Current through September 21, 2024
(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:
https://ecfr.gov.
(ii) PAD and single-well oil and gas
production facilities or sources, shall comply with all applicable requirements
of these regulations unless a 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://www3.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 calendar
days after the liquid volume reaches 100 barrels, or in no event less
frequently than once every 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 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 12 calendar months in barrels per
day (bpd).
(B) Use any generally
accepted model in accordance with 40 CFR Part 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 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 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 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 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 minutes during any two 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 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
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
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 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 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 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.
