(a) Applicability. - (i) These regulations apply to all PAD and single-well oil and gas production facilities or sources, and all compressor stations, located in the Upper Green River Basin (UGRB) ozone nonattainment area that exist as of January 1, 2014. The UGRB ozone nonattainment area is that area which was adopted by reference from 40 CFR part 81.351, revised and published as of July 1, 2013, not including any later amendments. Copies of the Code of Federal Regulations (CFR) are available for public inspection and can be purchased from the Department of Environmental Quality, Air Quality Division, Cheyenne Office. Contact information for the Cheyenne Office is available at: http://deq.wyoming.gov/. Copies of the CFR can also be purchased from Government Institutes, 15200 NBN Way, Building B, Blue Ridge Summit, PA 17214, or online at: http://www.gpo.gov/fdsys/browse/collectionCfr.action?collectionCode=CFR.
- (ii) PAD and single-well oil and gas production facilities or sources, shall comply with all applicable requirements of these regulations unless a Wyoming Air Quality Standards and Regulations (WAQSR) Chapter 6, Section 2 permit has been issued that meets or exceeds the control requirements of these regulations; and
- (iii) A compressor station, as defined in Subsection (b), shall comply with the requirements of Subsection (g) of these regulations unless a WAQSR Chapter 6, Section 2 permit has been issued that meets or exceeds the Subsection (g) requirements; and
- (iv) In spite of the requirements of Chapter 6, Section 2(a)(i) and (iii) of the WAQSR, a preconstruction permit under Chapter 6, Section 2 is not required for any control device (flare/enclosed combustion unit) or equipment identified in these regulations unless a facility or source is required to obtain a permit under Chapter 6, Section 4 or Section 13.
- (v) A WAQSR Chapter 6, Section 2 permit will be required for the use of any alternative emission control device and/or equipment to be used in lieu of, or in combination with, a combustion device required by these regulations.
(b) Definitions.
"Composite extended hydrocarbon analysis" are averaged extended hydrocarbon compositions based on samples from at least five wells producing from the same formation and under similar conditions (± 25 psig).
"Compressor station" means any permanent combination of one or more compressors that move natural gas at increased pressure from fields, in transmission pipelines, or into storage.
"Dehydration unit" means a system that uses glycol to absorb water from produced gas before it is introduced into gas sales or collection lines.
"Extended hydrocarbon analysis" means a gas chromatograph analysis performed on pressurized hydrocarbon liquid (oil/condensate) and gas samples, and shall include speciated hydrocarbons from methane (C1) through decane (C10), and the following Hazardous Air Pollutants (HAP): benzene, toluene, ethyl-benzene, xylenes (BTEX), n-hexane, and 2-2-4 -trimethylpentane.
"Facility components" consist of flanges, connectors (other than flanges), open-ended lines, pumps, valves and "other" components listed in Table 2-4 from EPA-453/R-95-017 at the site grouped by stream (gas, light oil, heavy oil, water/oil). Table 2-4 from EPA-453/R-95-017 is available online at: http://deq.wyoming.gov/aqd/ or http://www.epa.gov/ttnchie1/efdocs/equiplks.pdf.
"Flashing emissions" means VOC emissions, including HAP components, that occur when gases are released from produced liquids (oil, condensate, produced water, or a mixture thereof) that are exposed to temperature increases or pressure drops as they are transferred from pressurized vessels to lower pressure separation vessels or to atmospheric storage tanks.
"Optical gas imaging instrument" means an instrument that makes visible, emissions that may otherwise be invisible to the naked eye.
"PAD facility" means a location where more than one well and/or associated production equipment are located, where some or all production equipment is shared by more than one well or where well streams from more than one well are routed through individual production trains at the same location.
"Separation vessels" means all gun barrels, production and test separators, production and test treaters, water knockouts, gas boots, flash separators, and drip pots.
"Single-well facility" means a facility where production equipment is associated with only one well.
"Storage tanks" means any tanks that contain oil, condensate, produced water, or some mixture thereof.
(c) Flashing Emissions at Existing PAD and Single-Well Facilities or Sources as of January 1, 2014. - (i) VOC emissions from all existing storage tanks and all existing separation vessels are subject to these regulations.
- (A) For total uncontrolled VOC emissions from flashing that are greater than or equal to 4 tons per year (tpy), flashing emissions from all produced oil, condensate, water tanks, and separation vessels shall be controlled to at least 98% manufacturer-designed VOC destruction efficiency by January 1, 2017.
- (B) Storage tanks that are on site for use during emergency or upset conditions are not subject to the control requirements in this Subsection.
- (C) Emergency, open-top, and/or blowdown tanks shall not be used as active storage tanks but may be used for temporary storage.
- (I) Emergency tanks shall only be utilized for unavoidable equipment malfunctions as defined in Chapter 1, Section 5 of the WAQSR.
- (II) If emergency, open-top, and/or blowdown tanks are utilized, they must be emptied within seven (7) calendar days after the liquid volume reaches 100 barrels, or in no event less frequently than once every ninety (90) calendar days.
- (III) All tanks subject to this Subsection must have a liquid level gauge, or equivalent device, in place by January 1, 2017.
- (D) Control Removal. The removal of flashing emissions control devices will be allowed pursuant to the requirements in Subparagraph (h)(iii)(E), after one (1) year from the date of installation if uncontrolled VOC flashing emissions have declined to less than, and will remain below 4 tpy.
- (ii) Calculation for Flashing Emissions.
- (A) Determine the average daily condensate/oil production for the previous twelve (12) calendar months in barrels per day (bpd).
- (B) Use any generally accepted model in accordance with 40 CFR 60, Subpart OOOO or direct measurement of tank emissions to determine uncontrolled VOC emissions.
- (C) Model input shall consist of:
- (I) A site-specific analysis of liquids, or composite extended hydrocarbon analysis of liquids, taken from the pressurized, upstream separation equipment under normal operating conditions;
- (II) Average daily condensate/oil production rate as determined in Subparagraph (c)(ii)(A) of these regulations;
- (III) Site-specific or composite extended hydrocarbon analyses will be no older than three (3) years from date of flashing emissions calculation including;
- (1.) The average, actual equipment operational parameters, including separator temperature and pressure; and
- (2.) American Petroleum Institute (API) gravity and Reid vapor pressure (RVP) of sales oil.
(d) Dehydration Units at Existing PAD and Single-Well Facilities or Sources as of January 1, 2014. - (i) VOC emissions released from all existing dehydration units are subject to these regulations.
- (A) For total uncontrolled VOC emissions from all dehydration units that are greater than or equal to 4 tpy, VOC emissions from all dehydration units shall be controlled to at least 98% manufacturer-designed VOC destruction efficiency and equipped with reboiler still vent condensers by January 1, 2017.
- (B) Control Removal. The removal of combustion units used to achieve the 98% manufacturer-designed VOC destruction efficiency will be allowed pursuant to the requirements in Subparagraph (h)(iii)(E), after one (1) year from the date of installation if total uncontrolled VOC emissions from all dehydration units are less than, and will remain below 4 tpy, and all dehydration units are equipped with reboiler still vent condensers.
- (ii) Calculation for Dehydration Units.
- (A) Determine the average daily gas production rate for the previous twelve (12) calendar months in million cubic feet per day (MMCFD).
- (B) Use the model GRI-GLYCalc, Version 4.0 or higher, and the annualized average daily production rate to determine annualized uncontrolled VOC emissions from the dehydration unit process vents. Process vents include reboiler still vents and glycol flash separators.
- (C) Model input shall consist of:
- (I) A site-specific wet gas analysis or composite extended hydrocarbon analysis of wet gas taken upstream of the contact tower under normal operating conditions;
- (II) Average daily gas production rate as determined in Subparagraph (d)(ii)(A) of these regulations; and
- (III) Site-specific or composite extended hydrocarbon analyses shall be no older than three (3) years from date of the dehydration unit calculation including;
- (1.) The average, actual equipment operational parameters, including wet gas temperature and pressure, dry gas water content, glycol flash separator temperature and pressure, stripping gas source and rate; and
- (2.) The maximum lean glycol circulation rate in gallons per minute (gpm) for the glycol circulation pump in use.
(e) Existing Pneumatic Pumps at PAD and Single-Well Facilities or Sources as of January 1, 2014. VOC emissions associated with the discharge streams of all natural gas-operated pneumatic pumps shall be controlled to at least 98% manufacturer-designed VOC destruction efficiency, or the pump discharge streams shall be routed into a sales line, collection line, fuel supply line, other closed loop system, or replaced with solar, electric, or air driven pumps by January 1, 2017.
(f) Existing Pneumatic Controllers at PAD and Single-Well Facilities or Sources as of January 1, 2014. Natural gas-operated pneumatic controllers shall be low (less than 6 standard cubic feet per hour (scfh)) or zero bleed controllers or the controller discharge streams shall be routed into a sales line, collection line, fuel supply line, or other closed loop system by January 1, 2017.
(g) Fugitive Emissions. - (i) For PAD and single-well facilities or sources, and compressor stations, in existence prior to January 1, 2014, with fugitive emissions greater than or equal to 4 tpy of VOCs, including HAP components, operators shall develop and implement a Leak Detection and Repair (LDAR) Protocol by January 1, 2017.
- (A) The LDAR Protocol inspection monitoring schedule shall be no less frequent than quarterly; and
- (B) Shall include a leak repair schedule; and
- (C) Each quarterly inspection shall consist of some combination of 40 CFR part 60, Appendix A, Method 21, an optical gas imaging instrument, other instrument-based technologies, or audio-visual-olfactory (AVO) inspections.
- (D) An LDAR Protocol consisting of only AVO inspections will not satisfy the requirements of this Subsection.
- (ii) Calculation for Fugitive Emissions.
- (A) Fugitive emissions shall be estimated using Table 2-4 from EPA-453/R-95-017, Protocol for Equipment Leak Emission Estimates, and the owner(s) or operator(s) facility component count.
- (I) PAD and single-well facility or source component counts shall be determined by actual field count, or a representative component count from the same geographical area, taken from no less than one hundred (100) wells located at a PAD or single-well facility.
- (II) Compressor station component counts shall be determined by actual field count.
- (III) Emission factors in the Protocol for Equipment Leak Emission Estimates are not intended to be used to represent emissions from components that are improperly designed or equipment not maintained properly.
- (B) Site-specific speciated hydrocarbon emission rates can be estimated by multiplying the total hydrocarbon emission rate, estimated in Subparagraph (g)(ii)(A) above, by measured VOC and HAP weight fractions.
(h) Monitoring, Recordkeeping, and Reporting. - (i) Monitoring. The owner(s) or operator(s) of each PAD and single-well facility or source, or compressor station, shall comply with all applicable monitoring requirements as specified by this Paragraph.
- (A) Operation of a combustion device used to control emissions shall be continually monitored using any device(s) that sense and record a parameter(s) that indicates whether the combustion device is functioning to achieve the 98% manufacturer-designed VOC destruction efficiency requirements as specified by these regulations.
- (I) The combustion device shall be designed, constructed, operated, and maintained to be smokeless, to satisfy the requirements of Chapter 3, Section 6(b)(i) of the WAQSR.
- (II) Visible emissions shall not exceed a total of five (5) minutes during any two (2) consecutive hours as determined by 40 CFR part 60, Appendix A, Method 22.
- (B) All emission control devices and equipment used to reduce VOC emissions at any PAD and single-well facility or source shall be operated and maintained pursuant to manufacturer specifications or equivalent, and consistent with good engineering and maintenance practices.
- (C) Owner(s) or operator(s) shall conduct a quarterly site evaluation of control equipment, systems, and devices that include, but are not limited to, combustion units, reboiler overheads condensers, storage tanks, drip tanks, vent lines, connectors, fittings, valves, relief valves, hatches, and any other appurtenance employed to, or involved with, eliminating, reducing, containing or collecting vapors and routing them to an emission control system or device.
- (I) At least one (1) of the quarterly evaluations per calendar year shall consist of 40 CFR part 60, Appendix A, Method 21, an optical gas imaging instrument, or other instrument-based technologies.
- (II) Owner(s) or operator(s) required to implement an LDAR Protocol have satisfied the requirements of Subparagraph (C) above.
- (ii) Recordkeeping. The owner(s) or operator(s) of each PAD and single-well facility or source, or compressor station, shall comply with all applicable recordkeeping requirements as specified by this Paragraph. Records shall be maintained for a period of five (5) years and made available to the Division upon request.
- (A) All emission control devices and equipment are adequately designed and sized to achieve the control efficiency required by these regulations and to accommodate fluctuations in emissions.
- (B) Owner(s) or operator(s) shall maintain the following records for each combustion device:
- (I) Manufacturer-designed VOC destruction efficiency.
- (II) Records of the parameter monitoring during active site operation under Subparagraph (h)(i)(A) including;
- (1.) A description of the reason(s) for the absence of the monitored parameter;
- (2.) The steps taken to return the combustion device back to the 98% manufacturer-designed VOC destruction efficiency; and
- (3.) Date and duration of periods when the combustion device and/or the associated containment and collection equipment is not functioning to achieve the 98% manufacturer-designed VOC destruction efficiency.
- (III) Date and duration of visible emissions from the combustion device.
- (C) Owner(s) or operator(s) shall record and maintain records for fugitive emissions pursuant to Subsection (g) of these regulations. These records shall include the dates and results of all LDAR inspections performed pursuant to the LDAR protocol for a PAD and single-well facility or source, or compressor station, including the date(s) and type of corrective action taken as a result of the required inspections.
- (D) Records of the date, duration, and reason for emergency and/or blowdown tank usage, shall be maintained pursuant to Subparagraph (c)(i)(C) of these regulations.
- (E) Owners or operators that utilize emergency, open-top, and/or blowdown tanks pursuant to Subsection (c) shall record and maintain monthly records for volume stored in tanks, volume removed from tanks, and the date when the removal of liquid occurred.
- (iii) Reporting. The owner(s) or operator(s) of each PAD and single-well facility or source, or compressor station, shall comply with all applicable reporting requirements as specified by this Subsection.
- (A) The owner(s) or operator(s) shall provide the name and location of the PAD and single-well facility or source, or compressor station, anticipated to require the installation of a combustion device, replacement of equipment, or implementation of an LDAR Protocol, if applicable, by January 1, 2016.
- (B) Installation Notification of Control Device(s) and Associated Equipment (including pneumatic pumps). Owner(s) or operator(s) of each PAD and single-well facility or source subject to the requirements of these regulations shall submit a report to the Division thirty (30) days after the end of each calendar quarter, beginning January 1, 2016, containing the following, if applicable:
- (I) The number of pollution control devices or equipment installed;
- (II) Pollution control installation date, type of control, and equipment controlled;
- (III) Name and location of the PAD and/or single-well facility or source where controls are installed.
- (C) Installation Notification of Pneumatic Controller(s). Owner(s) or operator(s) of each PAD and single-well facility or source subject to the requirements of these regulations shall submit a report to the Division thirty (30) days after the end of each calendar quarter, beginning January 1, 2016, containing the following, if applicable:
- (I) The number and type of pneumatic controllers installed and date of installation; and
- (II) Name and location of the PAD and/or single-well facility or source where pneumatic controllers are installed.
- (D) The final, quarterly notification of installation required under Subsections (B) and (C) above, shall be submitted no later than January 31, 2017, if applicable.
- (E) Removal Notification of Control Device(s). The owner(s) or operator(s) of each PAD and single-well facility or source subject to the requirements of these regulations shall submit a demonstration to the Division for approval prior to removal of any pollution control device. This demonstration shall contain at a minimum:
- (I) The average daily condensate/oil or gas production rate for the previous twelve (12) calendar months;
- (II) Emissions as determined by utilizing paragraph (I) above, and the calculation for flashing emissions in Paragraph (c)(ii), and/or the calculation for dehydration units in Paragraph (d)(ii) of these regulations;
- (III) Any additional supporting data used to calculate emissions, including but not limited to, a site specific or composite extended hydrocarbon analysis no older than three (3) years from the proposed removal date; and
- (IV) Name and location of the PAD and/or single-well facility or source where controls are proposed for removal.
- (F) Any PAD and single-well facility or source, or compressor station, subject to requirements of Subsection (g) of these regulations shall submit, for Division review and approval, the LDAR Protocol prior to implementation of the protocol.
- (G) All report and notification submissions shall be certified as being true, accurate, and complete by a responsible official to the best of their knowledge. A responsible official is an individual who is responsible for the information provided in the reports and notifications, and who accepts responsibility for the reports and notifications.
- (H) The owner(s) or operator(s) shall submit notifications or reports as required in this Subsection to the Division electronically through https://airimpact.wyo.gov or by hard copy to the Cheyenne Office and Lander Field Office. Contact information for the Cheyenne and Lander offices is located at: http://deq.wyoming.gov/.
(i) Compliance. Compliance with Chapter 8, Section 6 of the WAQSR, does not relieve any owner(s) or operator(s) of a PAD and single-well facility or source, or compressor station, from the responsibility to comply with any other applicable requirements set forth in any federal or State law, rule or regulation, or in any permit.
Amended, Eff. 12/20/2016.