(iii)(A) The dates of each compliance test as required in sections G.5.2(e), G.5.3(i), G.5.4, and G.5.7(f).
      (B) The background level measured during each compliance test.
      (C) The maximum instrument reading measured at the equipment during each compliance test.
      (iv) A list of identification numbers for equipment in vacuum service.
      (v) A list of identification numbers for equipment that the owner or operator designates as operating in VOC service less than 300 hr/yr in accordance with section G.5.1(e), a description of the conditions under which the equipment is in VOC service, and rationale supporting the designation that it is in VOC service less than 300 hr/yr.
      (vi) The date and results of the weekly visual inspection for indications of liquids dripping from pumps in light liquid service.
      (vii) Records of the information specified in paragraphs (a)(5)(vii)(A) through (F) of this section for monitoring instrument calibrations conducted according to sections 8.1.2 and 10 of USEPA Method 21 of appendix A-7 of this part and section G.7(b).
      (A) Date of calibration and initials of operator performing the calibration.
      (B) Calibration gas cylinder identification, certification date, and certified concentration.
      (C) Instrument scale(s) used.
      (D) A description of any corrective action taken if the meter readout could not be adjusted to correspond to the calibration gas value in accordance with section 10.1 of USEPA Method 21 of appendix A-7 of this part.
      (E) Results of each calibration drift assessment required by section G.7(b)(2) (i.e., instrument reading for calibration at end of monitoring day and the calculated percent difference from the initial calibration value).
      (F) If an owner or operator makes their own calibration gas, a description of the procedure used.
      (viii) The connector monitoring schedule for each process unit as specified in section G.9.7(b)(3)(v).
      (ix) Records of each release from a pressure relief device subject to section G.5.4.
      (6) The following information pertaining to all valves subject to the requirements of section G.5.7(g) and (h), all pumps subject to the requirements of section G.5.2(g), and all connectors subject to the requirements of section G.5.11(e) shall be recorded in a log that is kept in a readily accessible location:
      (i) A list of identification numbers for valves, pumps, and connectors that are designated as unsafe-to-monitor, an explanation for each valve, pump, or connector stating why the valve, pump, or connector is unsafe-to-monitor, and the plan for monitoring each valve, pump, or connector.
      (ii) A list of identification numbers for valves that are designated as difficult-to-monitor, an explanation for each valve stating why the valve is difficult-to-monitor, and the schedule for monitoring each valve.
      (7) The following information shall be recorded for valves complying with section G.6.2:
      (i) A schedule of monitoring.
      (ii) The percent of valves found leaking during each monitoring period.
      (8) The following information shall be recorded in a log that is kept in a readily accessible location:
      (i) Design criterion required in sections G.5.2(d)(5) and G.5.3(e)(2) and explanation of the design criterion; and
      (ii) Any changes to this criterion and the reasons for the changes.
      (A) The following information shall be recorded in a log that is kept in a readily accessible location for use in determining exemptions:
      (1) An analysis demonstrating the design capacity of the natural gas processing plant,
      (2) A statement listing the feed or raw materials and products from the processing plant(s) and an analysis demonstrating whether these chemicals are heavy liquids or beverage alcohol, and
      (3) An analysis demonstrating that equipment is not in VOC service.
      (9) Information and data used to demonstrate that a piece of equipment is not in VOC service shall be recorded in a log that is kept in a readily accessible location.
       (10) The following recordkeeping requirements apply to pressure relief devices.
      (i) When each leak is detected, a weatherproof and readily visible identification, marked with the equipment identification number, must be attached to the leaking equipment. The identification on the pressure relief device may be removed after it has been repaired.
      (ii) When each leak is detected as specified in section G.3(b)(2), the following information must be recorded in a log and shall be kept for 2 years in a readily accessible location:
      (A) The instrument and operator identification numbers and the equipment identification number.
      (B) The date the leak was detected and the dates of each attempt to repair the leak.
      (C) Repair methods applied in each attempt to repair the leak.
      (D) "Above 500 ppm" if the maximum instrument reading measured by the methods specified in paragraph (a) of this section after each repair attempt is 500 ppm or greater.
      (E) "Repair delayed" and the reason for the delay if a leak is not repaired within 15 calendar days after discovery of the leak.
      (F) The signature of the owner or operator (or designate) whose decision it was that repair could not be effected without a process shutdown.
      (G) The expected date of successful repair of the leak if a leak is not repaired within 15 days.
      (H) Dates of process unit shutdowns that occur while the equipment is unrepaired.
      (I) The date of successful repair of the leak.
      (J) A list of identification numbers for equipment that are designated for no detectable emissions under the provisions of section G.5.4 (a). The designation of equipment subject to the provisions of section G.5.4 (a) must be signed by the owner or operator.
      (b) Reporting requirements. Each owner or operator subject to the VOC equipment leak requirements shall comply with the reporting requirements of paragraphs (b)(1) through (5).
      (1) Each owner or operator subject to the equipment leak VOC emission control requirements of section G.5 shall submit semiannual reports to the permitting authority beginning 6 months after a facility becomes subject to VOC emission control requirements of section G.
      (2) The initial semiannual report to the permitting authority shall include the following information:
      (i) Process unit identification.
      (ii) Number of valves subject to the requirements of section G.5.7, excluding those valves designated for no detectable emissions under the provisions of section G.5.7(f).
      (iii) Number of pumps subject to the requirements of section G.5.2, excluding those pumps designated for no detectable emissions under the provisions of section G.5.2(e) and those pumps complying with section G.5.2(f).
      (iv) Number of compressors subject to the requirements of section G.5.3, excluding those compressors designated for no detectable emissions under the provisions of section G.5.3(i) and those compressors complying with section G.5.3(h).
      (v) Number of connectors subject to the requirements of section G.9.11.
      (vi) Number of pressure relief devices subject to the requirements, except for those pressure relief devices designated for no detectable emissions under the provisions of section G.5.4 (a) and those pressure relief devices complying with section G.5.4 (c).
      (3) All semiannual reports to the permitting authority shall include the following information:
      (i) Process unit identification.
      (ii) For each month during the semiannual reporting period,
      (A) Number of valves for which leaks were detected as described in section G.5.7(b) or section G.6.2,
      (B) Number of valves for which leaks were not repaired as required in section G.5.7(d)(1),
      (C) Number of pumps for which leaks were detected as described in section G.5.2(b), (d)(4)(ii)(A) or (B), or (d)(5)(iii),
      (D) Number of pumps for which leaks were not repaired as required in section G.5.2(c)(1) and (d)(6),
      (E) Number of compressors for which leaks were detected as described in section G.5.3(f),
      (F) Number of compressors for which leaks were not repaired as required in section G.5.3(g)(1),
      (G) Number of connectors for which leaks were detected as described in section G.9.7(b)
      (H) Number of connectors for which leaks were not repaired as required in section G.9.7(d), and
      (I) The facts that explain each delay of repair and, where appropriate, why a process unit shutdown was technically infeasible.
      (iii) An owner or operator must include the following information in all semiannual reports:
      (A) Number of pressure relief devices for which leaks were detected; and
      (B) Number of pressure relief devices for which leaks were not repaired.
      (iv) Dates of process unit shutdowns which occurred within the semiannual reporting period.
      (v) Revisions to items reported according to paragraph (b)(1) of this section if changes have occurred since the initial report or subsequent revisions to the initial report.
      (4) An owner or operator electing to comply with the provisions of section G.6.1 or section G.6.2 shall notify the permitting authority of the alternative standard selected 90 days before implementing either of the provisions.
      (5) An owner or operator shall report the results of all performance tests to the permitting authority.
G.9	Definitions
      Equipment, as used in the standards and requirements in this rule relative to the equipment leaks of VOC from onshore natural gas processing plants, means each pump, pressure relief device, open-ended valve or line, valve, and flange or other connector that is in VOC service or in wet gas service, and any device or system required by those same standards and requirements in this rule.
      Gas processing plant process unit means equipment assembled for the extraction of natural gas liquids from field gas, the fractionation of the liquids into natural gas products, or other operations associated with the processing of natural gas products. A process unit can operate independently if supplied with sufficient feed or raw materials and sufficient storage facilities for the products.
      Natural gas processing plant (gas plant) means any processing site engaged in the extraction of natural gas liquids from field gas, fractionation of mixed natural gas liquids to natural gas products, or both. A Joule-Thompson valve, a dew point depression valve, or an isolated or standalone Joule-Thompson skid is not a natural gas processing plant.
      Onshore means all facilities except those that are located in the territorial seas or on the outer continental shelf.

H	Pneumatic Pumps: VOC Emissions Control Requirements
H.1	Applicability
      Each pneumatic pump, which is a natural gas-driven chemical/methanol or natural gas-driven diaphragm pump located at a natural gas processing plant or located from the wellhead and point of custody transfer to the natural gas transmission and storage segment for which a control device is located on site. For purposes of the requirements specified in this section, we refer to these pumps as gas-driven pneumatic pumps.
H.2	What VOC Emission Reduction Requirements Apply to Natural Gas-Driven Pneumatic Pumps?
      For each natural gas-driven pneumatic pump, you must comply with the VOC emission control requirements, based on natural gas as a surrogate for VOC, in either paragraph (a)(1) or (b)(1) of this section, as applicable.
      (a)(1) Each natural gas-driven pneumatic pump at a natural gas processing plant must have a natural gas emission rate of zero.
      (2) Each natural gas-driven pneumatic pump at a natural gas processing plant must be tagged with the date the natural gas-driven pneumatic pump is required to comply with the model rule (as established by the regulatory authority) that allows traceability to the records for that gas-driven pneumatic pump as required in section H.5(a)(1)(i).
      (b)(1) Each natural gas-driven pneumatic pump located between the wellhead and point of custody transfer to the natural gas transmission and storage segment, for which a control device is located on site, must reduce natural gas emissions by 95 percent, except as provided in paragraph (b)(2) of this section.
	(2) You are not required to install a control device solely for the purposes of complying with the 95 percent reduction of paragraph (b)(1) of this section. If you do not have a control device installed on site by the compliance date specified by your regulatory authority, then you must comply instead with the provisions of paragraph (b)(2)(i) and (ii) of this section.
      	(i) Submit a certification in accordance with H.5(b)(1)(i).
      	(ii) If you subsequently install a control device, you are no longer required to submit the certification in H.5(b)(1)(i) and must be in compliance with the requirements of paragraph (b)(1) of this section within 30 days of installation of the control device. Compliance with this requirement should be reported in the next annual report in accordance with H.5(a)(1)(iii).
      (3) Each natural gas-driven pneumatic pump located between the wellhead and point of custody transfer to the natural gas transmission and storage segment for which a control device is located on site must be tagged with the date that the pneumatic pump must comply with the model rule (as established by the regulatory authority) that allows traceability to the records for that natural gas-driven pneumatic pump as required in section H.5(a)(1)(ii).
      (4) If you use a control device to reduce emissions, you must connect the natural gas-driven pneumatic pump subject to VOC emission control requirements through a closed vent system that meets the requirements of section D.1(b) and routed to a control device that meets the conditions specified in section E.1. As an alternative to routing the closed vent system to a control device, you may route the closed vent system to a process.
      (c) You must demonstrate initial compliance by the compliance date specified by your regulatory authority by demonstrating compliance with standards that apply to natural gas-driven pneumatic pump sources subject to VOC emission requirements as required by section H.3.
      (d) You must demonstrate continuous compliance with standards that apply to natural gas-driven pneumatic pump sources subject to VOC emission requirements as required by section H.4.
      (e) You must perform the required recordkeeping, and reporting as required by section H.5.
H.3	Initial Compliance Demonstration Requirements
      You must demonstrate initial compliance by the compliance date specified by your regulatory authority by demonstrating compliance with the VOC emission control requirements for natural gas-driven pneumatic pumps specified in paragraphs (a) through (f) of this section, as applicable.
      (a) You own or operate a pneumatic pump located at a natural gas processing plant and your natural gas-driven chemical/methanol or diaphragm pump is driven by a gas other than natural gas and therefore emits zero natural gas.
      (b) You own or operate a natural gas-driven pneumatic pump located between the wellhead and point of custody transfer to the natural gas transmission and storage segment and your natural gas-driven pneumatic pump is controlled by at least 95 percent.
	(c) You own or operate a natural gas-driven pneumatic pump located between the wellhead and point of custody transfer to the natural gas transmission and storage segment and your pneumatic pump is not controlled by at least 95 percent because a control device is not available at the site, you must submit the certification in section H.5(a)(1)(i).
      (d) You must tag each natural gas-driven pneumatic pump subject to VOC emission requirements according to the requirements of section (a)(2) or (b)(3), as applicable.
      (e) You must include a listing of the natural gas-driven pneumatic pumps subject to VOC emission requirements specified in paragraphs (a) through (c) of this section in the initial annual report submitted for your natural gas-driven pneumatic pump according to the requirements of section H.5(b).
      (f) You must maintain the records as specified in section H.5(a) for each natural gas-driven chemical/methanol or diaphragm pump subject to VOC emission control requirements of section H.
H.4	Continuous Compliance Demonstration Requirements
      You have demonstrated continuous compliance for each natural gas-driven pneumatic pump at a location with a control device on site by complying with the requirements of paragraphs (a) and (b) of this section.
      (a) You must reduce VOC emissions from the natural gas-driven pneumatic pump by 95 percent or greater.
      (b) For each control device used to reduce emissions, you must demonstrate continuous compliance with the performance requirements of section H.2(a)(1) and (b)(1) using the procedures specified in paragraphs (b)(1) through (7) of this section. If you use a condenser as the control device to achieve the requirements specified in section H.2, you must demonstrate compliance according to paragraph (b)(8) of this section. You may switch between compliance with paragraphs (b)(1) through (7) of this section and compliance with paragraph (b)(8) of this section only after at least 1 year of operation in compliance with the selected approach. You must provide notification of such a change in the compliance method in the next annual report, as required in section H.5(b)(1), following the change.
      (1) You must operate below (or above) the site specific maximum (or minimum) parameter value established according to the requirements of section E.2(f)(1).
      (2) You must calculate the daily average of the applicable monitored parameter in accordance with section E.2(e) except that the inlet gas flow rate to the control device must not be averaged.
      (3) Compliance with the operating parameter limit is achieved when the daily average of the monitoring parameter value calculated under paragraph (b)(2) of this section is either equal to or greater than the minimum monitoring value or equal to or less than the maximum monitoring value established under paragraph (b)(1) of this section. When performance testing of a combustion control device is conducted by the device manufacturer as specified in section F(d), compliance with the operating parameter limit is achieved when the criteria in section F(e) are met.
      (4) You must operate the continuous monitoring system required in section E.2(a) at all times the source is operating, 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). 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. You are required to complete monitoring system repairs in response to monitoring system malfunctions and to return the monitoring system to operation as expeditiously as practicable.
      (5) You may not use data recorded during monitoring system malfunctions, repairs associated with monitoring system malfunctions, or required monitoring system quality assurance or control activities in calculations used to report emissions or operating levels. You must use all the data collected during all other required data collection periods to assess the operation of the control device and associated control system.
      (6) Failure to collect required data is a deviation of the monitoring requirements, 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).
      (7) If you use a combustion control device to meet the requirements of section H.2 and you demonstrate compliance using the test procedures specified in section F(b), you must comply with paragraphs (b)(7)(i) through (iv) of this section.
      (i) A pilot flame must be present at all times of operation.
      (ii) Devices must be operated with no visible emissions, except for periods not to exceed a total of one minute during any 15 minute period. A visible emissions test using section 11 of Method 22, 40 CFR part 60, appendix A, must be performed at least once every calendar month, separated by at least 15 days between each test. The observation period shall be 15 minutes.
      (iii) Devices failing the visible emissions test must follow manufacturer's repair instructions, if available, or best combustion engineering practice as outlined in the unit inspection and maintenance plan, to return the unit to compliant operation. All repairs and maintenance activities for each unit must be recorded in a maintenance and repair log and must be available for inspection.
      (iv) Following return to operation from maintenance or repair activity, each device must pass a Method 22, 40 CFR part 60, appendix A, visual observation as described in paragraph (b)(7)(ii) of this section.
      (8) If you use a condenser as the control device to achieve the percent reduction performance requirements specified in section H.2(b)(1), you must demonstrate compliance using the procedures in paragraphs (b)(8)(i) through (v) of this section.
      (i) You must establish a site-specific condenser performance curve according to section E.2(f)(2).
      (ii) You must calculate the daily average condenser outlet temperature in accordance with section E.2(e).
      (iii) You must determine the condenser efficiency for the current operating day using the daily average condenser outlet temperature calculated under paragraph (b)(8)(ii) of this section and the condenser performance curve established under paragraph (b)(8)(i) of this section.
      (D) Except as provided in paragraphs (b)(8)(iv)(A) and (B) of this section, at the end of each operating day, you must calculate the 365-day rolling average TOC emission reduction, as appropriate, from the condenser efficiencies as determined in paragraph (b)(8)(iii) of this section.
       (A) After the compliance dates specified by your regulatory authority, if you have less than 120 days of data for determining average TOC emission reduction, you must calculate the average TOC emission reduction for the first 120 days of operation after the compliance date. You have demonstrated compliance with the overall 95 percent reduction requirement if the 120-day average TOC emission reduction is equal to or greater than 95 percent.
 	(B) After 120 days and no more than 364 days of operation after the compliance date specified by your regulatory authority, you must calculate the average TOC emission reduction as the TOC emission reduction averaged over the number of days between the current day and the applicable compliance date. You have demonstrated compliance with the overall 95 percent reduction requirement if the average TOC emission reduction is equal to or greater than 95 percent.
      (v) If you have data for 365 days or more of operation, you have demonstrated compliance with the TOC emission reduction if the rolling 365-day average TOC emission reduction calculated in paragraph (b)(8)(iv) of this section is equal to or greater than 95 percent.
      (3) You must submit the annual report required by section H.5(b)(1) and maintain the records as specified in section H.5(a)(1).
H.5	Recordkeeping and Reporting Requirements
      (a) Recordkeeping requirements.
      (1) For each applicable natural gas-driven pneumatic pump subject to VOC emission control requirements, you must maintain the records identified in paragraphs (a)(1)(i) through (iii) of this section onsite or at the nearest local field office for at least five years.
      (i) Records of the date that an individual natural gas-driven pneumatic pump is required to comply with the model rule (as specified by the regulatory authority), location and manufacturer specifications for each natural gas-driven pneumatic pump.
      (ii) Records of deviations in cases where the natural gas-driven pneumatic pump was not operated in compliance with the requirements specified in section H.2.
      (iii) Records of the control device installation date and the location of sites containing natural gas-driven pneumatic pumps at which a control device was installed, where previously there was no control device at the site.
      (iv) Except as specified in paragraph (a)(iv)(G) of this section, records of each control device tested under section F(d) which meets the criteria in section F(d)(11) and section F(e) and used to comply with section H.2(b)(1) for each natural gas-driven pneumatic pump.
      (A) Make, model and serial number of purchased device.
      (B) Date of purchase.
      (C) Copy of purchase order.
       (D) Location of the pneumatic pump and control device in latitude and longitude coordinates in decimal degrees to an accuracy and precision of five (5) decimals of a degree using the North American Datum of 1983.
      (E) Inlet gas flow rate.
 	(F) Records of continuous compliance requirements in FEuro as specified in paragraphs (a)(1)(iv)(F)(1) through (4) of this section.
       (1) Records that the pilot flame is present at all times of operation.
 	(2) Records that the device was operated with no visible emissions except for periods not to exceed a total of 2 minutes during any hour.
 	(3) Records of the maintenance and repair log.
      (4) Records of the visible emissions test following return to operation from a maintenance or repair activity.
       (G) As an alternative to the requirements of paragraph (a)(1)(iv)(D) of this part, you may maintain records of one or more digital photographs with the date the photograph was taken and the latitude and longitude of the pneumatic pump and control device imbedded within or stored with the digital file. As an alternative to imbedded latitude and longitude within the digital photograph, the digital photograph may consist of a photograph of the pneumatic pump and control device with a photograph of a separately operating GIS device within the same digital picture, provided the latitude and longitude output of the GIS unit can be clearly read in the digital photograph.
      (b) Reporting Requirements.
      (1) For each natural gas-driven pneumatic pump subject to VOC emission control requirements, annual reports are required to include the information specified in paragraphs (b)(1)(i) through (iv) of this section.
      (i) In the initial annual report, a certification that there is no control device on site, if applicable.
      (ii) An identification of each natural gas-driven pneumatic pump, including the identification information specified in section H.2(a)(2) or (b)(3).
      (iii) An identification of any sites which contain natural gas-driven pneumatic pumps and which installed a control device during the reporting period, where there was no control device previously at the site.
      (iv) Records of deviations specified in paragraph (a)(1)(ii) of this section that occurred during the reporting period.
	(v) If complying with H.2(b)(1) with a control device tested under section F(d), which meets the criteria in section F(d)(11) and section F(e), records specified in paragraphs (a)(1)(iv)(A) through (G) of this section for each pneumatic pump constructed, modified or reconstructed during the reporting period.
H.6	Definitions
      Chemical/methanol or diaphragm pump means a gas-driven positive displacement pump typically used to inject precise amounts of chemicals into process streams or circulate glycol compounds for freeze protection.
      Natural gas processing plant (gas plant) means any processing site engaged in the extraction of natural gas liquids from field gas, fractionation of mixed natural gas liquids to natural gas products, or both. A Joule-Thompson valve, a dew depression valve, or a standalone Joule-Thompson skid is not a natural gas processing plant.
      Natural gas-driven chemical/methanol or diaphragm pump means a chemical or methanol injection or circulation pump or a diaphragm pump powered by pressurized natural gas.

I	Fugitive Emissions Components VOC Emissions Control Requirements
I.1	Applicability
      (a) The collection of fugitive emission components at a well site with wells that produce, on average, greater than 15 barrel equivalents per day. The fugitive emissions requirements of this section do not apply to well sites that only contain wellheads.
      (b) The collection of fugitive emission components at a compressor station located from the wellhead to the point of custody transfer to the natural gas transmission and storage segment or to an oil pipeline.
I.2	What VOC Emission Control Requirements Apply to the Collection of Fugitive Emission Components at a Well Site and a Compressor Station?
	For fugitive emissions, VOC emission control requirements apply to the collection of fugitive emission components at a well site and compressor station (that is located from the wellhead to the point of custody transfer to the natural gas transmission and storage segment or to an oil pipeline), as specified in paragraphs (a) through (e) of this section for monitoring the collection of fugitive emission components. These requirements are independent of the closed vent system and control requirements in section D.
      (a) You must monitor all fugitive emission components, as defined in section I.6, in accordance with paragraphs (b) through (d). You must repair all sources of fugitive emissions in accordance with paragraph (e). You must keep records in accordance and report in accordance with section I.5(a). For purposes of this section, fugitive emissions are defined as: any visible emission from a fugitive emission component using optical gas imaging.
      (b) You must develop corporate-wide fugitive emissions monitoring plan that covers the collection of fugitive emission components at well sites and compressor stations in accordance with paragraph (c) of this section, and you must develop a site-specific fugitive emissions monitoring plan specific to each collection of fugitive emission components at a well site and each collection of fugitive emission components at a compressor station in accordance with paragraph (d) of this section. Alternatively, you may develop a site-specific plan for each collection of fugitive emission components at a well site and each collection of fugitive emission components at a compressor station that covers the elements of both the corporate-wide and site-specific plans.
	(c) Your corporate-wide monitoring plan must include the elements specified in paragraphs (c)(1) through (c)(8) of this section, as a minimum.
	(1) Frequency for conducting surveys. Monitoring surveys must be conducted at least as frequently as required by sections I.3 and section I.4 of this section.
	(2) Technique for determining fugitive emissions.
	(3) Manufacturer and model number of fugitive emission detection equipment to be used.
	(4) Procedures and timeframes for identifying and fixing fugitive emission components from which fugitives are detected, including timeframes for fugitive emission components that are unsafe to repair. Your repair schedule must meet the requirements of paragraph (e) of this section at a minimum.
	(5) Procedures and timeframes for verifying fugitive emission component repairs.
	(6) Records that will be kept and the length of time records will be kept.
	(7) Your plan must also include the elements specified in paragraphs (c)(7)(i) through (vii).
	(i) Verification that your optical gas imaging equipment meets the specifications of paragraphs (c)(7)(i)(A) and (B) of this section. This verification is an initial verification and may either be performed by the facility, by the manufacturer, or by a third party. For purposes of complying with the fugitive emissions monitoring program with optical gas imaging, a fugitive emission is defined as any visible emissions observed using optical gas imaging.
	(A) Your optical gas imaging equipment must be capable of imaging gases in the spectral range for the compound of highest concentration in the potential fugitive emissions.
	(B) Your optical gas imaging equipment must be capable of imaging a gas that is half methane, half propane at a concentration of <=10,000 ppm at a flow rate of >=60 g/hr from a quarter inch diameter orifice.
	(ii) Procedure for a daily verification check.
	(iii) Procedure for determining the operator's maximum viewing distance from the equipment and how the operator will ensure that this distance is maintained.
	(iv) Procedure for determining maximum wind speed during which monitoring can be performed and how the operator will ensure monitoring occurs only at wind speeds below this threshold.
	(v) Procedures for conducting surveys, including the items specified in paragraphs (c)(7)(v)(A) through (C) of this section.
	(A) How the operator will ensure an adequate thermal background is present in order to view potential fugitive emissions.
	(B) How the operator will deal with adverse monitoring conditions, such as wind.
	(C) How the operator will deal with interferences (e.g., steam).
	(vi) Training and experience needed prior to performing surveys.
	(vii) Procedures for calibration and maintenance. Procedures must comply with those recommended by the manufacturer.
	(d) Your site-specific monitoring plan must include the elements specified in paragraphs (d)(1) through (d)(3) of this section, as a minimum.
	(1) Deviations from your corporate-wide plan.
	(2) Sitemap.
	(3) Your plan must also include your defined walking path. The walking path must ensure that all fugitive emissions components are within sight of the path and must account for interferences.
	(e) Each monitoring survey shall observe each fugitive emissions components for fugitive emissions.
      (f) For fugitive emissions components also subject to the repair provisions of sections D.2(e)(9) through (12) and (f)(4) through (7), those provisions apply instead to those closed vent system and covers, and the repair provisions of paragraphs (f)(1) and (2) of this section do not apply to those closed vent systems and covers.
      (1) Each identified source is required to monitor fugitive emission components as specified in section I.3 and I.4. Identified fugitive emissions shall be repaired or replaced as soon as practicable, but no later than 15 calendar days after detection of the fugitive emissions. If the repair or replacement is technically infeasible or unsafe to repair during operation of the unit, the repair or replacement must be completed during the next scheduled shutdown or within 6 months, whichever is earlier.
	(2) Each repaired or replaced fugitive emissions component must be resurveyed as soon as practical, but no later than 15 days after completion of the repair or replacement, to ensure that there is no leak.
      (i) For repairs that cannot be made during the monitoring survey when the fugitive emissions are initially found, the operator may resurvey the repaired fugitive emissions components using Method 21 or optical gas imaging no later than 15 days of finding such fugitive emissions.
      (ii) Operators that use Method 21 to resurvey the repaired fugitive emissions components, are subject to the resurvey provisions specified in paragraphs (e)(2)(ii)(A) and (B).
      (A) A fugitive emissions component is repaired when the Method 21 instrument indicates a concentration of less than 500 ppm above background.
      (B) Operators must use the Method 21 monitoring requirements specified in section G.3(g).
      (iii) Operators that use optical gas imaging to resurvey the repaired fugitive emissions components, are subject to the resurvey provisions specified in paragraphs (e)(2)(iii)(A) and (B).
	(A) A fugitive emissions component is repaired when the optical gas imaging instrument shows no indication of visible emissions.
      (B) Operators must use the optical gas imaging monitoring requirements specified in paragraph (a) of this section.
I.3	Initial Compliance Demonstration
      (a) Each well site with a collection of fugitive emissions components must conduct an initial monitoring survey within 30 days of being subject to VOC emission control requirements of section I.
	(b) Each compressor station site with a collection of fugitive emissions components must conduct an initial monitoring survey within 30 days of being subject to VOC emission control requirements of section I.2.
I.4	Continuous Compliance Demonstration
      (a) A monitoring survey of each collection of fugitive emissions components at a well site and a compressor station site subject to VOC emission control requirements under section I shall be conducted at least semiannually after the initial survey. Consecutive semiannual monitoring surveys shall be conducted at least four months apart.
	(b) The monitoring frequency specified in paragraph (a) of this section shall be increased to quarterly in the event that two consecutive semiannual monitoring surveys detect fugitive emissions at greater than three percent of the fugitive emissions components at a well site or at greater than three percent of the fugitive emission components at a compressor station subject to VOC emission control requirements under section I.
	(c) The monitoring frequency specified in paragraph (a) of this section may be decreased to annual in the event that two consecutive semiannual surveys detect no fugitive emissions at less than one percent of the fugitive emissions components at the well site, or less than one percent of the fugitive emissions components at a compressor station subject to VOC emission control requirements under section I. The monitoring frequency shall return to semiannual if a annual survey detects fugitive emissions between one and three percent of the fugitive emissions components at the well site, or between one and three percent of the fugitive emissions components at the compressor station, and shall return to quarterly if a survey detects fugitive emissions at greater than three percent of the fugitive emissions components at the well site, or greater than three percent of the fugitive emissions components at the compressor station.
I.5	Recordkeeping and Reporting Requirements
      (a) Records for each monitoring survey shall be maintained as specified in paragraphs (a)(1) through (6) and must contain, at a minimum, the information specified in paragraphs (a)(1) through (a)(6). Records are required to be maintained onsite or at the nearest local field office for at least five years.
	(1) Date of the survey.
	(2) Beginning and end time of the survey.
	(3) Name of operator(s) performing survey. You must note the training and experience of the operator.
	(4) Ambient temperature, sky conditions, and maximum wind speed at the time of the survey.
	(5) Any deviations from the monitoring plan or a statement that there were no deviations from the monitoring plan.
	(6) Documentation of each source of fugitive emissions (e.g. fugitive emissions component), including the information specified in paragraphs (a)(6)(i) through (iv) of this section.
	(i) Location.
	(ii) One or more digital photographs of each required monitoring survey being performed. The digital photograph must include the date the photograph was taken and the latitude and longitude of the well site or compressor station subject to VOC emission control requirements under section I imbedded within or stored with the digital file. As an alternative to imbedded latitude and longitude within the digital photograph, the digital photograph may consist of a photograph of the monitoring survey being performed with a photograph of a separately operating GIS device within the same digital picture, provided the latitude and longitude output of the GIS unit can be clearly read in the digital photograph.
      (iii) The date of the successful repair of the fugitive emission component.
      	(iv) The instrument used to resurvey a repaired fugitive emissions component that could not be repaired during the initial fugitive emissions finding.
	(b) Annual reports shall be submitted for each collection of fugitive emissions components at a well site and each collection of fugitive emissions components at a compressor station subject to VOC emission control requirements under section I that include the information specified in paragraph (a) of this section for each monitoring survey conducted during the year. Multiple collection of fugitive emissions components at a well site or collection of fugitive emissions as a compressor station subject to VOC emission control requirements under section I may be included in a single annual report.
I.6	Definitions
	Compressor station site means any permanent combination of one or more compressors that move natural gas at increased pressure into gathering or transmission pipelines, or into storage.
      Fugitive emissions component means any component that has the potential to emit fugitive emissions of VOC at a well site or compressor station, , including but not limited to valves, connectors, pressure relief devices, open-ended lines, access doors, flanges, closed vent systems, thief hatches or other openings on a storage vessels, agitator seals, distance pieces, crankcase vents, blowdown vents, pump seals or diaphragms, compressors, separators, pressure vessels, dehydrators, heaters, instruments, and meters. Devices that vent as part of normal operations, such as natural gas-driven pneumatic controllers or natural gas-driven pumps, are not fugitive emissions components, insofar as the gas discharged from the device's vent is not considered a fugitive emission. Emissions originating from other than the vent, such as the seals around the bellows of a diaphragm pump, would be considered fugitive emissions.
      Well site means one or more areas that are directly disturbed during the drilling and subsequent operation of, or affected by, production facilities directly associated with any oil well, natural gas well, or injection well and its associated well site. For the purposes of the fugitive emissions standards at section I.1, well site also includes tank batteries collecting crude oil, condensate, intermediate hydrocarbon liquids, or produced water condensate from wells not located at the well site (e.g., centralized tank batteries). For the purposes of the fugitive emission requirements, a well site that only contains one or more wellheads is not subject to these requirements.

United States
Environmental Protection
Agency
                 Office of Air Quality Planning and Standards
                     Sector Policies and Programs Division
                          Research Triangle Park, NC
                                                               Publication No.
                                                               EPA-453/P-51-001
                                                                   August, 2015


[Federal Register Volume 81, Number 210 (Monday, October 31, 2016)]
[Proposed Rules]
[Pages 75365-75366]
[FR Doc No: 2016-26209]

-----------------------------------------------------------------------

ENVIRONMENTAL PROTECTION AGENCY

40 CFR Part 63

[EPA-HQ-OAR-2009-0234; FRL-9954-62-OAR]
RIN 2060-AS75

Mercury and Air Toxics Standards (MATS) Completion of Electronic
Reporting Requirements

AGENCY: Environmental Protection Agency (EPA).

ACTION: Proposed rule; extension of comment period.

-----------------------------------------------------------------------

SUMMARY: On September 29, 2016, the Environmental Protection Agency
(EPA) proposed a rule titled, ``Mercury and Air Toxics Standards (MATS)
Completion of Electronic Reporting Requirements.'' The EPA is extending
the comment period on the proposed rule that was scheduled to close on
October 31, 2016, by 15 days until November 15, 2016. The EPA is making
this change based on three requests for additional time to prepare
comments on this proposed rule.

DATES: The public comment period for the proposed rule published in the
Federal Register on September 29, 2016 (81 FR 67062), is being
extended. Written comments must be received on or before November 15,
2016.

ADDRESSES: The EPA has established a docket for the proposed rulemaking
(available at http://www.regulations.gov). The Docket ID No. is EPA-HQ-
OAR-2009-0234. Submit your comments, identified by

Docket ID No. EPA-HQ-OAR-2009-0234, to the Federal eRulemaking Portal:
http://www.regulations.gov. Follow the online instructions for
submitting comments. Once submitted, comments cannot be edited or
withdrawn. The EPA may publish any comment received to its public
docket. Do not submit electronically any information you consider to be
Confidential Business Information (CBI) or other information whose
disclosure is restricted by statute. If you need to include CBI as part
of your comment, please visit http://www.epa.gov/dockets/comments.html
for instructions. Multimedia submissions (audio, video, etc.) must be
accompanied by a written comment. The written comment is considered the
official comment and should include discussion of all points you wish
to make.
    For additional submission methods, the full EPA public comment
policy, and general guidance on making effective comments, please visit
http://www.epa.gov/dockets/comments.html.

FOR FURTHER INFORMATION CONTACT: For additional information on this
action, contact Barrett Parker, Sector Policies and Programs Division,
Office of Air Quality Planning and Standards (D243-05), Environmental
Protection Agency, Research Triangle Park, NC 27711; telephone number:
(919) 541-5635; email address<EMAIL_ADDRESS>
SUPPLEMENTARY INFORMATION: To allow additional time for stakeholders to
provide comments, the EPA has decided to extend the public comment
period until November 15, 2016.

    Dated: October 24, 2016.
Stephen Page,
Director, Office of Air Quality Planning and Standards.
[FR Doc. 2016-26209 Filed 10-28-16; 8:45 am]
 BILLING CODE 6560-50-P


Comment Info: =================

General Comment:Ecigs and eliquids have helped me stop smoking and saved me money, i no longer have a bad cough and feel better using my ecig.i feel that with out the proper testing and facts it makes no sense to deem ecigs and liquids to be in the same category as tabacco.

 A 75 day comment period is insufficient time for the vaping industry and the wider vaping community to comment on the proposed deeming regulations. I would respectfully request that the period for comment be extended to 180 days.


[Federal Register Volume 76, Number 87 (Thursday, May 5, 2011)]
[Notices]
[Page 25696]
[FR Doc No: 2011-10965]

-----------------------------------------------------------------------

DEPARTMENT OF HEALTH AND HUMAN SERVICES

Food and Drug Administration

[Docket No. FDA-2009-D-0322]

Guidance for Industry on Dosage Delivery Devices for Orally
Ingested OTC Liquid Drug Products; Availability

AGENCY: Food and Drug Administration, HHS.

ACTION: Notice.

-----------------------------------------------------------------------

SUMMARY: The Food and Drug Administration (FDA) is announcing the
availability of a guidance for industry entitled ``Dosage Delivery
Devices for Orally Ingested OTC Liquid Drug Products.'' This document
is intended to provide guidance to firms that are manufacturing,
marketing, or distributing orally ingested over-the-counter (OTC)
liquid drug products packaged with dosage delivery devices (e.g.,
calibrated cups, droppers, syringes, or spoons). FDA is issuing this
guidance because of ongoing concerns about potentially serious
accidental drug overdoses that can result from the use of dosage
delivery devices with markings that are inconsistent or incompatible
with the labeled dosage directions for orally ingested OTC liquid drug
products.

DATES: Submit either electronic or written comments on Agency guidances
at any time.

ADDRESSES: Submit written requests for single copies of this guidance
to the Division of Drug Information, Center for Drug Evaluation and
Research, Food and Drug Administration, 10903 New Hampshire Ave., Bldg.
51, rm. 2201, Silver Spring, MD 20993-0002. Send one self-addressed
adhesive label to assist that office in processing your requests. See
the SUPPLEMENTARY INFORMATION section for electronic access to the
guidance document.
    Submit electronic comments on the guidance to http://www.regulations.gov. Submit written comments to the Division of Dockets
Management (HFA-305), Food and Drug Administration, 5630 Fishers Lane,
rm. 1061, Rockville, MD 20852.

FOR FURTHER INFORMATION CONTACT: Spencer Salis, Center for Drug
Evaluation and Research, Food and Drug Administration, 10903 New
Hampshire Ave., Building 51, rm. 5216, Silver Spring, MD 20993-0002,
301-796-3327.

SUPPLEMENTARY INFORMATION:

I. Background

    FDA is announcing the availability of a guidance for industry
entitled ``Dosage Delivery Devices for Orally Ingested OTC Liquid Drug
Products.'' The Agency has determined that many orally ingested OTC
liquid drug products in the marketplace are packaged with dosage
delivery devices that bear markings that are inconsistent with the
labeled dosage directions, contain superfluous markings, or are missing
necessary markings. FDA is issuing this guidance because of ongoing
concerns about potentially serious accidental drug overdoses that can
result from the use of dosage delivery devices with markings that are
inconsistent or incompatible with the labeled dosage directions for
orally ingested OTC drug products. FDA recommends that dosage delivery
devices be included for all orally ingested OTC drug products that are
liquid formulations, that they should bear markings that are consistent
with the labeled dosage directions, and that they should be labeled in
a manner that attempts to ensure that they are used only with the
products with which they are included.
    In the Federal Register of November 5, 2009 (74 FR 57319), FDA
announced the availability of a draft guidance for industry entitled
``Dosage Delivery Devices for Over-the-Counter Liquid Drug Products.''
The notice gave interested persons an opportunity to comment by
February 2, 2010. We received a number of comments from individuals,
firms, and consumer groups. We have carefully considered the comments
and, where appropriate, have made corrections, added information, or
clarified the information in the guidance in response to the comments
or on our own initiative.
    This guidance is being issued consistent with FDA's good guidance
practices regulation (21 CFR 10.115). The guidance represents the
Agency's current thinking on dosage delivery devices for orally
ingested OTC liquid drug products. It does not create or confer any
rights for or on any person and does not operate to bind FDA or the
public. An alternative approach may be used if such approach satisfies
the requirements of the applicable statutes and regulations.

II. Comments

    Interested persons may submit to the Division of Dockets Management
(see ADDRESSES) either electronic or written comments regarding this
document. It is only necessary to send one set of comments. It is no
longer necessary to send two copies of mailed comments. Identify
comments with the docket number found in brackets in the heading of
this document. Received comments may be seen in the Division of Dockets
Management between 9 a.m. and 4 p.m., Monday through Friday.

III. Electronic Access

    Persons with access to the Internet may obtain the document at
either http://www.fda.gov/Drugs/GuidanceComplianceRegulatoryInformation/Guidances/default.htm or http://www.regulations.gov.

    Dated: April 28, 2011.
Leslie Kux,
Acting Assistant Commissioner for Policy.
[FR Doc. 2011-10965 Filed 5-4-11; 8:45 am]
BILLING CODE 4160-01-P