)(9)
No
Section reserved.
§63.10(c)(10) through
(11)
No
See §63.774(g) for recordkeeping of malfunctions.
§63.10(c)(12) through (14)
Yes.

§63.10(c)(15)
No.

§63.10(d)(1)
Yes.

§63.10(d)(2)
Yes
Area sources located outside UA plus offset and UC boundaries do not have to submit performance test reports.
§63.10(d)(3)
Yes.

§63.10(d)(4)
Yes.

§63.10(d)(5)
No
See §63.775(b)(6) or (c)(6) for reporting of malfunctions.
§63.10(e)(1)
Yes
Area sources located outside UA plus offset and UC boundaries are not required to submit reports.
§63.10(e)(2)
Yes
Area sources located outside UA plus offset and UC boundaries are not required to submit reports.
§63.10(e)(3)(i)
Yes
Subpart HH requires major sources to submit Periodic Reports semi-annually. Area sources are required to submit Periodic Reports annually. Area sources located outside UA plus offset and UC boundaries are not required to submit reports.
§63.10(e)(3)(i)(A)
Yes.

§63.10(e)(3)(i)(B)
Yes.

§63.10(e)(3)(i)(C)
No
Section reserved.
§63.10(e)(3)(ii)
through (viii)
Yes.

§63.10(f)
Yes.

§63.11(a) and (b)
Yes.

§63.11(c), (d), and (e)
Yes.

§63.12(a) through (c)
Yes.

§63.13(a) through (c)
Yes.

§63.14(a) and (b)
Yes.

§63.15(a) and (b)
Yes.

§63.16
Yes.

Subpart HHH  -  [Amended]
	23. Section 63.1270 is amended by:
	a. Revising paragraph (a) introductory text;
	b. Revising paragraph (a)(4);
	c. Revising paragraphs (d)(1) and (d)(2); and
	d. Adding paragraphs (d)(3) and (d)(4) to read as follows:
§63.1270 Applicability and designation of affected source.
	(a) This subpart applies to owners and operators of natural gas transmission and storage facilities that transport or store natural gas prior to entering the pipeline to a local distribution company or to a final end user (if there is no local distribution company), and that are major sources of hazardous air pollutants (HAP) emissions as defined in §63.1271. Emissions for major source determination purposes can be estimated using the maximum natural gas throughput calculated in either paragraph (a)(1) or (2) of this section and paragraphs (a)(3) and (4) of this section. As an alternative to calculating the maximum natural gas throughput, the owner or operator of a new or existing source may use the facility design maximum natural gas throughput to estimate the maximum potential emissions. Other means to determine the facility's major source status are allowed, provided the information is documented and recorded to the Administrator's satisfaction in accordance with §63.10(b)(3). A compressor station that transports natural gas prior to the point of custody transfer or to a natural gas processing plant (if present) is not considered a part of the Natural Gas Transmission and Storage source category. A facility that is determined to be an area source, but subsequently increases its emissions or its potential to emit above the major source levels (without obtaining and complying with other limitations that keep its potential to emit HAP below major source levels), and becomes a major source, must comply thereafter with all applicable provisions of this subpart starting on the applicable compliance date specified in paragraph (d) of this section. Nothing in this paragraph is intended to preclude a source from limiting its potential to emit through other appropriate mechanisms that may be available through the permitting authority.
* * * * *
	(4) The owner or operator shall determine the maximum values for other parameters used to calculate potential emissions as the maximum over the same period for which maximum throughput is determined as specified in paragraph (a)(1) or (a)(2) of this section. These parameters shall be based on an annual average or the highest single measured value. For estimating maximum potential emissions from glycol dehydration units, the glycol circulation rate used in the calculation shall be the unit's maximum rate under its physical and operational design consistent with the definition of potential to emit in §63.2.
* * * * *
	(d) * * *
	(1) Except as specified in paragraphs (d)(3) and (4) of this section, the owner or operator of an affected source, the construction or reconstruction of which commenced before February 6, 1998, shall achieve compliance with this provisions of the subpart no later than June 17, 2002 except as provided for in §63.6(i). The owner or operator of an area source, the construction or reconstruction of which commenced before February 6, 1998, that increases its emissions of (or its potential to emit) HAP such that the source becomes a major source that is subject to this subpart shall comply with this subpart 3 years after becoming a major source.
	(2) Except as specified in paragraphs (d)(3) and (4) of this section, the owner or operator of an affected source, the construction or reconstruction of which commences on or after February 6, 1998, shall achieve compliance with the provisions of this subpart immediately upon initial startup or June 17, 1999, whichever date is later. Area sources, the construction or reconstruction of which commences on or after February 6, 1998, that become major sources shall comply with the provisions of this standard immediately upon becoming a major source.
	(3)  Each affected small glycol dehydration unit, as defined in §63.1271, located at a major source, that commenced construction before [INSERT DATE OF PUBLICATION IN THE FEDERAL REGISTER] must achieve compliance no later than 3 years after the date of publication of the final rule in the Federal Register, except as provided in §63.6(i).
	(4) Each affected small glycol dehydration unit, as defined in §63.1271, located at a major source, that commenced construction on or after [INSERT DATE OF PUBLICATION IN THE FEDERAL REGISTER] must achieve compliance immediately upon initial startup or the date of publication of the final rule in the Federal Register, whichever is later.
* * * * *
	24. Section 63.1271 is amended by:
	a. Adding a definition for "affirmative defense" in alphabetical order;
	b. Adding a definition for "BTEX" in alphabetical order;
	c. Adding a definition for "flare" in alphabetical order;
	d. Revising the definition for "glycol dehydration unit baseline operations";
	e. Adding a definition for "large glycol dehydration units" in alphabetical order;
	f. Adding a definition for "small glycol dehydration units" in alphabetical order; and
	(g) Revising the definition of "temperature monitoring device" to read as follows:
§63.1271 Definitions.
* * * * *
	Affirmative defense means, in the context of an enforcement proceeding, a response or defense put forward by a defendant, regarding which the defendant has the burden of proof, and the merits of which are independently and objectively evaluated in a judicial or administrative proceeding.
* * * * *
	BTEX means benzene, toluene, ethyl benzene and xylene.
* * * * *
	Flare means a thermal oxidation system using an open flame (i.e., without enclosure).
* * * * *
	Glycol dehydration unit baseline operations means operations representative of the large glycol dehydration unit operations as of June 17, 1999 and the small glycol dehydration unit operations as of [INSERT DATE OF PUBLICATION IN THE FEDERAL REGISTER]. For the purposes of this subpart, for determining the percentage of overall HAP emission reduction attributable to process modifications, glycol dehydration unit baseline operations shall be parameter values (including, but not limited to, glycol circulation rate or glycol-HAP absorbency) that represent actual long-term conditions (i.e., at least 1 year). Glycol dehydration units in operation for less than 1 year shall document that the parameter values represent expected long-term operating conditions had process modifications not been made.
* * * * *
	Large glycol dehydration unit means a glycol dehydration unit with an actual annual average natural gas flowrate equal to or greater than 283.0 thousand standard cubic meters per day and actual annual average benzene emissions equal to or greater than 0.90 Mg/yr, determined according to §63.1282(a).
* * * * *
	Small glycol dehydration unit means a glycol dehydration unit, located at a major source, with an actual annual average natural gas flowrate less than 283.0 thousand standard cubic meters per day or actual annual average benzene emissions less than 0.90 Mg/yr, determined according to §63.1282(a).
	Temperature monitoring device means an instrument used to monitor temperature and having a minimum accuracy of +-1 percent of the temperature being monitored expressed in °C, or +-2.5 °C, whichever is greater. The temperature monitoring device may measure temperature in degrees Fahrenheit or degrees Celsius, or both.
	25. Section 63.1272 is amended by:
	a. Revising paragraph (a) through (d); and
	b. Deleting paragraph (e) to read as follows:
§63.1272 Startups and shutdowns.
	(a) The provisions set forth in this subpart shall apply at all times.
	(b) The owner or operator shall not shut down items of equipment that are required or utilized for compliance with the provisions of this subpart during times when emissions are being routed to such items of equipment, if the shutdown would contravene requirements of this subpart applicable to such items of equipment. This paragraph does not apply if the owner or operator must shut down the equipment to avoid damage due to a contemporaneous startup or shutdown of the affected source or a portion thereof.
	(c) During startups and shutdowns, the owner or operator shall implement measures to prevent or minimize excess emissions to the maximum extent practical.
	(d) In response to an action to enforce the standards set forth in this subpart, you may assert an affirmative defense to a claim for civil penalties for exceedances of such standards that are caused by malfunction, as defined in §63.2. Appropriate penalties may be assessed, however, if you fail to meet your burden of proving all the requirements in the affirmative defense. The affirmative defense shall not be available for claims for injunctive relief.
	(1) To establish the affirmative defense in any action to enforce such a limit, the owner or operator must timely meet the notification requirements in paragraph (d)(2) of this section, and must prove by a preponderance of evidence that:
	(i) The excess emissions:
	(A) Were caused by a sudden, infrequent and unavoidable failure of air pollution control and monitoring equipment, process equipment or a process to operate in a normal or usual manner; and
	(B) Could not have been prevented through careful planning, proper design or better operation and maintenance practices; and
	(C) Did not stem from any activity or event that could have been foreseen and avoided, or planned for; and
	(D) Were not part of a recurring pattern indicative of inadequate design, operation, or maintenance; and
	(ii) Repairs were made as expeditiously as possible when the applicable emission limitations were being exceeded. Off-shift and overtime labor were used, to the extent practicable to make these repairs; and
	(iii) The frequency, amount and duration of the excess emissions (including any bypass) were minimized to the maximum extent practicable during periods of such emissions; and
	(iv) If the excess emissions resulted from a bypass of control equipment or a process, then the bypass was unavoidable to prevent loss of life, personal injury, or severe property damage; and
	(v) All possible steps were taken to minimize the impact of the excess emissions on ambient air quality, the environment, and human health; and
	(vi) All emissions monitoring and control systems were kept in operation if at all possible, consistent with safety and good air pollution control practices; and
	(vii) All of the actions in response to the excess emissions were documented by properly signed, contemporaneous operating logs; and
	(viii) At all times, the affected source was operated in a manner consistent with good practices for minimizing emissions; and
	(ix) A written root cause analysis has been prepared to determine, correct, and eliminate the primary causes of the malfunction and the excess emissions resulting from the malfunction event at issue. The analysis shall also specify, using best monitoring methods and engineering judgment, the amount of excess emissions that were the result of the malfunction.
	(2) Notification. The owner or operator of the affected source experiencing an exceedance of its emission limit(s) during a malfunction shall notify the Administrator by telephone or facsimile transmission as soon as possible, but no later than two business days after the initial occurrence of the malfunction, if it wishes to avail itself of an affirmative defense to civil penalties for that malfunction. The owner or operator seeking to assert an affirmative defense shall also submit a written report to the Administrator within 45 days of the initial occurrence of the exceedance of the standard in this subpart to demonstrate, with all necessary supporting documentation, that it has met the requirements set forth in paragraph (d)(1) of this section. The owner or operator may seek an extension of this deadline for up to 30 additional days by submitting a written request to the Administrator before the expiration of the 45 day period. Until a request for an extension has been approved by the Administrator, the owner or operator is subject to the requirement to submit such report within 45 days of the initial occurrence of the exceedance.
* * * * *
	26. Section 63.1274 is amended by:
	a. Revising paragraph (c) introductory text;
	b. Deleting and reserving paragraph (d);
	c. Revising paragraph (g); and
	d. Adding paragraph (h) to read as follows:
§63.1274 General standards.
* * * * *
	(c) The owner or operator of an affected source (i.e., glycol dehydration unit) located at an existing or new major source of HAP emissions shall comply with the requirements in this subpart as follows:
* * * * *
	(d) [RESERVED]
* * * * *
	(g) In all cases where the provisions of this subpart require an owner or operator to repair leaks by a specified time after the leak is detected, it is a violation of this standard to fail to take action to repair the leak(s) within the specified time. If action is taken to repair the leak(s) within the specified time, failure of that action to successfully repair the leak(s) is not a violation of this standard. However, if the repairs are unsuccessful, and a leak is detected, the owner or operator shall take further action as required by the applicable provisions of this subpart.
	(h) At all times the owner or operator must operate and maintain any affected source, including associated air pollution control equipment and monitoring equipment, in a manner consistent with safety and good air pollution control practices for minimizing emissions. Determination of whether such operation and maintenance procedures are being used will be based on information available to the Administrator which may include, but is not limited to, monitoring results, review of operation and maintenance procedures, review of operation and maintenance records, and inspection of the source.
	27. Section 63.1275 is amended by:
	a. Revising paragraph (a);
	b. Revising paragraph (b)(1) introductory text;
	c. Revising paragraph (b)(1)(i);
	d. Deleting and reserving paragraph (b)(1)(ii);
	e. Adding paragraph (b)(1)(iii);
	f. Revising paragraph (c)(2);
	g. Revising paragraph (c)(3) introductory text;
	h. Revising paragraph (c)(1)(i);
	i. Deleting and reserving paragraph (c)(3)(ii); and
	j. Adding paragraph (c)(3)(iii) to read as follows:
§63.1275 Glycol dehydration unit process vent standards.
	(a) This section applies to each glycol dehydration unit subject to this subpart that must be controlled for air emissions as specified in paragraph (c)(1) of §63.1274.
	(b) * * *
	(1) For each glycol dehydration unit process vent, the owner or operator shall control air emissions by either paragraph (b)(1)(i) or (b)(1)(iii) of this section.
	(i) The owner or operator of a large glycol dehydration unit, as defined in §63.1271, shall connect the process vent to a control device or a combination of control devices through a closed-vent system. The closed-vent system shall be designed and operated in accordance with the requirements of §63.1281(c). The control device(s) shall be designed and operated in accordance with the requirements of §63.1281(d).
	(ii) [Reserved]
	(iii) You must limit BTEX emissions from each small glycol dehydration unit, as defined in §63.1271, to the limit determined in Equation 1 of this section. The limit must be met in accordance with one of the alternatives specified in paragraphs (b)(i)(iii)(A) through (D) of this section.
    Equation 1
Where:
ELBTEX = Unit-specific BTEX emission limit, megagrams per year;
6.42x10-5 = BTEX emission limit, grams BTEX/standard cubic meter -ppmv;
Throughput = Annual average daily natural gas throughput, standard cubic meters per day
Ci,BTEX = BTEX concentration of the natural gas at the inlet to the glycol dehydration unit, ppmv.

	(A) Connect the process vent to a control device or combination of control devices through a closed-vent system. The closed vent system shall be designed and operated in accordance with the requirements of §63.1281(c). The control device(s) shall be designed and operated in accordance with the requirements of §63.1281(f).
	(B) Meet the emissions limit through process modifications in accordance with the requirements specified in §63.1281(e).
      (C) Meet the emission limit for each small glycol dehydration unit using a combination of process modifications and one or more control devices through the requirements specified in paragraphs (b)(1)(iii)(A) and (B) of this section.
	(D) Demonstrate that the emissions limit is met through actual uncontrolled operation of the small glycol dehydration unit. Document operational parameters in accordance with the requirements specified in §63.1281(e) and emissions in accordance with the requirements specified in §63.1282(a)(3).
* * * * *
	(c) * * *
	(2) The owner or operator shall demonstrate, to the Administrator's satisfaction, that the total HAP emissions to the atmosphere from the large glycol dehydration unit process vent are reduced by 95.0 percent through process modifications or a combination of process modifications and one or more control devices, in accordance with the requirements specified in §63.1281(e).
	(3) Control of HAP emissions from a GCG separator (flash tank) vent is not required if the owner or operator demonstrates, to the Administrator's satisfaction, that total emissions to the atmosphere from the glycol dehydration unit process vent are reduced by one of the levels specified in paragraph (c)(3)(i) or (iii) through the installation and operation of controls as specified in paragraph (b)(1) of this section.
	(i) For any large glycol dehydration unit, HAP emissions are reduced by 95.0 percent or more.
	(ii) [Reserved]
	(iii) For each small glycol dehydration unit, BTEX emissions are reduced to a level less than the limit calculated by paragraph (b)(1)(iii) of this section.
	28. Section 63.1281 is amended by:
	a. Revising paragraph (c)(1);
	b. Revising paragraph (d)(1) introductory text;
	c. Revising paragraph (d)(1)(ii);
	d. Revising paragraph (d)(1)(i)(C);
	e. Revising paragraphs (d)(1)(ii) and (iii);
	f. Revising paragraph (d)(4)(i);
	g. Revising paragraph (d)(5)(i);
	h. Revising paragraph (e)(2);
	i. Revising paragraph (e)(3) introductory text;
	j. Revising paragraph (e)(3)(ii); and
	k. Adding paragraph (f) to read as follows:
§63.1281 Control equipment requirements.
* * * * *
	(c)* * *
	(1) The closed-vent system shall route all gases, vapors, and fumes emitted from the material in an emissions unit to a control device that meets the requirements specified in paragraph (d) of this section.
* * * * *
	(d) Control device requirements for sources except small glycol dehydration units. Owners and operators of small glycol dehydration units shall comply with the control requirements in paragraph (f) of this section.
	(1) * * *
	(i) An enclosed combustion device (e.g., thermal vapor incinerator, catalytic vapor incinerator, enclosed flare, boiler, or process heater) that is designed and operated in accordance with one of the following performance requirements:
* * * * *
	(C) For a control device that can demonstrate a combustion zone temperature during the performance test conducted under §63.772(e), operates at a minimum temperature of 760°C.
* * * * *
	(ii) A vapor recovery device (e.g., carbon adsorption system or condenser) or other non-destructive control device that is designed and operated to reduce the mass content of either TOC or total HAP in the gases vented to the device by 95.0 percent by weight or greater as determined in accordance with the requirements of §63.1282(d).
	(iii) A flare, as defined in §63.1271, that is designed and operated in accordance with the requirements of §63.11(b).
* * * * *
	(4) * * *
	(i) Each control device used to comply with this subpart shall be operating at all times. An owner or operator may vent more than one unit to a control device used to comply with this subpart.
	(5) * * *
	(i) Following the initial startup of the control device, all carbon in the control device shall be replaced with fresh carbon on a regular, predetermined time interval that is no longer than the carbon service life established for the carbon adsorption system. Records identifying the schedule for replacement and records of each carbon replacement shall be maintained as required in §63.1284(b)(7)(ix). The schedule for replacement shall be submitted with the Notification of Compliance Status Report as specified in §63.775(d)(4)(iv). Each carbon replacement must be reported in the Periodic Reports as specified in §63.1285(e)(2)(xi).
* * * * *
	(e) * * *
* * * * *
	(2) The owner or operator shall document, to the Administrator's satisfaction, the conditions for which glycol dehydration unit baseline operations shall be modified to achieve the 95.0 percent overall HAP emission reduction, or BTEX limit determined in §63.1275(b)(1)(iii), as applicable, either through process modifications or through a combination of process modifications and one or more control devices. If a combination of process modifications and one or more control devices are used, the owner or operator shall also establish the emission reduction to be achieved by the control device to achieve an overall HAP emission reduction of 95.0 percent for the glycol dehydration unit process vent or, if applicable, the BTEX limit determined in §63.1275(b)(1)(iii) for the small glycol dehydration unit process vent. Only modifications in glycol dehydration unit operations directly related to process changes, including but not limited to changes in glycol circulation rate or glycol-HAP absorbency, shall be allowed. Changes in the inlet gas characteristics or natural gas throughput rate shall not be considered in determining the overall emission reduction due to process modifications.
	(3) The owner or operator that achieves a 95.0 percent HAP emission reduction or meets the BTEX limit determined in §63.1275(b)(1)(iii), as applicable, using process modifications alone shall comply with paragraph (e)(3)(i) of this section. The owner or operator that achieves a 95.0 percent HAP emission reduction or meets the BTEX limit determined in §63.1275(b)(1)(iii), as applicable, using a combination of process modifications and one or more control devices shall comply with paragraphs (e)(3)(i) and (e)(3)(ii) of this section.
* * * * *
	(ii) The owner or operator shall comply with the control device requirements specified in paragraph (d) or (f) of this section, as applicable, except that the emission reduction or limit achieved shall be the emission reduction or limit specified for the control device(s) in paragraph (e)(2) of this section.
	(f) Control device requirements for small glycol dehydration units.
	(1) The control device used to meet BTEX the emission limit calculated in §63.1275(b)(1)(iii) shall be one of the control devices specified in paragraphs (f)(1)(i) through (iii) of this section.
	(i) An enclosed combustion device (e.g., thermal vapor incinerator, enclosed flare, catalytic vapor incinerator, boiler, or process heater) that is designed and operated to reduce the mass content of BTEX in the gases vented to the device as determined in accordance with the requirements of §63.1282(d). If a boiler or process heater is used as the control device, then the vent stream shall be introduced into the flame zone of the boiler or process heater; or
	(ii) A vapor recovery device (e.g., carbon adsorption system or condenser) or other non-destructive control device that is designed and operated to reduce the mass content of BTEX in the gases vented to the device as determined in accordance with the requirements of §63.1282(d); or
	(iii) A flare, as defined in §63.1271, that is designed and operated in accordance with the requirements of §63.11(b).
	(2) The owner or operator shall operate each control device in accordance with the requirements specified in paragraphs (f)(2)(i) and (ii) of this section.
	(i) Each control device used to comply with this subpart shall be operating at all times. An owner or operator may vent more than one unit to a control device used to comply with this subpart.
	(ii) For each control device monitored in accordance with the requirements of §63.1283(d), the owner or operator shall demonstrate compliance according to the requirements of either §63.1282(e) or (g).
	(3) For each carbon adsorption system used as a control device to meet the requirements of paragraph (f)(1) of this section, the owner or operator shall manage the carbon as required under (d)(5)(i) and (ii) of this section.
	29. Section 63.1282 is amended by:
	a. Revising paragraph (a) introductory text;
	b. Revising paragraph (a)(1)(ii);
	c. Revising paragraph (a)(2) introductory text;
	d. Revising paragraphs (a)(2)(i) and (ii);
	e. Adding paragraph (c);
	f. Revising paragraph (d) introductory text;
	g. Revising paragraphs (d)(1)(i) through (v);
	h. Revising paragraph (d)(2);
	i. Revising paragraph (d)(3) introductory text;
	j. Revising paragraph (d)(3)(i)(B);
	k. Revising paragraph (d)(3)(iv)(C)(1);
	l. Adding paragraphs (d)(3)(v) and (vi);
	m. Revising paragraph (d)(4) introductory text;
	n. Revising paragraph (d)(4)(i);
	o. Revising paragraph (d)(5);
	p. Revising paragraph (e) introductory text;
	q. Adding paragraphs (e)(2) through (e)(6);
	r. Revising paragraph (f) introductory text;
	s. Revising paragraph (f)(1);
	t. Revising paragraph (f)(2) introductory text;
	u. Revising paragraph (f)(2)(iii);
	v. Revising paragraph (f)(3); and
	w. Adding paragraphs (g) and (h) to read as follows:
§63.1282 Test methods, compliance procedures and compliance demonstrations.
	(a) Determination of glycol dehydration unit flowrate, benzene emissions or BTEX emissions. The procedures of this paragraph shall be used by an owner or operator to determine glycol dehydration unit natural gas flowrate, benzene emissions, or BTEX emissions.
	(1) * * *
* * * * *
	(ii) The owner or operator shall document, to the Administrator's satisfaction, the actual annual average natural gas flowrate to the glycol dehydration unit.
	(2) The determination of actual average benzene or BTEX emissions from a glycol dehydration unit shall be made using the procedures of either paragraph (a)(2)(i) or (a)(2)(ii) of this section. Emissions shall be determined either uncontrolled or with Federally enforceable controls in place.
	(i) The owner or operator shall determine actual average benzene or BTEX emissions using the model GRI-GLYCalc[TM] , Version 3.0 or higher, and the procedures presented in the associated GRI-GLYCalc[TM] Technical Reference Manual. Inputs to the model shall be representative of actual operating conditions of the glycol dehydration unit and may be determined using the procedures documented in the Gas Research Institute (GRI) report entitled "Atmospheric Rich/Lean Method for Determining Glycol Dehydrator Emissions" (GRI - 95/0368.1); or
	(ii) The owner or operator shall determine an average mass rate of benzene or BTEX emissions in kilograms per hour through direct measurement by performing three runs of Method 18 in 40 CFR part 60, appendix A (or an equivalent method), and averaging the results of the three runs. Annual emissions in kilograms per year shall be determined by multiplying the mass rate by the number of hours the unit is operated per year. This result shall be converted to megagrams per year.
* * * * *
	(c)  Test procedures and compliance demonstrations for small glycol dehydration units. This paragraph applies to the test procedures for small dehydration units.
	(1)  If the owner or operator is using a control device to comply with the emission limit in §63.1275(b)(1)(iii), the requirements of paragraph (d) of this section apply. Compliance is demonstrated using the methods specified in paragraph (e) of this section.
	(2) If no control device is used to comply with the emission limit in §63.1275(b)(1)(iii), the owner or operator must determine the glycol dehydration unit BTEX emissions as specified in paragraphs (c)(2)(i) through (iii) of this section. Compliance is demonstrated if the BTEX emissions determined as specified in paragraphs (c)(2)(i) through (iii) are less than the emission limit calculated using the equation in §63.1275(b)(1)(iii).
	(i) Method 1 or 1A, 40 CFR part 60, appendix A, as appropriate, shall be used for selection of the sampling sites at the outlet of the glycol dehydration unit process vent. Any references to particulate mentioned in Methods 1 and 1A do not apply to this section.
	(ii) The gas volumetric flowrate shall be determined using Method 2, 2A, 2C, or 2D, 40 CFR part 60, appendix A, as appropriate.
	(iii)  The BTEX emissions from the outlet of the glycol dehydration unit process vent shall be determined using the procedures specified in paragraph (d)(3)(v) of this section. As an alternative, the mass rate of BTEX at the outlet of the glycol dehydration unit process vent may be calculated using the model GRI-GLYCalc[TM] , Version 3.0 or higher, and the procedures presented in the associated GRI-GLYCalc[TM] Technical Reference Manual. Inputs to the model shall be representative of actual operating conditions of the glycol dehydration unit and shall be determined using the procedures documented in the Gas Research Institute (GRI) report entitled "Atmospheric Rich/Lean Method for Determining Glycol Dehydrator Emissions" (GRI - 95/0368.1). When the BTEX mass rate is calculated for glycol dehydration units using the model GRI-GLYCalc[TM] , all BTEX measured by Method 18, 40 CFR part 60, appendix A, shall be summed.
	(d) Control device performance test procedures. This paragraph applies to the performance testing of control devices. The owners or operators shall demonstrate that a control device achieves the performance requirements of §63.1281(d)(1), (e)(3)(ii), or (f)(1) using a performance test as specified in paragraph (d)(3) of this section. Owners or operators using a condenser have the option to use a design analysis as specified in paragraph (d)(4) of this section. The owner or operator may elect to use the alternative procedures in paragraph (d)(5) of this section for performance testing of a condenser used to control emissions from a glycol dehydration unit process vent. As an alternative to conducting a performance test under this section for combustion control devices, a control device that can be demonstrated to meet the performance requirements of §63.1281(d)(1), (e)(3)(ii), or (f)(1) through a performance test conducted by the manufacturer, as specified in paragraph (g) of this section, can be used.
	(1) * * *
	(i) Except as specified in paragraph (d)(2) of this section, a flare, as defined in §63.1271, that is designed and operated in accordance with §63.11(b);
	(ii) Except for control devices used for small glycol dehydration units, a boiler or process heater with a design heat input capacity of 44 megawatts or greater;
	(iii) Except for control devices used for small glycol dehydration units, a boiler or process heater into which the vent stream is introduced with the primary fuel or is used as the primary fuel;
	(iv) Except for control devices used for small glycol dehydration units, a boiler or process heater burning hazardous waste for which the owner or operator has either been issued a final permit under 40 CFR part 270 and complies with the requirements of 40 CFR part 266, subpart H, or has certified compliance with the interim status requirements of 40 CFR part 266, subpart H;
	(v) Except for control devices used for small glycol dehydration units, a hazardous waste incinerator for which the owner or operator has been issued a final permit under 40 CFR part 270 and complies with the requirements of 40 CFR part 264, subpart O, or has certified compliance with the interim status requirements of 40 CFR part 265, subpart O.
* * * * *
	(2) An owner or operator shall design and operate each flare, as defined in §63.1271, in accordance with the requirements specified in §63.11(b) and the compliance determination shall be conducted using Method 22 of 40 CFR part 60, appendix A, to determine visible emissions.
	(3) For a performance test conducted to demonstrate that a control device meets the requirements of §63.1281(d)(1), (e)(3)(ii), or (f)(1) the owner or operator shall use the test methods and procedures specified in paragraphs (d)(3)(i) through (v) of this section. The initial and periodic performance tests shall be conducted according to the schedule specified in paragraph (d)(3)(vi) of this section.
	(i) * * *
* * * * *
	(B) To determine compliance with the enclosed combustion device total HAP concentration limit specified in §63.1281(d)(1)(i)(B), or the BTEX emission limit specified in §63.1275(b)(1)(iii), the sampling site shall be located at the outlet of the combustion device.
* * * * *
	(iv) * * *
* * * * *
	(C) * * *
	(1)  The emission rate correction factor for excess air, integrated sampling and analysis procedures of Method 3A or 3B, 40 CFR part 60, appendix A, shall be used to determine the oxygen concentration. The samples shall be taken during the same time that the samples are taken for determining TOC concentration or total HAP concentration.
* * * * *
	(v) To determine compliance with the BTEX emission limit specified in §63.1281(f)(1) the owner or operator shall use one of the following methods: Method 18, 40 CFR part 60, appendix A;  ASTM D6420 - 99 (2004), as specified in §63.772(a)(1)(ii); or any other method or data that have been validated according to the applicable procedures in Method 301, 40 CFR part 63, appendix A. The following procedures shall be used to calculate BTEX emissions:
	(A) The minimum sampling time for each run shall be 1 hour in which either an integrated sample or a minimum of four grab samples shall be taken. If grab sampling is used, then the samples shall be taken at approximately equal intervals in time, such as 15-minute intervals during the run.
	(B) The mass rate of BTEX (Eo) shall be computed using the equations and procedures specified in paragraphs (d)(3)(v)(B)(1) and (2) of this section.
	(1) The following equation shall be used:

Where:
Eo= Mass rate of BTEX at the outlet of the control device, dry basis, kilogram per hour.
Coj= Concentration of sample component j of the gas stream at the outlet of the control device, dry basis, parts per million by volume.
Moj= Molecular weight of sample component j of the gas stream at the outlet of the control device, gram/gram-mole.
Qo= Flowrate of gas stream at the outlet of the control device, dry standard cubic meter per minute.
K2= Constant, 2.494x10[−6] (parts per million) (gram-mole per standard cubic meter) (kilogram/gram) (minute/hour), where standard temperature (gram-mole per standard cubic meter) is 20 degrees C.
n = Number of components in sample.

	(2) When the BTEX mass rate is calculated, only BTEX compounds measured by Method 18, 40 CFR part 60, appendix A, or ASTM D6420 - 99 (2004) as specified in §63.772(a)(1)(ii), shall be summed using the equations in paragraph (d)(3)(v)(B)(1) of this section.
	(vi) The owner or operator shall conduct performance tests according to the schedule specified in paragraphs (d)(3)(vi)(A) and (B) of this section.
	(A)  An initial performance test shall be conducted within 180 days after the compliance date that is specified for each affected source in §63.1270(d)(3) and (4) except that the initial performance test for existing combustion control devices at existing major sources shall be conducted no later than 3 years after the date of publication of the final rule in the Federal Register. If the owner or operator of an existing combustion control device at an existing major source chooses to replace such device with a control device tested under §63.1282(g), then the installed device shall comply with all provisions of this subpart no later than 3 years after the date of publication of the final rule in the Federal Register. The performance test results shall be submitted in the Notification of Compliance Status Report as required in §63.1285(d)(1)(ii).
	(B) Periodic performance tests shall be conducted. The first periodic performance test shall be conducted no later than 60 months after the initial performance test required in paragraph (d)(3)(vi)(A) of this section. Subsequent periodic performance tests shall be conducted at intervals no longer than 60 months following the previous periodic performance test or whenever a source desires to establish a new operating limit. The periodic performance test results must be submitted in the next Periodic Report as specified in §63.1285(e)(2)(x).
	(4) For a condenser design analysis conducted to meet the requirements of §63.1281(d)(1), (e)(3)(ii), or (f)(1), the owner or operator shall meet the requirements specified in paragraphs (d)(4)(i) and (d)(4)(ii) of this section. Documentation of the design analysis shall be submitted as a part of the Notification of Compliance Status Report as required in §63.1285(d)(1)(i).
	(i) The condenser design analysis shall include an analysis of the vent stream composition, constituent concentrations, flowrate, relative humidity, and temperature, and shall establish the design outlet organic compound concentration level, design average temperature of the condenser exhaust vent stream, and the design average temperatures of the coolant fluid at the condenser inlet and outlet. As an alternative to the condenser design analysis, an owner or operator may elect to use the procedures specified in paragraph (d)(5) of this section.
* * * * *
	(5) As an alternative to the procedures in paragraph (d)(4)(i) of this section, an owner or operator may elect to use the procedures documented in the GRI report entitled, "Atmospheric Rich/Lean Method for Determining Glycol Dehydrator Emissions," (GRI - 95/0368.1) as inputs for the model GRI-GLYCalc[TM] , Version 3.0 or higher, to generate a condenser performance curve.
	(e) Compliance demonstration for control devices performance requirements. This paragraph applies to the demonstration of compliance with the control device performance requirements specified in §63.1281(d)(1), (e)(3)(ii), and (f)(1). Compliance shall be demonstrated using the requirements in paragraphs (e)(1) through (3) of this section. As an alternative, an owner or operator that installs a condenser as the control device to achieve the requirements specified in §63.1281(d)(1)(ii), (e)(3)(ii), or (f)(1) may demonstrate compliance according to paragraph (f) of this section. An owner or operator may switch between compliance with paragraph (e) of this section and compliance with paragraph (f) of this section only after at least 1 year of operation in compliance with the selected approach. Notification of such a change in the compliance method shall be reported in the next Periodic Report, as required in §63.1285(e), following the change.
* * * * *
	(2) The owner or operator shall calculate the daily average of the applicable monitored parameter in accordance with §63.1283(d)(4) Except that the inlet gas flowrate to the control device shall not be averaged.
	(3) Compliance is achieved when the daily average of the monitoring parameter value calculated under paragraph (e)(2) of this section is either equal to or greater than the minimum or equal to or less than the maximum monitoring value established under paragraph (e)(1) of this section. For inlet gas flowrate, compliance with the operating parameter limit is achieved when the value is equal to or less than the value established under §63.1282(g).
	(4) Except for periods of monitoring system malfunctions, repairs associated with monitoring system malfunctions, and required monitoring system quality assurance or quality control activities (including, as applicable, system accuracy audits and required zero and span adjustments), the CMS required in §63.1283(d) must be operated at all times the affected source is operating. A monitoring system malfunction is any sudden, infrequent, not reasonably preventable failure of the monitoring system to provide valid data. Monitoring system failures that are caused in part by poor maintenance or careless operation are not malfunctions. Monitoring system repairs are required to be completed in response to monitoring system malfunctions and to return the monitoring system to operation as expeditiously as practicable.
	(5)  Data recorded during monitoring system malfunctions, repairs associated with monitoring system malfunctions, or required monitoring system quality assurance or control activities may not be used in calculations used to report emissions or operating levels. All the data collected during all other required data collection periods must be used in assessing the operation of the control device and associated control system.
	(6)  Except for periods of monitoring system malfunctions, repairs associated with monitoring system malfunctions, and required quality monitoring system quality assurance or quality control activities (including, as applicable, system accuracy audits and required zero and span adjustments), failure to collect required data is a deviation of the monitoring requirements.
	(f) Compliance demonstration with percent reduction or emission limit performance requirements -- condensers. This paragraph applies to the demonstration of compliance with the performance requirements specified in §63.1281(d)(1)(ii), (e)(3) or (f)(1) for condensers. Compliance shall be demonstrated using the procedures in paragraphs (f)(1) through (f)(3) of this section.
	(1) The owner or operator shall establish a site-specific condenser performance curve according to the procedures specified in §63.1283(d)(5)(ii). For sources required to meet the BTEX limit in accordance with §63.1281(e) or (f)(1) the owner or operator shall identify the minimum percent reduction necessary to meet the BTEX limit.
	(2) Compliance with the percent reduction requirement in §63.1281(d)(1)(ii), (e)(3), or (f)(1) shall be demonstrated by the procedures in paragraphs (f)(2)(i) through (iii) of this section.
* * * * *
	(iii) Except as provided in paragraphs (f)(2)(iii)(A), (B), and (D) of this section, at the end of each operating day the owner or operator shall calculate the 30-day average HAP, or BTEX, emission reduction, as appropriate, from the condenser efficiencies as determined in paragraph (f)(2)(ii) of this section for the preceding 30 operating days. If the owner or operator uses a combination of process modifications and a condenser in accordance with the requirements of §63.1281(e), the 30-day average HAP emission, or BTEX, emission reduction, shall be calculated using the emission reduction achieved through process modifications and the condenser efficiency as determined in paragraph (f)(2)(ii) of this section, both for the preceding 30 operating days.
	(A) After the compliance date specified in §63.1270(d), an owner or operator of a facility that stores natural gas that has less than 30 days of data for determining the average HAP, or BTEX, emission reduction, as appropriate, shall calculate the cumulative average at the end of the withdrawal season, each season, until 30 days of condenser operating data are accumulated. For a facility that does not store natural gas, the owner or operator that has less than 30 days of data for determining average HAP, or BTEX, emission reduction, as appropriate, shall calculate the cumulative average at the end of the calendar year, each year, until 30 days of condenser operating data are accumulated.
	(B) After the compliance date specified in §63.1270(d), for an owner or operator that has less than 30 days of data for determining the average HAP, or BTEX, emission reduction, as appropriate, compliance is achieved if the average HAP, or BTEX, emission reduction, as appropriate, calculated in paragraph (f)(2)(iii)(A) of this section is equal to or greater than 95.0 percent.
* * * * *
	(3) Compliance is achieved based on the applicable criteria in paragraphs (f)(3)(i) or (ii) of this section.
	(i) For sources meeting the HAP emission reduction specified in §63.1281(d)(1)(ii) or (e)(3) if the average HAP emission reduction calculated in paragraph (f)(2)(iii) of this section is equal to or greater than 95.0 percent.
	(ii) For sources required to meet the BTEX limit under §63.1281(e)(3) or (f)(1), compliance is achieved if the average BTEX emission reduction calculated in paragraph (f)(2)(iii) of this section is equal to or greater than the minimum percent reduction identified in paragraph (f)(1) of this section.
* * * * *
      (g) Performance testing for combustion control devices - manufacturers' performance test.
      (1) This paragraph applies to the performance testing of a combustion control device conducted by the device manufacturer. The manufacturer shall demonstrate that a specific model of control device achieves the performance requirements in (g)(7) of this section by conducting a performance test as specified in paragraphs (g)(2) through (6) of this section.
      (2) Performance testing shall consist of three 1-hour (or longer) test runs for each of the four following firing rate settings making a total of 12 test runs per test. Propene (propylene) gas shall be used for the testing fuel. All fuel analyses shall be performed by an independent third-party laboratory (not affiliated with the control device manufacturer or fuel supplier).
      (i) 90 - 100 percent of maximum design rate (fixed rate).
      (ii) 70 - 100 - 70 percent (ramp up, ramp down).
      (iii) 30 - 70 - 30 percent (ramp up, ramp down).
      (iv) 0 - 30 - 0 percent (ramp up, ramp down).
      (3) All models employing multiple enclosures shall be tested simultaneously and with all burners operational. Results shall be reported for the each enclosure individually and for the average of the emissions from all interconnected combustion enclosures/chambers. Control device operating data shall be collected continuously throughout the performance test using an electronic Data Acquisition System and strip chart. Data shall be submitted with the test report in accordance with paragraph (g)(8)(iii) of this section.
      (4) Inlet testing shall be conducted as specified in paragraphs (g)(4)(i) through (iii) of this section.
      (i) The fuel flow metering system shall be located in accordance with Method 2A, 40 CFR part 60, appendix A-1, (or other approved procedure) to measure fuel flow rate at the control device inlet location. The fitting for filling fuel sample containers shall be located a minimum of 8 pipe diameters upstream of any inlet fuel flow monitoring meter.
      (ii) Inlet flow rate shall be determined using Method 2A, 40 CFR part 60, appendix A-1. Record the start and stop reading for each 60-minute THC test. Record the gas pressure and temperature at 5-minute intervals throughout each 60-minute THC test.
      (iii) Inlet fuel sampling shall be conducted in accordance with the criteria in paragraphs (g)(4)(iii)(A) and (B) of this section.
      (A) At the inlet fuel sampling location, securely connect a Silonite-coated stainless steel evacuated canister fitted with a flow controller sufficient to fill the canister over a 1 hour period. Filling shall be conducted as specified in the following:
      (1) Open the canister sampling valve at the beginning of the total hydrocarbon (THC) test, and close the canister at the end of the THC test.
      (2) Fill one canister for each THC test run.
      (3) Label the canisters individually and record on a chain of custody form.
      (B) Each fuel sample shall be analyzed using the following methods. The results shall be included in the test report.
      (1) Hydrocarbon compounds containing between one and five atoms of carbon plus benzene using ASTM D1945-03.
      (2) Hydrogen (H2), carbon monoxide (CO), carbon dioxide (CO2), nitrogen (N2), oxygen (O2) using ASTM D1945-03.
      (3) Carbonyl sulfide, carbon disulfide plus mercaptans using ASTM D5504.
      (4) Higher heating value using ASTM D3588-98 or ASTM D4891-89.
      (5) Outlet testing shall be conducted in accordance with the criteria in paragraphs (G)(5)(i) through (v) of this section.
      (i) Sampling and flowrate measured in accordance with the following:
      (A) The outlet sampling location shall be a minimum of 4 equivalent stack diameters downstream from the highest peak flame or any other flow disturbance, and a minimum of one equivalent stack diameter upstream of the exit or any other flow disturbance. A minimum of two sample ports shall be used.
      (B) Flow rate shall be measured using Method 1, 40 CFR part 60, Appendix 1, for determining flow measurement traverse point location; and Method 2, 40 CFR part 60, Appendix 1, shall be used to measure duct velocity. If low flow conditions are encountered (i.e., velocity pressure differentials less than 0.05 inches of water) during the performance test, a more sensitive manometer shall be used to obtain an accurate flow profile.
      (ii) Molecular weight shall be determined as specified in paragraphs (g)(5)(ii)(A) and (B) of this section.
      (A) An integrated bag sample shall be collected during the Method 4, 40 CFR part 60, Appendix A, moisture test. Analyze the bag sample using a gas chromatograph-thermal conductivity detector (GC-TCD) analysis meeting the following criteria:
      (1) Collect the integrated sample throughout the entire test, and collect representative volumes from each traverse location.
      (2) The sampling line shall be purged with stack gas before opening the valve and beginning to fill the bag.
      (3) The bag contents shall be kneaded or otherwise vigorously mixed prior to the GC analysis.
      (4) The GC-TCD calibration procedure in Method 3C, 40 CFR part 60, Appendix A, shall be modified by using EPA Alt-045 as follows: For the initial calibration, triplicate injections of any single concentration must agree within 5 percent of their mean to be valid. The calibration response factor for a single concentration re-check must be within 10 percent of the original calibration response factor for that concentration. If this criterion is not met, the initial calibration using at least three concentration levels shall be repeated.
      (B) Report the molecular weight of: O2, CO2, Methane (CH4) and N2 and include in the test report submitted under §63.1285(d).
      (iii) Moisture shall be determined using Method 4, 40 CFR part 60, Appendix A. Traverse both ports with the Method 4, 40 CFR part 60, Appendix A, sampling train during each test run. Ambient air shall not be introduced into the Method 3C, 40 CFR part 60, Appendix A, integrated bag sample during the port change.
      (iv) Carbon monoxide shall be determined using Method 10, 40 CFR part 60, Appendix A. The test shall be run at the same time and with the sample points used for EPA Method 25A, 40 CFR part 60, Appendix A, testing. An instrument range of 0-10 per million by volume-dry (ppmvd) shall be used.
      (v) Visible emissions shall be determined using Method 22, 40 CFR part 60, Appendix A. The test shall be performed continuously during each test run. A digital color photograph of the exhaust point, taken from the position of the observer and annotated with date and time, will be taken once per test run and the four photos included in the test report.
      (6) Total hydrocarbons (THC) shall be determined as specified by the following criteria:
      (i) Conduct THC sampling using Method 25A, 40 CFR part 60, Appendix A, except the option for locating the probe in the center 10 percent of the stack shall not be allowed. The THC probe must be traversed to 16.7 percent, 50 percent, and 83.3 percent of the stack diameter during the testing.
      (ii) A valid test shall consist of three Method 25A, 40 CFR part 60, Appendix A, tests, each no less than 60 minutes in duration.
      (iii) A 0-10 parts per million by volume-wet (ppmvw) (as propane) measurement range is preferred; as an alternative a 0-30 ppmvw (as carbon) measurement range may be used.
      (iv) Calibration gases will be propane in air and be certified through EPA Protocol 1  -  "EPA Traceability Protocol for Assay and Certification of Gaseous Calibration Standards," September 1997, as amended August 25, 1999, EPA - 600/R - 97/121 (or more recent if updated since 1999).
      (v) THC measurements shall be reported in terms of ppmvw as propane.
      (vi)  THC results shall be corrected to 3 percent CO2, as measured by Method 3C, 40 CFR part 60, Appendix A.
      (vii) Subtraction of methane/ethane from the THC data is not allowed in determining results.
      (7) Performance test criteria:
      (i) The control device model tested must meet the criteria in paragraphs (g)(7)(i)(A) through (C) of this section:
      (A) Method 22, 40 CFR part 60, Appendix A, results under paragraph (g)(5)(v) of this section with no indication of visible emissions, and
      (B)  Average Method 25A, 40 CFR part 60, Appendix A, results under paragraph (g)(6) of this section equal to or less than 10.0 ppmvw THC as propane corrected to 3.0 percent CO2, and
      (C) Average CO emissions determined under paragraph (g)(5)(iv) of this section equal to or less than 10 parts ppmvd, corrected to 3.0 percent CO2.
      (ii) The manufacturer shall determine a maximum inlet gas flow rate which shall not be exceeded for each control device model to achieve the criteria in paragraph (g)(7)(i) of this section.
      (iii) A control device meeting the criteria in paragraph (g)(7)(i)(A) through (C) of this section will have demonstrated a destruction efficiency of 98.0 percent for HAP regulated under this subpart.
      (8) The owner or operator of a combustion control device model tested under this section shall submit the information listed in paragraphs (g)(8)(i) through (iii) in the test report required under §63.1285(d)(1)(iii).
      (i) Full schematic of the control device and dimensions of the device components.
      (ii) Design net heating value of the device.
      (iii) The test parameters listed in (g)(8)(iii)(A) through (Q) of this section, as applicable for the tested model.
      (A) Fuel gas flow including the maximum allowable inlet gas flow rate.
      (B) Fuel gas delivery pressure and temperature.
      (C) Fuel gas moisture.
      (D) Air/ steam injection/ assist.
      (E) Purge gas usage.
      (F) Condensate (liquid fuel) separation.
      (G) Combustion zone temperature.
      (H) Excess combustion air.
      (I) Flame arrestor(s).
      (J) Burner manifold pressure.
      (K) Pilot flame sensor.
      (L) Pilot flame design fuel and fuel usage.
      (M) Tip velocity.
      (N) Momentum flux ratio.
      (O) Exit temperature.
      (P) Exit flow rate.
      (Q) Wind velocity and direction.
      (iv) The test report shall include all calibration quality assurance/quality control data, calibration gas values, gas cylinder certification, and strip charts annotated with test times and calibration values.
      (h) Compliance demonstration for combustion control devices - manufacturers' performance test. This paragraph applies to the demonstration of compliance for a combustion control device tested under the provisions in paragraph (g) of this section. Owners or operators shall demonstrate that a control device achieves the performance requirements of §63.1281(d)(1), (e)(3)(ii) or (f)(1), by installing a device tested under paragraph (g) of this section and complying with the following criteria:
      (1) The inlet gas flow rate shall not exceed the maximum rate identified specified by the manufacturer. Flow rate shall be measured as specified in §63.1283(d)(3)(i)(H)(1).
      (2) A pilot flame shall be present at all times of operation. The pilot flame shall be monitored in accordance with §63.1283(d)(3)(i)(H)(2).
      (3) Devices shall be operated with no visible emissions, except for periods not to exceed a total of 5 minutes during any 2 consecutive hours. A visible emissions test using Method 22, 40 CFR part 60, Appendix A, shall be performed monthly. The observation period shall be 2 hours and shall be used according to Method 22.
      (4) Compliance with the operating parameter limit is achieved when the following criteria are met:
      (i) The inlet gas flow rate monitored under paragraph (h)(1) of this section is equal to or below the maximum established by the manufacturer; and
      (ii) The pilot flame is present at all times; and
      (iii) During the visible emissions test performed under paragraph (h)(3) of this section the duration of visible emissions does not exceed a total of 5 minutes during the observation period. Devices failing the visible emissions test shall follow the requirements in paragraphs (h)(4)(iii)(A) and (B) of this section.
      (A) Following the first failure, the fuel nozzle(s) and burner tubes shall be replaced.
      (B) If, following replacement of the fuel nozzle(s) and burner tubes as specified in (h)(4)(iii)(A), the visible emissions test is not passed in the next scheduled test, either a performance test shall be performed under paragraph (d) of this section, or the device shall be replaced with another control device whose model was tested, and met, the requirements in paragraph (g) of this section.
	30. Section 63.1283 is amended by:
	a. Revising paragraph (d)(1) introductory text;
	b. Revising paragraph (d)(1)(ii) and adding paragraphs (d)(1)(iii) and (iv);
	c. Revising paragraph (d)(2)(i) and (d)(2)(ii);
	d. Revising paragraphs (d)(3)(i)(A) and (B);
	e. Revising paragraphs (d)(3)(i)(D) and (E);
	f. Revising paragraphs (d)(3)(i)(F)(1) and (2);
	g. Revising paragraph (d)(3)(i)(G);
	h. Adding paragraph (d)(3)(i)(H);
	i. Revising paragraph (d)(4);
	j. Revising paragraph (d)(5)(i) introductory text;
	k. Revising paragraphs (d)(5)(i)(A) and (B);
	l. Adding paragraph (d)(5)(i)(C);
	m. Revising paragraphs (d)(5)(ii)(A) through (C);
	n. Revising paragraph (d)(6) introductory text;
	o. Revising paragraphs (d)(6)(ii);
	p. Revising paragraph (d)(7)(v);
	q. Revising paragraph (d)(8)(i)(A); and
	r. Revising paragraph (d)(8)(ii) to read as follows:
§63.1283 Inspection and monitoring requirements.
* * * * *
	(d) Control device monitoring requirements. (1) For each control device except as provided for in paragraph (d)(2) of this section, the owner or operator shall install and operate a continuous parameter monitoring system in accordance with the requirements of paragraphs (d)(3) through (9) of this section. Owners or operators that install and operate a flare in accordance with §63.1281(d)(1)(iii) or (f)(1)(iii) are exempt from the requirements of paragraphs (d)(4) and (5) of this section. The continuous monitoring system shall be designed and operated so that a determination can be made on whether the control device is achieving the applicable performance requirements of §63.1281(d), (e)(3), or (f)(1). Each continuous parameter monitoring system shall meet the following specifications and requirements:
* * * * *
	(ii) A site-specific monitoring plan must be prepared that addresses the monitoring system design, data collection, and the quality assurance and quality control elements outlined in paragraph (d) of this section and in §63.8(d). Each CPMS must be installed, calibrated, operated and maintained in accordance with the procedures in your approved site-specific monitoring plan. Using the process described in §63.8(f)(4), you may request approval of monitoring system quality assurance and quality control procedures alternative to those specified in paragraphs (d)(1)(ii)(A) through (E) of this section in your site-specific monitoring plan.
	(A)  The performance criteria and design specifications for the monitoring system equipment, including the sample interface, detector signal analyzer, and data acquisition and calculations;
	(B) Sampling interface (e.g., thermocouple) location such that the monitoring system will provide representative measurements;
	(C) Equipment performance checks, system accuracy audits, or other audit procedures;
	(D) Ongoing operation and maintenance procedures in accordance with provisions in §63.8(c)(1) and (c)(3); and
	(E) Ongoing reporting and recordkeeping procedures in accordance with provisions in §63.10(c), (e)(1), and (e)(2)(i).
	(iii) The owner or operator must conduct the CPMS equipment performance checks, system accuracy audits, or other audit procedures specified in the site-specific monitoring plan at least once every 12 months.
	(iv) The owner or operator must conduct a performance evaluation of each CPMS in accordance with the site-specific monitoring plan.
	(2) * * *
	(i) Except for control devices for small glycol dehydration units, a boiler or process heater in which all vent streams are introduced with the primary fuel or are used as the primary fuel;
	(ii) Except for control devices for small glycol dehydration units, a boiler or process heater with a design heat input capacity equal to or greater than 44 megawatts.
	(3) * * *
	(i) * * *