propane) measurement range may be used.
* * * * *
    (12) The owner or operator of a combustion control device model
tested under this paragraph (d)(12) must submit the information listed
in paragraphs (d)(12)(i) through (vi) of this section for each test run
in the test report required by this section in accordance with Sec.
60.5420a(b)(10). Owners or operators who claim that any of the
performance test information being submitted is confidential business
information (CBI) must submit a complete file including information
claimed to be CBI, on a compact disc, flash drive, or other commonly
used electronic storage media to the EPA. The electronic media must be
clearly marked as CBI and mailed to Attn: CBI Document Control Officer;
Office of Air Quality Planning and Standards (OAQPS), Room 521; 109
T.W. Alexander Drive; Research Triangle Park, NC 27711. The same file
with the CBI omitted must be submitted to<EMAIL_ADDRESS>* * * * *

0
20. Section 60.5415a is amended by:
0
a. Revising the section heading and paragraphs (b) introductory text
and (b)(3);
0
b. Removing paragraph (b)(4);
0
c. Revising paragraphs (c)(1), (g) introductory text, (h) introductory
text, and (h)(2); and
0
d. Adding paragraphs (i) and (j).
    The revisions and additions read as follows:

Sec.  60.5415a   How do I demonstrate continuous compliance with the
standards for my well, centrifugal compressor, reciprocating
compressor, pneumatic controller, pneumatic pump, storage vessel,
collection of fugitive emissions components at a well site, and
collection of fugitive emissions components at a compressor station
affected facilities, equipment leaks at onshore natural gas processing
plants and sweetening unit affected facilities?

* * * * *
    (b) For each centrifugal compressor affected facility and each
pneumatic pump affected facility, you must demonstrate continuous
compliance according to paragraph (b)(3) of this section. For each
centrifugal compressor affected facility, you also must demonstrate
continuous compliance according to paragraphs (b)(1) and (2) of this
section.
* * * * *
    (3) You must submit the annual reports required by Sec.
60.5420a(b)(1), (3), and (8) and maintain the records as specified in
Sec.  60.5420a(c)(2), (6) through (11), (16), and (17), as applicable.
* * * * *
    (c) * * *
    (1) You must continuously monitor the number of hours of operation
for each reciprocating compressor affected facility or track the number
of months since initial startup, since August 2, 2016, or since the
date of the most recent reciprocating compressor rod packing
replacement, whichever is latest.
* * * * *
    (g) For each sweetening unit affected facility, you must
demonstrate continuous compliance with the standards for SO2
specified in Sec.  60.5405a(b) according to paragraphs (g)(1) and (2)
of this section.
* * * * *
    (h) For each collection of fugitive emissions components at a well
site and each collection of fugitive emissions components at a
compressor station, you must demonstrate continuous compliance with the
fugitive emission standards specified in Sec.  60.5397a(a)(1) according
to paragraphs (h)(1) through (4) of this section.
* * * * *
    (2) You must repair each identified source of fugitive emissions as
required in Sec.  60.5397a(h).
* * * * *
    (i) For each collection of fugitive emissions components at a well
site complying with Sec.  60.5397a(a)(2), you must demonstrate
continuous compliance according to paragraphs (i)(1) through (4) of
this section. You must perform the calculations shown in paragraphs
(i)(1) through (4) of this section within 45 days of the end of each
month. The rolling 12-month average of the total well site production
determined according to paragraph (i)(4) of this section must be at or
below 15 boe per day.
    (1) Begin with the most recent 12-month average.
    (2) Determine the daily combined oil and natural gas production of
each individual well at the well site for the month. To convert gas
production to equivalent barrels of oil, divide the cubic feet of gas
produced by 6,000.
    (3) Sum the daily production for each individual well at the well
site and divide by the number of days in the month. This is the average
daily total well site production for the month.
    (4) Use the result determined in paragraph (i)(3) of this section
and average with the daily total well site production values determined
for each of the preceding 11 months to calculate the rolling 12-month
average of the total well site production.
    (j) To demonstrate that the well site produced at or below 15 boe
per day for the first 30 days after startup of production as specified
in Sec.  60.5397a(3), you must calculate the daily production for each
individual well at the well site during the first 30 days of production
after completing any action listed in Sec.  60.5397a(a)(2)(i) through
(v) and sum the individual well production values to obtain the total
well site production. The calculation must be performed within 45 days
of the end of the first 30 days of production after completing any
action listed in Sec.  60.5397a(a)(2)(i) through (v). To convert gas
production to equivalent barrels of oil, divide cubic feet of gas
produced by 6,000.

0
21. Section 60.5416a is amended by revising the introductory text and
paragraphs (a) introductory text, (a)(4) introductory text, (b)
introductory text, (c) introductory text, (c)(1), and (c)(2)
introductory text, adding paragraph (c)(2)(iv), and revising paragraph
(d) to read as follows:

Sec.  60.5416a   What are the initial and continuous cover and closed
vent system inspection and monitoring requirements for my centrifugal
compressor, reciprocating compressor, pneumatic pump, and storage
vessel affected facilities?

    For each closed vent system or cover at your centrifugal
compressor, reciprocating compressor, pneumatic pump, and storage
vessel affected facilities, you must comply with the applicable
requirements of paragraphs (a) through (d) of this section.
    (a) Inspections for closed vent systems and covers installed on
each centrifugal compressor or reciprocating compressor affected
facility. Except as provided in paragraphs (b)(11) and (12) of this
section, you must inspect each closed vent system according to the
procedures and schedule specified in paragraphs (a)(1) and (2) of this
section, inspect each cover according to the procedures and schedule
specified in paragraph (a)(3) of this section, and inspect each bypass
device according to the procedures of paragraph (a)(4) of this section.
* * * * *
    (4) For each bypass device, except as provided for in Sec.
60.5411a(a)(3)(ii), you must meet the requirements of paragraph
(a)(4)(i) or (ii) of this section.
* * * * *
    (b) No detectable emissions test methods and procedures. If you are
required to conduct an inspection of a closed vent system or cover at
your centrifugal compressor or reciprocating compressor affected
facility as specified in paragraph (a)(1), (2), or (3) of this section,
you must meet the requirements of paragraphs (b)(1) through (13) of
this section.
* * * * *
    (c) Cover and closed vent system inspections for storage vessel
affected facilities. If you install a control device or route emissions
to a process, you must comply with the inspection and recordkeeping
requirements for each closed vent system and cover as specified in
paragraphs (c)(1) and (2) of this section. You must also comply with
the requirements of paragraphs (c)(3) through (7) of this section.
    (1) Closed vent system inspections. For each closed vent system,
you must conduct an inspection as specified in paragraphs (c)(1)(i)
through (iii) or paragraph (c)(1)(iv) of this section.
    (i) You must maintain records of the inspection results as
specified in Sec.  60.5420a(c)(6).
    (ii) Conduct olfactory, visual, and auditory inspections at least
once every calendar month for defects that could result in air
emissions. Defects include, but are not limited to, visible cracks,
holes, or gaps in piping; loose connections; liquid leaks; or broken or
missing caps or other closure devices.
    (iii) Monthly inspections must be separated by at least 14 calendar
days.
    (iv) Conduct optical gas imaging inspections for any visible
emissions at the same frequency as the frequency for the collection of
fugitive emissions components located at the same type of site, as
specified in Sec.  60.5397a(g)(1).

    (2) Cover inspections. For each cover, you must conduct inspections
as specified in paragraphs (c)(2)(i) through (iii) or paragraph
(c)(2)(iv) of this section.
* * * * *
    (iv) Conduct optical gas imaging inspections for any visible
emissions at the same frequency as the frequency for the collection of
fugitive emissions components located at the same type of site, as
specified in Sec.  60.5397a(g)(1).
* * * * *
    (d) Closed vent system inspections for pneumatic pump affected
facilities. If you install a control device or route emissions to a
process, you must comply with the inspection and recordkeeping
requirements for each closed vent system as specified in paragraph
(d)(1) of this section. You must also comply with the requirements of
paragraphs (c)(3) through (7) of this section.
    (1) For each closed vent system, you must conduct an inspection as
specified in paragraphs (d)(1)(i) through (iii), paragraph (d)(1)(iv),
or paragraph (d)(1)(v) of this section.
    (i) You must maintain records of the inspection results as
specified in Sec.  60.5420a(c)(6).
    (ii) Conduct olfactory, visual, and auditory inspections at least
once every calendar month for defects that could result in air
emissions. Defects include, but are not limited to, visible cracks,
holes, or gaps in piping; loose connections; liquid leaks; or broken or
missing caps or other closure devices.
    (iii) Monthly inspections must be separated by at least 14 calendar
days.
    (iv) Conduct optical gas imaging inspections for any visible
emissions at the same frequency as the frequency for the collection of
fugitive components located at the same type of site, as specified in
Sec.  60.5397a(g)(1).
    (v) Conduct inspections as specified in paragraphs (a)(1) and (2)
of this section.
    (2) [Reserved]

0
22. Section 60.5417a is amended by revising the introductory text and
paragraph (a) to read as follows:

Sec.  60.5417a   What are the continuous control device monitoring
requirements for my centrifugal compressor and storage vessel affected
facilities?

    You must meet the applicable requirements of this section to
demonstrate continuous compliance for each control device used to meet
emission standards for your storage vessel affected facility or
centrifugal compressor affected facility.
    (a) For each control device used to comply with the emission
reduction standard for centrifugal compressor affected facilities in
Sec.  60.5380a(a)(1), you must install and operate a continuous
parameter monitoring system for each control device as specified in
paragraphs (c) through (g) of this section, except as provided for in
paragraph (b) of this section. If you install and operate a flare in
accordance with Sec.  60.5412a(a)(3), you are exempt from the
requirements of paragraphs (e) and (f) of this section. If you install
and operate an enclosed combustion device or control device which is
not specifically listed in paragraph (d) of this section, you must
demonstrate continuous compliance according to paragraphs (h)(1)
through (4) of this section.
* * * * *

0
23. Revise Sec.  60.5420a to read as follows:

Sec.  60.5420a   What are my notification, reporting, and recordkeeping
requirements?

    (a) Notifications. You must submit the notifications according to
paragraphs (a)(1) and (2) of this section if you own or operate one or
more of the affected facilities specified in Sec.  60.5365a that was
constructed, modified, or reconstructed during the reporting period.
    (1) If you own or operate an affected facility that is the group of
all equipment within a process unit at an onshore natural gas
processing plant, or a sweetening unit, you must submit the
notifications required in Sec. Sec.  60.7(a)(1), (3), and (4) and
60.15(d). If you own or operate a well, centrifugal compressor,
reciprocating compressor, pneumatic controller, pneumatic pump, storage
vessel, collection of fugitive emissions components at a well site, or
collection of fugitive emissions components at a compressor station,
you are not required to submit the notifications required in Sec. Sec.
60.7(a)(1), (3), and (4) and 60.15(d).
    (2)(i) If you own or operate a well affected facility, you must
submit a notification to the Administrator no later than 2 days prior
to the commencement of each well completion operation listing the
anticipated date of the well completion operation. The notification
shall include contact information for the owner or operator; the United
States Well Number; the latitude and longitude coordinates for each
well in decimal degrees to an accuracy and precision of five (5)
decimals of a degree using the North American Datum of 1983; and the
planned date of the beginning of flowback. You may submit the
notification in writing or in electronic format.
    (ii) If you are subject to state regulations that require advance
notification of well completions and you have met those notification
requirements, then you are considered to have met the advance
notification requirements of paragraph (a)(2)(i) of this section.
    (3) An owner or operator electing to comply with the provisions of
Sec.  60.5399a shall notify the Administrator of the alternative
fugitive emissions standard selected within the annual report, as
specified in paragraph (b)(7) of this section.
    (b) Reporting requirements. You must submit annual reports
containing the information specified in paragraphs (b)(1) through (8)
and (12) of this section and performance test reports as specified in
paragraph (b)(9) or (10) of this section, if applicable. You must
submit annual reports following the procedure specified in paragraph
(b)(11) of this section. The initial annual report is due no later than
90 days after the end of the initial compliance period as determined
according to Sec.  60.5410a. Subsequent annual reports are due no later
than same date each year as the initial annual report. If you own or
operate more than one affected facility, you may submit one report for
multiple affected facilities provided the report contains all of the
information required as specified in paragraphs (b)(1) through (8) and
(12) of this section. Annual reports may coincide with title V reports
as long as all the required elements of the annual report are included.
You may arrange with the Administrator a common schedule on which
reports required by this part may be submitted as long as the schedule
does not extend the reporting period.
    (1) The general information specified in paragraphs (b)(1)(i)
through (iv) of this section is required for all reports.
    (i) The company name, facility site name associated with the
affected facility, U.S. Well ID or U.S. Well ID associated with the
affected facility, if applicable, and address of the affected facility.
If an address is not available for the site, include a description of
the site location and provide the latitude and longitude coordinates of
the site in decimal degrees to an accuracy and precision of five (5)
decimals of a degree using the North American Datum of 1983.
    (ii) An identification of each affected facility being included in
the annual report.
    (iii) Beginning and ending dates of the reporting period.
    (iv) A certification by a certifying official of truth, accuracy,
and completeness. This certification shall

state that, based on information and belief formed after reasonable
inquiry, the statements and information in the document are true,
accurate, and complete.
    (2) For each well affected facility that is subject to Sec.
60.5375a(a) or (f), the records of each well completion operation
conducted during the reporting period, including the information
specified in paragraphs (b)(2)(i) through (xiv) of this section, if
applicable. In lieu of submitting the records specified in paragraphs
(b)(2)(i) through (xiv) of this section, the owner or operator may
submit a list of each well completion with hydraulic fracturing
completed during the reporting period, and the digital photograph
required by paragraph (c)(1)(v) of this section for each well
completion. For each well affected facility that routes flowback
entirely through one or more production separators, only the records
specified in paragraphs (b)(2)(i) through (iv) and (vi) of this section
are required to be reported. For periods where salable gas is unable to
be separated, the records specified in paragraphs (b)(2)(iv) and (viii)
through (xii) of this section must also be reported, as applicable. For
each well affected facility that is subject to Sec.  60.5375a(g), the
record specified in paragraph (b)(2)(xv) of this section is required to
be reported.
    (i) Well Completion ID.
    (ii) Latitude and longitude of the well in decimal degrees to an
accuracy and precision of five (5) decimals of a degree using North
American Datum of 1983.
    (iii) U.S. Well ID.
    (iv) The date and time of the onset of flowback following hydraulic
fracturing or refracturing or identification that the well immediately
starts production.
    (v) The date and time of each attempt to direct flowback to a
separator as required in Sec.  60.5375a(a)(1)(ii).
    (vi) The date and time that the well was shut in and the flowback
equipment was permanently disconnected, or the startup of production.
    (vii) The duration (in hours) of flowback.
    (viii) The duration (in hours) of recovery and disposition of
recovery (i.e., routed to the gas flow line or collection system, re-
injected into the well or another well, used as an onsite fuel source,
or used for another useful purpose that a purchased fuel or raw
material would serve).
    (ix) The duration (in hours) of combustion.
    (x) The duration (in hours) of venting.
    (xi) The specific reasons for venting in lieu of capture or
combustion.
    (xii) For any deviations recorded as specified in paragraph
(c)(1)(ii) of this section, the date and time the deviation began, the
duration of the deviation, and a description of the deviation.
    (xiii) For each well affected facility subject to Sec.
60.5375a(f), a record of the well type (i.e., wildcat well, delineation
well, or low pressure well (as defined Sec.  60.5430a)) and supporting
inputs and calculations, if applicable.
    (xiv) For each well affected facility for which you claim an
exception under Sec.  60.5375a(a)(3), the specific exception claimed
and reasons why the well meets the claimed exception.
    (xv) For each well affected facility with less than 300 scf of gas
per stock tank barrel of oil produced, the supporting analysis that was
performed in order the make that claim, including but not limited to,
GOR values for established leases and data from wells in the same basin
and field.
    (3) For each centrifugal compressor affected facility, the
information specified in paragraphs (b)(3)(i) through (v) of this
section.
    (i) An identification of each centrifugal compressor using a wet
seal system constructed, modified, or reconstructed during the
reporting period.
    (ii) For each deviation that occurred during the reporting period
and recorded as specified in paragraph (c)(2) of this section, the date
and time the deviation began, the duration of the deviation, and a
description of the deviation.
    (iii) If required to comply with Sec.  60.5380a(a)(2), the
information in paragraphs (b)(3)(iii)(A) through (C) of this section.
    (A) Dates of each inspection required under Sec.  60.5416a(a) and
(b);
    (B) Each defect or leak identified during each inspection, date of
repair or the date of anticipated repair if the repair is delayed; and
    (C) Date and time of each bypass alarm or each instance the key is
checked out if you are subject to the bypass requirements of Sec.
60.5416a(a)(4).
    (iv) If complying with Sec.  60.5380a(a)(1) with a control device
tested under Sec.  60.5413a(d) which meets the criteria in Sec.
60.5413a(d)(11) and (e), the information in paragraphs (b)(3)(iv)(A)
through (D) of this section.
    (A) Identification of the compressor with the control device.
    (B) Make, model, and date of purchase of the control device.
    (C) For each instance where the inlet gas flow rate exceeds the
manufacturer's listed maximum gas flow rate, where there is no
indication of the presence of a pilot flame, or where visible emissions
exceeded 1 minute in any 15-minute period, include the date and time
the deviation began, the duration of the deviation, and a description
of the deviation.
    (D) For each visible emissions test following return to operation
from a maintenance or repair activity, the date of the visible
emissions test, the length of the test, and the amount of time for
which visible emissions were present.
    (v) If complying with Sec.  60.5380a(a)(1) with a control device
not tested under Sec.  60.5413a(d), identification of the compressor
with the tested control device, the date the performance test was
conducted, and pollutant(s) tested. Submit the performance test report
following the procedures specified in paragraph (b)(9) of this section.
    (4) For each reciprocating compressor affected facility, the
information specified in paragraphs (b)(4)(i) through (iii) of this
section.
    (i) The cumulative number of hours of operation or the number of
months since initial startup, since August 2, 2016, or since the
previous reciprocating compressor rod packing replacement, whichever is
latest. Alternatively, a statement that emissions from the rod packing
are being routed to a process through a closed vent system under
negative pressure.
    (ii) If applicable, for each deviation that occurred during the
reporting period and recorded as specified in paragraph (c)(3)(iii) of
this section, the date and time the deviation began, duration of the
deviation and a description of the deviation.
    (iii) If required to comply with Sec.  60.5385a(a)(3), the
information in paragraphs (b)(4)(iii)(A) through (C) of this section.
    (A) Dates of each inspection required under Sec.  60.5416a(a) and
(b);
    (B) Each defect or leak identified during each inspection, and date
of repair or date of anticipated repair if repair is delayed; and
    (C) Date and time of each bypass alarm or each instance the key is
checked out if you are subject to the bypass requirements of Sec.
60.5416a(a)(4).
    (5) For each pneumatic controller affected facility, the
information specified in paragraphs (b)(5)(i) through (iii) of this
section.
    (i) An identification of each pneumatic controller constructed,
modified, or reconstructed during the reporting period, including the
month and year of installation, reconstruction or modification and
identification information that allows traceability to the records
required in paragraph (c)(4)(iii) or (iv) of this section.

    (ii) If applicable, reason why the use of pneumatic controller
affected facilities with a natural gas bleed rate greater than the
applicable standard are required.
    (iii) For each instance where the pneumatic controller was not
operated in compliance with the requirements specified in Sec.
60.5390a, a description of the deviation, the date and time the
deviation began, and the duration of the deviation.
    (6) For each storage vessel affected facility, the information in
paragraphs (b)(6)(i) through (ix) of this section.
    (i) An identification, including the location, of each storage
vessel affected facility for which construction, modification, or
reconstruction commenced during the reporting period. The location of
the storage vessel shall be 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.
    (ii) Documentation of the VOC emission rate determination according
to Sec.  60.5365a(e)(1) for each storage vessel that became an affected
facility during the reporting period or is returned to service during
the reporting period.
    (iii) For each deviation that occurred during the reporting period
and recorded as specified in paragraph (c)(5) of this section, the date
and time the deviation began, duration of the deviation and a
description of the deviation.
    (iv) A statement that you have met the requirements specified in
Sec.  60.5410a(h)(2) and (3).
    (v) For each storage vessel constructed, modified, reconstructed,
or returned to service during the reporting period complying with Sec.
60.5395a(a)(2) with a control device tested under Sec.  60.5413a(d)
which meets the criteria in Sec.  60.5413a(d)(11) and (e), the
information in paragraphs (b)(6)(v)(A) through (D) of this section.
    (A) Identification of the storage vessel with the control device.
    (B) Make, model, and date of purchase of the control device.
    (C) For each instance where the inlet gas flow rate exceeds the
manufacturer's listed maximum gas flow rate, where there is no
indication of the presence of a pilot flame, or where visible emissions
exceeded 1 minute in any 15-minute period, include the date and time
the deviation began, the duration of the deviation, and a description
of the deviation.
    (D) For each visible emissions test following return to operation
from a maintenance or repair activity, the date of the visible
emissions test, the length of the test, and the amount of time for
which visible emissions were present.
    (vi) If complying with Sec.  60.5395a(a)(2) with a control device
not tested under Sec.  60.5413a(d), identification of the storage
vessel with the tested control device, the date the performance test
was conducted, and pollutant(s) tested. Submit the performance test
report following the procedures specified in paragraph (b)(9) of this
section.
    (vii) If required to comply with Sec.  60.5395a(b)(1), the
information in paragraphs (b)(6)(vii)(A) through (C) of this section.
    (A) Dates of each inspection required under Sec.  60.5416a(c);
    (B) Each defect or leak identified during each inspection, and date
of repair or date of anticipated repair if repair is delayed; and
    (C) Date and time of each bypass alarm or each instance the key is
checked out if you are subject to the bypass requirements of Sec.
60.5416a(c)(3).
    (viii) You must identify each storage vessel affected facility that
is removed from service during the reporting period as specified in
Sec.  60.5395a(c)(1)(ii), including the date the storage vessel
affected facility was removed from service.
    (ix) You must identify each storage vessel affected facility
returned to service during the reporting period as specified in Sec.
60.5395a(c)(3), including the date the storage vessel affected facility
was returned to service.
    (7) For the collection of fugitive emissions components at each
well site and the collection of fugitive emissions components at each
compressor station, report the information specified in paragraphs
(b)(7)(i) through (iii) of this section, as applicable.
    (i)(A) Designation of the type of site (i.e., well site or
compressor station) at which the collection of fugitive emissions
components is located.
    (B) For each collection of fugitive emissions components at a well
site that became an affected facility during the reporting period, you
must include the date of the startup of production or the date of the
first day of production after modification. For each collection of
fugitive emissions components at a compressor station that became an
affected facility during the reporting period, you must include the
date of startup or the date of modification.
    (C) For each collection of fugitive emissions components at a well
site that meets the conditions specified in either Sec.
60.5397a(a)(1)(i) or (ii), you must specify the well site is a low
production well site and submit the total production for the well site.
    (D) For each collection of fugitive emissions components at a well
site where during the reporting period you complete the removal of all
major production and processing equipment such that the well site
contains only one or more wellheads, you must include the date of the
change to status as a wellhead only well site.
    (E) For each collection of fugitive emissions components at a well
site where you previously reported under paragraph (b)(7)(i)(C) of this
section the removal of all major production and processing equipment
and during the reporting period major production and processing
equipment is added back to the well site, the date that the first piece
of major production and processing equipment is added back to the well
site.
    (ii) For each fugitive emissions monitoring survey performed during
the annual reporting period, the information specified in paragraphs
(b)(7)(ii)(A) through (G) of this section.
    (A) Date of the survey.
    (B) Monitoring instrument used.
    (C) Any deviations from the monitoring plan elements under Sec.
60.5397a(c)(1), (2), and (7) and (c)(8)(i) or a statement that there
were no deviations from these elements of the monitoring plan.
    (D) Number and type of components for which fugitive emissions were
detected.
    (E) Number and type of fugitive emissions components that were not
repaired as required in Sec.  60.5397a(h).
    (F) Number and type of fugitive emission components (including
designation as difficult-to-monitor or unsafe-to-monitor, if
applicable) on delay of repair and explanation for each delay of
repair.
    (G) Date of planned shutdown(s) that occurred during the reporting
period if there are any components that have been placed on delay of
repair.
    (iii) For each collection of fugitive emissions components at a
well site or collection of fugitive emissions components at a
compressor station complying with an alternative fugitive emissions
standard under Sec.  60.5399a, in lieu of the information specified in
paragraphs (b)(7)(i) and (ii) of this section, you must provide the
information specified in paragraphs (b)(7)(iii)(A) through (C) of this
section.
    (A) The alternative standard with which you are complying.
    (B) The site-specific reports specified by the specific alternative
fugitive emissions standard, submitted in the format in which they were
submitted to the state, local, or tribal authority. If the report is in
hard copy, you must scan

the document and submit it as an electronic attachment to the annual
report required in paragraph (b) of this section.
    (C) If the report specified by the specific alternative fugitive
emissions standard is not site-specific, you must submit the
information specified in paragraphs (b)(7)(i) and (ii) of this section
for each individual site complying with the alternative standard.
    (8) For each pneumatic pump affected facility, the information
specified in paragraphs (b)(8)(i) through (iv) of this section.
    (i) For each pneumatic pump that is constructed, modified or
reconstructed during the reporting period, you must provide
certification that the pneumatic pump meets one of the conditions
described in paragraph (b)(8)(i)(A), (B), or (C) of this section.
    (A) No control device or process is available on site.
    (B) A control device or process is available on site and the owner
or operator has determined in accordance with Sec.  60.5393a(b)(5) that
it is technically infeasible to capture and route the emissions to the
control device or process.
    (C) Emissions from the pneumatic pump are routed to a control
device or process. If the control device is designed to achieve less
than 95 percent emissions reduction, specify the percent emissions
reductions the control device is designed to achieve.
    (ii) For any pneumatic pump affected facility which has been
previously reported as required under paragraph (b)(8)(i) of this
section and for which a change in the reported condition has occurred
during the reporting period, provide the identification of the
pneumatic pump affected facility and the date it was previously
reported and a certification that the pneumatic pump meets one of the
conditions described in paragraph (b)(8)(ii)(A), (B), (C), or (D) of
this section.
    (A) A control device has been added to the location and the
pneumatic pump now reports according to paragraph (b)(8)(i)(C) of this
section.
    (B) A control device has been added to the location and the
pneumatic pump affected facility now reports according to paragraph
(b)(8)(i)(B) of this section.
    (C) A control device or process has been removed from the location
or otherwise is no longer available and the pneumatic pump affected
facility now report according to paragraph (b)(8)(i)(A) of this
section.
    (D) A control device or process has been removed from the location
or is otherwise no longer available and the owner or operator has
determined in accordance with Sec.  60.5393a(b)(5) through an
engineering evaluation that it is technically infeasible to capture and
route the emissions to another control device or process.
    (iii) For each deviation that occurred during the reporting period
and recorded as specified in paragraph (c)(16)(ii) of this section, the
date and time the deviation began, duration of the deviation, and a
description of the deviation.
    (iv) If required to comply with Sec.  60.5393a(b), the information
in paragraphs (b)(8)(iv)(A) through (C) of this section.
    (A) Dates of each inspection required under Sec.  60.5416a(d);
    (B) Each defect or leak identified during each inspection, and date
of repair or date of anticipated repair if repair is delayed; and
    (C) Date and time of each bypass alarm or each instance the key is
checked out if you are subject to the bypass requirements of Sec.
60.5416a(c)(3).
    (9) Within 60 days after the date of completing each performance
test (see Sec.  60.8) required by this subpart, except testing
conducted by the manufacturer as specified in Sec.  60.5413a(d), you
must submit the results of the performance test following the procedure
specified in either paragraph (b)(9)(i) or (ii) of this section.
    (i) For data collected using test methods supported by the EPA's
Electronic Reporting Tool (ERT) as listed on the EPA's ERT website
(https://www.epa.gov/electronic-reporting-air-emissions/electronic-reporting-tool-ert) at the time of the test, you must submit the
results of the performance test to the EPA via the Compliance and
Emissions Data Reporting Interface (CEDRI), except as outlined in this
paragraph (b)(9)(i). (CEDRI can be accessed through the EPA's Central
Data Exchange (CDX) (https://cdx.epa.gov/).) The EPA will make all the
information submitted through CEDRI available to the public without
further notice to you. Do not use CEDRI to submit information you claim
as confidential business information (CBI). Anything submitted using
CEDRI cannot later be claimed CBI. Performance test data must be
submitted in a file format generated through the use of the EPA's ERT
or an alternate electronic file format consistent with the extensible
markup language (XML) schema listed on the EPA's ERT website. Although
we do not expect persons to assert a claim of CBI, if you wish to
assert a CBI claim, you must submit a complete file generated through
the use of the EPA's ERT or an alternate electronic file consistent
with the XML schema listed on the EPA's ERT website, including
information claimed to be CBI, on a compact disc, flash drive, or other
commonly used electronic storage media to the EPA. The electronic media
must be clearly marked as CBI and mailed to U.S. EPA/OAQPS/CORE CBI
Office, Attention: Group Leader, Measurement Policy Group, MD C404-02,
4930 Old Page Rd., Durham, NC 27703. The same ERT or alternate file
with the CBI omitted must be submitted to the EPA via the EPA's CDX as
described earlier in this paragraph (b)(9)(i). All CBI claims must be
asserted at the time of submission. Furthermore, under CAA section
114(c), emissions data is not entitled to confidential treatment, and
the EPA is required to make emissions data available to the public.
Thus, emissions data will not be protected as CBI and will be made
publicly available.
    (ii) For data collected using test methods that are not supported
by the EPA's ERT as listed on the EPA's ERT website at the time of the
test, you must submit the results of the performance test to the
Administrator at the appropriate address listed in Sec.  60.4.
    (10) For combustion control devices tested by the manufacturer in
accordance with Sec.  60.5413a(d), an electronic copy of the
performance test results required by Sec.  60.5413a(d) shall be
submitted via email to<EMAIL_ADDRESS>unless the test results
for that model of combustion control device are posted at the following
website: epa.gov/airquality/oilandgas/.
    (11) You must submit reports to the EPA via CEDRI, except as
outlined in this paragraph (b)(11). (CEDRI can be accessed through the
EPA's CDX (https://cdx.epa.gov/).) The EPA will make all the
information submitted through CEDRI available to the public without
further notice to you. Do not use CEDRI to submit information you claim
as CBI. Anything submitted using CEDRI cannot later be claimed CBI. You
must use the appropriate electronic report in CEDRI for this subpart or
an alternate electronic file format consistent with the extensible
markup language (XML) schema listed on the CEDRI website (https://www.epa.gov/electronic-reporting-air-emissions/cedri/). If the
reporting form specific to this subpart is not available in CEDRI at
the time that the report is due, you must submit the report to the
Administrator at the appropriate address listed in Sec.  60.4. Once the
form has been available in CEDRI for at least 90 calendar days, you
must begin submitting all subsequent reports via CEDRI. The reports
must be submitted by the

deadlines specified in this subpart, regardless of the method in which
the reports are submitted. Although we do not expect persons to assert
a claim of CBI, if you wish to assert a CBI claim, submit a complete
report generated using the appropriate form in CEDRI or an alternate
electronic file consistent with the XML schema listed on the EPA's
CEDRI website, including information claimed to be CBI, on a compact
disc, flash drive, or other commonly used electronic storage medium to
the EPA. The electronic medium shall be clearly marked as CBI and
mailed to U.S. EPA/OAQPS/CORE CBI Office, Attention: Group Leader,
Fuels and Incineration Group, MD C404-02, 4930 Old Page Rd., Durham, NC
27703. The same file with the CBI omitted shall be submitted to the EPA
via CEDRI. All CBI claims must be asserted at the time of submission.
Furthermore, under CAA section 114(c), emissions data is not entitled
to confidential treatment, and the EPA is required to make emissions
data available to the public. Thus, emissions data will not be
protected as CBI and will be made publicly available.
    (12) You must submit the certification signed by the qualified
professional engineer or in-house engineer according to Sec.
60.5411a(d) for each closed vent system routing to a control device or
process.
    (13) If you are required to electronically submit a report through
CEDRI in the EPA's CDX, you may assert a claim of EPA system outage for
failure to timely comply with the reporting requirement. To assert a
claim of EPA system outage, you must meet the requirements outlined in
paragraphs (b)(13)(i) through (vii) of this section.
    (i) You must have been or will be precluded from accessing CEDRI
and submitting a required report within the time prescribed due to an
outage of either the EPA's CEDRI or CDX systems.
    (ii) The outage must have occurred within the period of time
beginning 5 business days prior to the date that the submission is due.
    (iii) The outage may be planned or unplanned.
    (iv) You must submit notification to the Administrator in writing
as soon as possible following the date you first knew, or through due
diligence should have known, that the event may cause or caused a delay
in reporting.
    (v) You must provide to the Administrator a written description
identifying:
    (A) The date(s) and time(s) when CDX or CEDRI was accessed and the
system was unavailable;
    (B) A rationale for attributing the delay in reporting beyond the
regulatory deadline to the EPA system outage;
    (C) Measures taken or to be taken to minimize the delay in
reporting; and
    (D) The date by which you propose to report, or if you have already
met the reporting requirement at the time of the notification, the date
you reported.
    (vi) The decision to accept the claim of EPA system outage and
allow an extension to the reporting deadline is solely within the
discretion of the Administrator.
    (vii) In any circumstance, the report must be submitted
electronically as soon as possible after the outage is resolved.
    (14) If you are required to electronically submit a report through
CEDRI in the EPA's CDX, the owner or operator may assert a claim of
force majeure for failure to timely comply with the reporting
requirement. To assert a claim of force majeure, you must meet the
requirements outlined in paragraphs (b)(14)(i) through (v) of this
section.
    (i) You may submit a claim if a force majeure event is about to
occur, occurs, or has occurred or there are lingering effects from such
an event within the period of time beginning 5 business days prior to
the date the submission is due. For the purposes of this section, a
force majeure event is defined as an event that will be or has been
caused by circumstances beyond the control of the affected facility,
its contractors, or any entity controlled by the affected facility that
prevents you from complying with the requirement to submit a report
electronically within the time period prescribed. Examples of such
events are acts of nature (e.g., hurricanes, earthquakes, or floods),
acts of war or terrorism, or equipment failure or safety hazard beyond
the control of the affected facility (e.g., large scale power outage).
    (ii) You must submit notification to the Administrator in writing
as soon as possible following the date you first knew, or through due
diligence should have known, that the event may cause or caused a delay
in reporting.
    (iii) You must provide to the Administrator:
    (A) A written description of the force majeure event;
    (B) A rationale for attributing the delay in reporting beyond the
regulatory deadline to the force majeure event;
    (C) Measures taken or to be taken to minimize the delay in
reporting; and
    (D) The date by which you propose to report, or if you have already
met the reporting requirement at the time of the notification, the date
you reported.
    (iv) The decision to accept the claim of force majeure and allow an
extension to the reporting deadline is solely within the discretion of
the Administrator.
    (v) In any circumstance, the reporting must occur as soon as
possible after the force majeure event occurs.
    (c) Recordkeeping requirements. You must maintain the records
identified as specified in Sec.  60.7(f) and in paragraphs (c)(1)
through (18) of this section. All records required by this subpart must
be maintained either onsite or at the nearest local field office for at
least 5 years. Any records required to be maintained by this subpart
that are submitted electronically via the EPA's CDX may be maintained
in electronic format.
    (1) The records for each well affected facility as specified in
paragraphs (c)(1)(i) through (vii) of this section, as applicable. For
each well affected facility for which you make a claim that the well
affected facility is not subject to the requirements for well
completions pursuant to Sec.  60.5375a(g), you must maintain the record
in paragraph (c)(1)(vi) of this section, only. For each well affected
facility that routes flowback entirely through one or more production
separators that are designed to accommodate flowback, only records of
the United States Well Number, the latitude and longitude of the well
in decimal degrees to an accuracy and precision of five (5) decimals of
a degree using North American Datum of 1983, the Well Completion ID,
and the date and time of startup of production are required. For
periods where salable gas is unable to be separated, records of the
date and time of onset of flowback, the duration and disposition of
recovery, the duration of combustion and venting (if applicable),
reasons for venting (if applicable), and deviations are required.
    (i) Records identifying each well completion operation for each
well affected facility.
    (ii) Records of deviations in cases where well completion
operations with hydraulic fracturing were not performed in compliance
with the requirements specified in Sec.  60.5375a, including the date
and time the deviation began, the duration of the deviation, and a
description of the deviation.
    (iii) You must maintain the records specified in paragraphs
(c)(1)(iii)(A) through (C) of this section.
    (A) For each well affected facility required to comply with the
requirements of Sec.  60.5375a(a), you must record: The latitude and
longitude of the well in decimal degrees to an accuracy and precision
of five (5) decimals of a

degree using North American Datum of 1983; the United States Well
Number; the date and time of the onset of flowback following hydraulic
fracturing or refracturing; the date and time of each attempt to direct
flowback to a separator as required in Sec.  60.5375a(a)(1)(ii); the
date and time of each occurrence of returning to the initial flowback
stage under Sec.  60.5375a(a)(1)(i); and the date and time that the
well was shut in and the flowback equipment was permanently
disconnected, or the startup of production; the duration of flowback;
duration of recovery and disposition of recovery (i.e., routed to the
gas flow line or collection system, re-injected into the well or
another well, used as an onsite fuel source, or used for another useful
purpose that a purchased fuel or raw material would serve); duration of
combustion; duration of venting; and specific reasons for venting in
lieu of capture or combustion. The duration must be specified in hours.
In addition, for wells where it is technically infeasible to route the
recovered gas as specified in Sec.  60.5375a(a)(1)(ii), you must record
the reasons for the claim of technical infeasibility with respect to
all four options provided in Sec.  60.5375a(a)(1)(ii).
    (B) For each well affected facility required to comply with the
requirements of Sec.  60.5375a(f), you must record: Latitude and
longitude of the well in decimal degrees to an accuracy and precision
of five (5) decimals of a degree using North American Datum of 1983;
the United States Well Number; the date and time of the onset of
flowback following hydraulic fracturing or refracturing; the date and
time that the well was shut in and the flowback equipment was
permanently disconnected, or the startup of production; the duration of
flowback; duration of recovery and disposition of recovery (i.e.,
routed to the gas flow line or collection system, re-injected into the
well or another well, used as an onsite fuel source, or used for
another useful purpose that a purchased fuel or raw material would
serve); duration of combustion; duration of venting; and specific
reasons for venting in lieu of capture or combustion. The duration must
be specified in hours.
    (C) For each well affected facility for which you make a claim that
it meets the criteria of Sec.  60.5375a(a)(1)(iii)(A), you must
maintain the following:
    (1) The latitude and longitude of the well in decimal degrees to an
accuracy and precision of five (5) decimals of a degree using North
American Datum of 1983; the United States Well Number; the date and
time of the onset of flowback following hydraulic fracturing or
refracturing; the date and time that the well was shut in and the
flowback equipment was permanently disconnected, or the startup of
production; the duration of flowback; duration of recovery and
disposition of recovery (i.e., routed to the gas flow line or
collection system, re-injected into the well or another well, used as
an onsite fuel source, or used for another useful purpose that a
purchased fuel or raw material would serve); duration of combustion;
duration of venting; and specific reasons for venting in lieu of
capture or combustion. The duration must be specified in hours.
    (2) If applicable, records that the conditions of Sec.
60.5375a(a)(1)(iii)(A) are no longer met and that the well completion
operation has been stopped and a separator installed. The records shall
include the date and time the well completion operation was stopped and
the date and time the separator was installed.
    (3) A record of the claim signed by the certifying official that no
liquids collection is at the well site. The claim must include a
certification by a certifying official of truth, accuracy, and
completeness. This certification shall state that, based on information
and belief formed after reasonable inquiry, the statements and
information in the document are true, accurate, and complete.
    (iv) For each well affected facility for which you claim an
exception under Sec.  60.5375a(a)(3), you must record: The latitude and
longitude of the well in decimal degrees to an accuracy and precision
of five (5) decimals of a degree using North American Datum of 1983;
the United States Well Number; the specific exception claimed; the
starting date and ending date for the period the well operated under
the exception; and an explanation of why the well meets the claimed
exception.
    (v) For each well affected facility required to comply with both
Sec.  60.5375a(a)(1) and (3), if you are using a digital photograph in
lieu of the records required in paragraphs (c)(1)(i) through (iv) of
this section, you must retain the records of the digital photograph as
specified in Sec.  60.5410a(a)(4).
    (vi) For each well affected facility for which you make a claim
that the well affected facility is not subject to the well completion
standards according to Sec.  60.5375a(g), you must maintain:
    (A) A record of the analysis that was performed in order the make
that claim, including but not limited to, GOR values for established
leases and data from wells in the same basin and field;
    (B) the latitude and longitude of the well in decimal degrees to an
accuracy and precision of five (5) decimals of a degree using North
American Datum of 1983; the United States Well Number;
    (C) A record of the claim signed by the certifying official. The
claim must include a certification by a certifying official of truth,
accuracy, and completeness. This certification shall state that, based
on information and belief formed after reasonable inquiry, the
statements and information in the document are true, accurate, and
complete.
    (vii) For each well affected facility subject to Sec.  60.5375a(f),
a record of the well type (i.e., wildcat well, delineation well, or low
pressure well (as defined Sec.  60.5430a)) and supporting inputs and
calculations, if applicable.
    (2) For each centrifugal compressor affected facility, you must
maintain records of deviations in cases where the centrifugal
compressor was not operated in compliance with the requirements
specified in Sec.  60.5380a, including a description of each deviation,
the date and time each deviation began and the duration of each
deviation. Except as specified in paragraph (c)(2)(viii) of this
section, you must maintain the records in paragraphs (c)(2)(i) through
(vii) of this section for each control device tested under Sec.
60.5413a(d) which meets the criteria in Sec.  60.5413a(d)(11) and (e)
and used to comply with Sec.  60.5380a(a)(1) for each centrifugal
compressor.
    (i) Make, model, and serial number of purchased device.
    (ii) Date of purchase.
    (iii) Copy of purchase order.
    (iv) Location of the centrifugal compressor 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.
    (v) Inlet gas flow rate.
    (vi) Records of continuous compliance requirements in Sec.
60.5413a(e) as specified in paragraphs (c)(2)(vi)(A) through (E) of
this section.
    (A) Records that the pilot flame is present at all times of
operation.
    (B) Records that the device was operated with no visible emissions
except for periods not to exceed a total of 1 minute during any 15-
minute period.
    (C) Records of the maintenance and repair log.
    (D) Records of the visible emissions test following return to
operation from a maintenance or repair activity, including the date of
the visible emissions test, the length of the test, and

the amount of time for which visible emissions were present.
    (E) Records of the manufacturer's written operating instructions,
procedures, and maintenance schedule to ensure good air pollution
control practices for minimizing emissions.
    (vii) Records of deviations for instances where the inlet gas flow
rate exceeds the manufacturer's listed maximum gas flow rate, where
there is no indication of the presence of a pilot flame, or where
visible emissions exceeded 1 minute in any 15-minute period, including
a description of the deviation, the date and time the deviation began,
and the duration of the deviation.
    (viii) As an alternative to the requirements of paragraph
(c)(2)(iv) of this section, you may maintain records of one or more
digital photographs with the date the photograph was taken and the
latitude and longitude of the centrifugal compressor 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 centrifugal
compressor and control device with a photograph of a separately
operating GPS device within the same digital picture, provided the
latitude and longitude output of the GPS unit can be clearly read in
the digital photograph.
    (3) For each reciprocating compressor affected facility, you must
maintain the records in paragraphs (c)(3)(i) through (iii) of this
section.
    (i) Records of the cumulative number of hours of operation or
number of months since initial startup, since August 2, 2016, or since
the previous replacement of the reciprocating compressor rod packing,
whichever is latest. Alternatively, a statement that emissions from the
rod packing are being routed to a process through a closed vent system
under negative pressure.
    (ii) Records of the date and time of each reciprocating compressor
rod packing replacement, or date of installation of a rod packing
emissions collection system and closed vent system as specified in
Sec.  60.5385a(a)(3).
    (iii) Records of deviations in cases where the reciprocating
compressor was not operated in compliance with the requirements
specified in Sec.  60.5385a, including the date and time the deviation
began, duration of the deviation, and a description of the deviation.
    (4) For each pneumatic controller affected facility, you must
maintain the records identified in paragraphs (c)(4)(i) through (v) of
this section, as applicable.
    (i) Records of the month and year of installation, reconstruction,
or modification, location 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, identification
information that allows traceability to the records required in
paragraph (c)(4)(iii) or (iv) of this section and manufacturer
specifications for each pneumatic controller constructed, modified, or
reconstructed.
    (ii) Records of the demonstration that the use of pneumatic
controller affected facilities with a natural gas bleed rate greater
than the applicable standard are required and the reasons why.
    (iii) If the pneumatic controller is not located at a natural gas
processing plant, records of the manufacturer's specifications
indicating that the controller is designed such that natural gas bleed
rate is less than or equal to 6 standard cubic feet per hour.
    (iv) If the pneumatic controller is located at a natural gas
processing plant, records of the documentation that the natural gas
bleed rate is zero.
    (v) For each instance where the pneumatic controller was not
operated in compliance with the requirements specified in Sec.
60.5390a, a description of the deviation, the date and time the
deviation began, and the duration of the deviation.
    (5) For each storage vessel affected facility, you must maintain
the records identified in paragraphs (c)(5)(i) through (vii) of this
section.
    (i) If required to reduce emissions by complying with Sec.
60.5395a(a)(2), the records specified in Sec. Sec.  60.5420a(c)(6)
through (8) and 60.5416a(c)(6)(ii) and (c)(7)(ii). You must maintain
the records in paragraph (c)(5)(vi) of this section for each control
device tested under Sec.  60.5413a(d) which meets the criteria in Sec.
60.5413a(d)(11) and (e) and used to comply with Sec.  60.5395a(a)(2)
for each storage vessel.
    (ii) Records of each VOC emissions determination for each storage
vessel affected facility made under Sec.  60.5365a(e) including
identification of the model or calculation methodology used to
calculate the VOC emission rate.
    (iii) For each instance where the storage vessel was not operated
in compliance with the requirements specified in Sec. Sec.  60.5395a,
60.5411a, 60.5412a, and 60.5413a, as applicable, a description of the
deviation, the date and time each deviation began, and the duration of
the deviation.
    (iv) For storage vessels that are skid-mounted or permanently
attached to something that is mobile (such as trucks, railcars, barges
or ships), records indicating the number of consecutive days that the
vessel is located at a site in the crude oil and natural gas production
source category. If a storage vessel is removed from a site and, within
30 days, is either returned to the site or replaced by another storage
vessel at the site to serve the same or similar function, then the
entire period since the original storage vessel was first located at
the site, including the days when the storage vessel was removed, will
be added to the count towards the number of consecutive days.
    (v) You must maintain records of the identification and location 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 of each storage vessel affected facility.
    (vi) Except as specified in paragraph (c)(5)(vi)(G) of this
section, you must maintain the records specified in paragraphs
(c)(5)(vi)(A) through (H) of this section for each control device
tested under Sec.  60.5413a(d) which meets the criteria in Sec.
60.5413a(d)(11) and (e) and used to comply with Sec.  60.5395a(a)(2)
for each storage vessel.
    (A) Make, model, and serial number of purchased device.
    (B) Date of purchase.
    (C) Copy of purchase order.
    (D) Location of the 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 Sec.
60.5413a(e) as specified in paragraphs (c)(5)(vi)(F)(1) through (5) 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 1 minute during any 15-
minute period.
    (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, including the date of
the visible emissions test, the length of the test, and the amount of
time for which visible emissions were present.
    (5) Records of the manufacturer's written operating instructions,
procedures, and maintenance schedule to ensure good air pollution
control practices for minimizing emissions.

    (G) Records of deviations for instances where the inlet gas flow
rate exceeds the manufacturer's listed maximum gas flow rate, where
there is no indication of the presence of a pilot flame, or where
visible emissions exceeded 1 minute in any 15-minute period, including
a description of the deviation, the date and time the deviation began,
and the duration of the deviation.
    (H) As an alternative to the requirements of paragraph
(c)(5)(vi)(D) of this section, you may maintain records of one or more
digital photographs with the date the photograph was taken and the
latitude and longitude of the storage vessel 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 storage vessel
and control device with a photograph of a separately operating GPS
device within the same digital picture, provided the latitude and
longitude output of the GPS unit can be clearly read in the digital
photograph.
    (vii) Records of the date that each storage vessel affected
facility is removed from service and returned to service, as
applicable.
    (6) Records of each closed vent system inspection required under
Sec.  60.5416a(a)(1) and (2) and (b) for centrifugal compressors and
reciprocating compressors, Sec.  60.5416a(c)(1) for storage vessels, or
Sec.  60.5416a(e) for pneumatic pumps as required in paragraphs
(c)(6)(i) through (iii) of this section.
    (i) A record of each closed vent system inspection or no detectable
emissions monitoring survey. You must include an identification number
for each closed vent system (or other unique identification description
selected by you) and the date of the inspection.
    (ii) For each defect or leak detected during inspections required
by Sec.  60.5416a(a)(1) and (2), (b), (c)(1), or (d), you must record
the location of the defect or leak, a description of the defect or the
maximum concentration reading obtained if using Method 21 of appendix
A-7 of this part, the date of detection, and the date the repair to
correct the defect or leak is completed.
    (iii) If repair of the defect is delayed as described in Sec.
60.5416a(b)(10), you must record the reason for the delay and the date
you expect to complete the repair.
    (7) A record of each cover inspection required under Sec.
60.5416a(a)(3) for centrifugal or reciprocating compressors or Sec.
60.5416a(c)(2) for storage vessels as required in paragraphs (c)(7)(i)
through (iii) of this section.
    (i) A record of each cover inspection. You must include an
identification number for each cover (or other unique identification
description selected by you) and the date of the inspection.
    (ii) For each defect detected during inspections required by Sec.
60.5416a(a)(3) or (c)(2), you must record the location of the defect, a
description of the defect, the date of detection, the corrective action
taken the repair the defect, and the date the repair to correct the
defect is completed.
    (iii) If repair of the defect is delayed as described in Sec.
60.5416a(b)(10) or (c)(5), you must record the reason for the delay and
the date you expect to complete the repair.
    (8) If you are subject to the bypass requirements of Sec.
60.5416a(a)(4) for centrifugal compressors or reciprocating
compressors, or Sec.  60.5416a(c)(3) for storage vessels or pneumatic
pumps, you must prepare and maintain a record of each inspection or a
record of each time the key is checked out or a record of each time the
alarm is sounded.
    (9) [Reserved]
    (10) For each centrifugal compressor or pneumatic pump affected
facility, records of the schedule for carbon replacement (as determined
by the design analysis requirements of Sec.  60.5413a(c)(2) or (3)) and
records of each carbon replacement as specified in Sec.
60.5412a(c)(1).
    (11) For each centrifugal compressor affected facility subject to
the control device requirements of Sec.  60.5412a(a), (b), and (c),
records of minimum and maximum operating parameter values, continuous
parameter monitoring system data, calculated averages of continuous
parameter monitoring system data, results of all compliance
calculations, and results of all inspections.
    (12) For each carbon adsorber installed on storage vessel affected
facilities, records of the schedule for carbon replacement (as
determined by the design analysis requirements of Sec.  60.5412a(d)(2))
and records of each carbon replacement as specified in Sec.
60.5412a(c)(1).
    (13) For each storage vessel affected facility subject to the
control device requirements of Sec.  60.5412a(c) and (d), you must
maintain records of the inspections, including any corrective actions
taken, the manufacturers' operating instructions, procedures and
maintenance schedule as specified in Sec.  60.5417a(h)(3). You must
maintain records of EPA Method 22 of appendix A-7 of this part, section
11 results, which include: Company, location, company representative
(name of the person performing the observation), sky conditions,
process unit (type of control device), clock start time, observation
period duration (in minutes and seconds), accumulated emission time (in
minutes and seconds), and clock end time. You may create your own form
including the above information or use Figure 22-1 in EPA Method 22 of
appendix A-7 of this part. Manufacturer's operating instructions,
procedures and maintenance schedule must be available for inspection.
    (14) A log of records as specified in Sec.  60.5412a(d)(1)(iii),
for all inspection, repair, and maintenance activities for each control
device failing the visible emissions test.
    (15) For each collection of fugitive emissions components at a well
site and each collection of fugitive emissions components at a
compressor station, maintain the records identified in paragraphs
(c)(15)(i) through (viii) of this section.
    (i) The date of the startup of production or the date of the first
day of production after modification for each collection of fugitive
emissions components at a well site and the date of startup or the date
of modification for each collection of fugitive emissions components at
a compressor station.
    (ii) For each collection of fugitive emissions components at a well
site complying with Sec.  60.5397a(a)(2), you must maintain records of
the daily production and calculations demonstrating that the rolling
12-month average is at or below 15 boe per day no later than 12 months
before complying with Sec.  60.5397a(a)(2).
    (iii) For each collection of fugitive emissions components at a
well site complying with Sec.  60.5397a(a)(3)(i), you must keep records
of daily production and calculations for the first 30 days after
completion of any action listed in Sec.  60.5397a(a)(2)(i) through (v)
demonstrating that total production from the well site is at or below
15 boe per day, or maintain records demonstrating the rolling 12-month
average total production for the well site is at or below 15 boe per
day.
    (iv) For each collection of fugitive emissions components at a well
site complying with Sec.  60.5397a(a)(3)(ii), you must keep the records
specified in paragraphs (c)(15)(i), (vi), and (vii) of this section.
    (v) For each collection of fugitive emissions components at a well
site where you complete the removal of all major production and
processing equipment such that the well site contains only one or more
wellheads, record the date the well site completes

the removal of all major production and processing equipment from the
well site, and, if the well site is still producing, record the well ID
or separate tank battery ID receiving the production from the well
site. If major production and processing equipment is subsequently
added back to the well site, record the date that the first piece of
major production and processing equipment is added back to the well
site.
    (vi) The fugitive emissions monitoring plan as required in Sec.
60.5397a(b), (c), and (d).
    (vii) The records of each monitoring survey as specified in
paragraphs (c)(15)(vii)(A) through (I) of this section.
    (A) Date of the survey.
    (B) Beginning and end time of the survey.
    (C) Name of operator(s), training, and experience of the
operator(s) performing the survey.
    (D) Monitoring instrument used.
    (E) Fugitive emissions component identification when Method 21 of
appendix A-7 of this part is used to perform the monitoring survey.
    (F) Ambient temperature, sky conditions, and maximum wind speed at
the time of the survey. For compressor stations, operating mode of each
compressor (i.e., operating, standby pressurized, and not operating-
depressurized modes) at the station at the time of the survey.
    (G) Any deviations from the monitoring plan or a statement that
there were no deviations from the monitoring plan.
    (H) Records of calibrations for the instrument used during the
monitoring survey.
    (I) Documentation of each fugitive emission detected during the
monitoring survey, including the information specified in paragraphs
(c)(15)(vii)(I)(1) through (8) of this section.
    (1) Location of each fugitive emission identified.
    (2) Type of fugitive emissions component, including designation as
difficult-to-monitor or unsafe-to-monitor, if applicable.
    (3) If Method 21 of appendix A-7 of this part is used for
detection, record the component ID and instrument reading.
    (4) For each repair that cannot be made during the monitoring
survey when the fugitive emissions are initially found, a digital
photograph or video must be taken of that component or the component
must be tagged for identification purposes. The digital photograph must
include the date that the photograph was taken and must clearly
identify the component by location within the site (e.g., the latitude
and longitude of the component or by other descriptive landmarks
visible in the picture). The digital photograph or identification
(e.g., tag) may be removed after the repair is completed, including
verification of repair with the resurvey.
    (5) The date of first attempt at repair of the fugitive emissions
component(s).
    (6) The date of successful repair of the fugitive emissions
component, including the resurvey to verify repair and instrument used
for the resurvey.
    (7) Identification of each fugitive emission component placed on
delay of repair and explanation for each delay of repair
    (8) Date of planned shutdowns that occur while there are any
components that have been placed on delay of repair.
    (viii) For each collection of fugitive emissions components at a
well site or collection of fugitive emissions components at a
compressor station complying with an alternative means of emissions
limitation under Sec.  60.5399a, you must maintain the records
specified by the specific alternative fugitive emissions standard for a
period of at least 5 years.
    (16) For each pneumatic pump affected facility, you must maintain
the records identified in paragraphs (c)(16)(i) through (v) of this
section.
    (i) Records of the date, location, and manufacturer specifications
for each pneumatic pump constructed, modified, or reconstructed.
    (ii) Records of deviations in cases where the pneumatic pump was
not operated in compliance with the requirements specified in Sec.
60.5393a, including the date and time the deviation began, duration of
the deviation, and a description of the deviation.
    (iii) Records on the control device used for control of emissions
from a pneumatic pump including the installation date, and
manufacturer's specifications. If the control device is designed to
achieve less than 95-percent emission reduction, maintain records of
the design evaluation or manufacturer's specifications which indicate
the percentage reduction the control device is designed to achieve.
    (iv) Records substantiating a claim according to Sec.
60.5393a(b)(5) that it is technically infeasible to capture and route
emissions from a pneumatic pump to a control device or process;
including the certification according to Sec.  60.5393a(b)(5)(ii) and
the records of the engineering assessment of technical infeasibility
performed according to Sec.  60.5393a(b)(5)(iii).
    (v) You must retain copies of all certifications, engineering
assessments, and related records for a period of five years and make
them available if directed by the implementing agency.
    (17) For each closed vent system routing to a control device or
process, the records of the assessment conducted according to Sec.
60.5411a(d):
    (i) A copy of the assessment conducted according to Sec.
60.5411a(d)(1);
    (ii) A copy of the certification according to Sec.
60.5411a(d)(1)(i); and
    (iii) The owner or operator shall retain copies of all
certifications, assessments, and any related records for a period of 5
years, and make them available if directed by the delegated authority.
    (18) A copy of each performance test submitted under paragraph
(b)(9) of this section.

0
24. Section 60.5422a is amended by revising paragraphs (a), (b), and
(c) introductory text to read as follows:

Sec.  60.5422a   What are my additional reporting requirements for my
affected facility subject to VOC requirements for onshore natural gas
processing plants?

    (a) You must comply with the requirements of paragraphs (b) and (c)
of this section in addition to the requirements of Sec.  60.487a(a),
(b)(1) through (3) and (5), and (c)(2)(i) through (iv) and (vii)
through (viii). You must submit semiannual reports to the EPA via the
Compliance and Emissions Data Reporting Interface (CEDRI). (CEDRI can
be accessed through the EPA's Central Data Exchange (CDX) (https://cdx.epa.gov/).) Use the appropriate electronic report in CEDRI for this
subpart or an alternate electronic file format consistent with the
extensible markup language (XML) schema listed on the CEDRI website
(https://www3.epa.gov/ttn/chief/cedri/). If the reporting form specific
to this subpart is not available in CEDRI at the time that the report
is due, submit the report to the Administrator at the appropriate
address listed in Sec.  60.4. Once the form has been available in CEDRI
for at least 90 days, you must begin submitting all subsequent reports
via CEDRI. The report must be submitted by the deadline specified in
this subpart, regardless of the method in which the report is
submitted.
    (b) An owner or operator must include the following information in
the initial semiannual report in addition to the information required
in Sec.  60.487a(b)(1) through (3) and (5): Number of pressure relief
devices subject to the requirements of Sec.  60.5401a(b) except for
those pressure relief devices designated for no detectable emissions
under the provisions of Sec.  60.482-4a(a) and those

pressure relief devices complying with Sec.  60.482-4a(c).
    (c) An owner or operator must include the information specified in
paragraphs (c)(1) and (2) of this section in all semiannual reports in
addition to the information required in Sec.  60.487a(c)(2)(i) through
(iv) and (vii) through (viii):
* * * * *

0
25. Section 60.5423a is amended by revising the section heading and
paragraph (b) introductory text and adding paragraph (b)(3) to read as
follows:

Sec.  60.5423a   What additional recordkeeping and reporting
requirements apply to my sweetening unit affected facilities?

* * * * *
    (b) You must submit a report of excess emissions to the
Administrator in your annual report if you had excess emissions during
the reporting period. The procedures for submitting annual reports are
located in Sec.  60.5420a(b). For the purpose of these reports, excess
emissions are defined as specified in paragraphs (b)(1) and (2) of this
section. The report must contain the information specified in paragraph
(b)(3) of this section.
* * * * *
    (3) For each period of excess emissions during the reporting
period, include the following information in your report:
    (i) The date and time of commencement and completion of each period
of excess emissions;
    (ii) The required minimum efficiency (Z) and the actual average
sulfur emissions reduction (R) for periods defined in paragraph (b)(1)
of this section; and
    (iii) The appropriate operating temperature and the actual average
temperature of the gases leaving the combustion zone for periods
defined in paragraph (b)(2) of this section.
* * * * *

0
26. Section 60.5430a is amended by:
0
a. Revising the definitions for ``Capital expenditure'' and
``Certifying official'';
0
b. Adding in alphabetical order the definitions for ``Coil tubing
cleanout,'' ``Custody meter,'' ``Custody meter assembly,'' and ``First
attempt at repair'';
0
c. Revising the definitions for ``Flowback'' and ``Fugitive emissions
component'';
0
d. Removing the definitions for ``Gas processing plant process unit''
and ``Greenfield site'';
0
e. Revising the definition of ``Low pressure well'';
0
f. Adding in alphabetical order the definition for ``Major production
and processing equipment'';
0
g. Revising the definition for ``Maximum average daily throughput'';
0
h. Adding in alphabetical order the definitions for ``Plug drill-out,''
``Repaired,'' and ``Screenout'';
0
i. Revising the definition for ``Startup of production'';
0
j. Adding in alphabetical order the definitions for ``UIC Class I
oilfield disposal well'' and ``UIC Class II oilfield disposal well'';
0
k. Revising the definition for ``Well site''; and
0
l. Adding in alphabetical order the definition for ``Wellhead only well
site''.
    The revisions and additions read as follows:

Sec.  60.5430a   What definitions apply to this subpart?

* * * * *
    Capital expenditure means, in addition to the definition in 40 CFR
60.2, an expenditure for a physical or operational change to an
existing facility that:
    (1) Exceeds P, the product of the facility's replacement cost, R,
and an adjusted annual asset guideline repair allowance, A, as
reflected by the following equation: P = R x A, where:
    (i) The adjusted annual asset guideline repair allowance, A, is the
product of the percent of the replacement cost, Y, and the applicable
basic annual asset guideline repair allowance, B, divided by 100 as
reflected by the following equation: A = Y x (B / 100);
    (ii) The percent Y is determined from the following equation: Y =
(CPI of date of construction/most recently available CPI of date of
project), where the ``CPI-U, U.S. city average, all items'' must be
used for each CPI value; and
    (iii) The applicable basic annual asset guideline repair allowance,
B, is 4.5.
* * * * *
    Certifying official means one of the following:
    (1) For a corporation: A president, secretary, treasurer, or vice-
president of the corporation in charge of a principal business
function, or any other person who performs similar policy or decision-
making functions for the corporation, or a duly authorized
representative of such person if the representative is responsible for
the overall operation of one or more manufacturing, production, or
operating facilities with an affected facility subject to this subpart
and either:
    (i) The facilities employ more than 250 persons or have gross
annual sales or expenditures exceeding $25 million (in second quarter
1980 dollars); or
    (ii) The Administrator is notified of such delegation of authority
prior to the exercise of that authority. The Administrator reserves the
right to evaluate such delegation;
    (2) For a partnership (including but not limited to general
partnerships, limited partnerships, and limited liability partnerships)
or sole proprietorship: A general partner or the proprietor,
respectively. If a general partner is a corporation, the provisions of
paragraph (1) of this definition apply;
    (3) For a municipality, State, Federal, or other public agency:
Either a principal executive officer or ranking elected official. For
the purposes of this part, a principal executive officer of a Federal
agency includes the chief executive officer having responsibility for
the overall operations of a principal geographic unit of the agency
(e.g., a Regional Administrator of EPA); or
    (4) For affected facilities:
    (i) The designated representative in so far as actions, standards,
requirements, or prohibitions under title IV of the CAA or the
regulations promulgated thereunder are concerned; or
    (ii) The designated representative for any other purposes under
this part.
    Coil tubing cleanout means the process where an operator runs a
string of coil tubing to the packed proppant within a well and jets the
well to dislodge the proppant and provide sufficient lift energy to
flow it to the surface. Coil tubing cleanout includes mechanical
methods to remove solids and/or debris from a wellbore.
* * * * *
    Custody meter means the meter where natural gas or hydrocarbon
liquids are measured for sales, transfers, and/or royalty
determination.
    Custody meter assembly means an assembly of fugitive emissions
components, including the custody meter, valves, flanges, and
connectors necessary for the proper operation of the custody meter.
* * * * *
    First attempt at repair means, for the purposes of fugitive
emissions components, an action taken for the purpose of stopping or
reducing fugitive emissions to the atmosphere. First attempts at repair
include, but are not limited to, the following practices where
practicable and appropriate: Tightening bonnet bolts; replacing bonnet
bolts; tightening packing gland nuts; or injecting lubricant into
lubricated packing.
* * * * *
    Flowback means the process of allowing fluids and entrained solids
to flow from a well following a treatment,

either in preparation for a subsequent phase of treatment or in
preparation for cleanup and returning the well to production. The term
flowback also means the fluids and entrained solids that emerge from a
well during the flowback process. The flowback period begins when
material introduced into the well during the treatment returns to the
surface following hydraulic fracturing or refracturing. The flowback
period ends when either the well is shut in and permanently
disconnected from the flowback equipment or at the startup of
production. The flowback period includes the initial flowback stage and
the separation flowback stage. Screenouts, coil tubing cleanouts, and
plug drill-outs are not considered part of the flowback process.
    Fugitive emissions component means any component that has the
potential to emit fugitive emissions of VOC at a well site or
compressor station, including valves, connectors, pressure relief
devices, open-ended lines, flanges, covers and closed vent systems not
subject to Sec.  60.5411 or Sec.  60.5411a, thief hatches or other
openings on a controlled storage vessel not subject to Sec.  60.5395 or
Sec.  60.5395a, compressors, 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 natural gas discharged from the device's
vent is not considered a fugitive emission. Emissions originating from
other than the device's vent, such as the thief hatch on a controlled
storage vessel, would be considered fugitive emissions.
* * * * *
    Low pressure well means a well that satisfies at least one of the
following conditions:
    (1) The static pressure at the wellhead following fracturing but
prior to the onset of flowback is less than the flow line pressure;
    (2) The pressure of flowback fluid immediately before it enters the
flow line, as determined under Sec.  60.5432a, is less than the flow
line pressure; or
    (3) Flowback of the fracture fluids will not occur without the use
of artificial lift equipment.
    Major production and processing equipment means reciprocating or
centrifugal compressors, glycol dehydrators, heater/treaters,
separators, and storage vessels collecting crude oil, condensate,
intermediate hydrocarbon liquids, or produced water, for the purpose of
determining whether a well site is a wellhead only well site.
    Maximum average daily throughput means the following:
    (1) For storage vessels that commenced construction,
reconstruction, or modification after September 18, 2015, and on and
before November 16, 2020, maximum average daily throughput means the
earliest calculation of daily average throughput during the 30-day PTE
evaluation period employing generally accepted methods.
    (2) For storage vessels that commenced construction,
reconstruction, or modification after November 16, 2020, maximum
average daily throughput means the earliest calculation of daily
average throughput, determined as described in paragraph (3) or (4) of
this definition, to an individual storage vessel over the days that
production is routed to that storage vessel during the 30-day PTE
evaluation period employing generally accepted methods specified in
Sec.  60.5365a(e)(1).
    (3) If throughput to the individual storage vessel is measured on a
daily basis (e.g., via level gauge automation or daily manual gauging),
the maximum average daily throughput is the average of all daily
throughputs for days on which throughput was routed to that storage
vessel during the 30-day evaluation period; or
    (4) If throughput to the individual storage vessel is not measured
on a daily basis (e.g., via manual gauging at the start and end of
loadouts), the maximum average daily throughput is the highest, of the
average daily throughputs, determined for any production period to that
storage vessel during the 30-day evaluation period, as determined by
averaging total throughput to that storage vessel over each production
period. A production period begins when production begins to be routed
to a storage vessel and ends either when throughput is routed away from
that storage vessel or when a loadout occurs from that storage vessel,
whichever happens first. Regardless of the determination methodology,
operators must not include days during which throughput is not routed
to an individual storage vessel when calculating maximum average daily
throughput for that storage vessel.
* * * * *
    Plug drill-out means the removal of a plug (or plugs) that was used
to isolate different sections of the well.
* * * * *
    Repaired means, for the purposes of fugitive emissions components,
that fugitive emissions components are adjusted, replaced, or otherwise
altered, in order to eliminate fugitive emissions as defined in Sec.
60.5397a and resurveyed as specified in Sec.  60.5397a(h)(4) and it is
verified that emissions from the fugitive emissions components are
below the applicable fugitive emissions definition.
* * * * *
    Screenout means an attempt to clear proppant from the wellbore to
dislodge the proppant out of the well.
* * * * *
    Startup of production means the beginning of initial flow following
the end of flowback when there is continuous recovery of salable
quality gas and separation and recovery of any crude oil, condensate,
or produced water, except as otherwise provided in this definition. For
the purposes of the fugitive monitoring requirements of Sec.  60.5397a,
startup of production means the beginning of the continuous recovery of
salable quality gas and separation and recovery of any crude oil,
condensate, or produced water.
* * * * *
    UIC Class I oilfield disposal well means a well with a UIC Class I
permit that meets the definition in 40 CFR 144.6(a)(2) and receives
eligible fluids from oil and natural gas exploration and production
operations.
    UIC Class II oilfield disposal well means a well with a UIC Class
II permit where wastewater resulting from oil and natural gas
production operations is injected into underground porous rock
formations not productive of oil or gas, and sealed above and below by
unbroken, impermeable strata.
* * * * *
    Well site means one or more surface sites that are constructed for
the drilling and subsequent operation of any oil well, natural gas
well, or injection well. For purposes of the fugitive emissions
standards at Sec.  60.5397a, well site also means a separate tank
battery surface site collecting crude oil, condensate, intermediate
hydrocarbon liquids, or produced water from wells not located at the
well site (e.g., centralized tank batteries). Also, for the purposes of
the fugitive emissions standards at Sec.  60.5397a, a well site does
not include:
    (1) UIC Class II oilfield disposal wells and disposal facilities;
    (2) UIC Class I oilfield disposal wells; and
    (3) The flange immediately upstream of the custody meter assembly
and equipment, including fugitive emissions components, located
downstream of this flange.
* * * * *
    Wellhead only well site means, for the purposes of the fugitive
emissions standards at Sec.  60.5397a, a well site that contains one or
more wellheads and no

major production and processing equipment.
* * * * *

0
27. Table 3 to subpart OOOOa of part 60 is amended by revising the
entries for Sec. Sec.  60.8 and 60.15 to read as follows:

            Table 3 to Subpart OOOOa of Part 60--Applicability of General Provisions to Subpart OOOOa
----------------------------------------------------------------------------------------------------------------
    General provisions
         citation                 Subject of citation           Applies to subpart?           Explanation
----------------------------------------------------------------------------------------------------------------

                                                  * * * * * * *
Sec.   60.8..............  Performance tests................  Yes....................  Except that the format of
                                                                                performance test reports
                                                                                is described in Sec.
                                                                                60.5420a(b). Performance
                                                                                testing is required for
                                                                                control devices used on
                                                                                storage vessels,
                                                                                centrifugal compressors,
                                                                                and pneumatic pumps,
                                                                                except that performance
                                                                                testing is not required
                                                                                for a control device
                                                                                used solely on pneumatic
                                                                                pump(s).

                                                  * * * * * * *
Sec.   60.15.............  Reconstruction...................  Yes....................  Except that Sec.
                                                                                60.15(d) does not apply
                                                                                to wells, pneumatic
                                                                                controllers, pneumatic
                                                                                pumps, centrifugal
                                                                                compressors,
                                                                                reciprocating
                                                                                compressors, storage
                                                                                vessels, or the
                                                                                collection of fugitive
                                                                                emissions components at
                                                                                a well site or the
                                                                                collection of fugitive
                                                                                emissions components at
                                                                                a compressor station.

                                                  * * * * * * *
----------------------------------------------------------------------------------------------------------------

[FR Doc. 2020-18115 Filed 9-10-20; 8:45 am]
BILLING CODE 6560-50-P


[Federal Register: March 20, 2008 (Volume 73, Number 55)]
[CORRECTIONS]
[Page 15049]
[DOCID:fr20mr08-90]

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

DEPARTMENT OF TRANSPORTATION

Federal Aviation Administration

14 CFR Part 71

[Docket No. FAA-2008-0059; Airspace Docket No. 08-ANE-90]

Establishment of Class E Airspace; Fort Kent, ME

Correction

    In rule document 08-734 beginning on page 9451 in the issue of
Thursday, February 21, 2008, make the following correction:
    On page 9452, in the first column, under ``Rule'' heading, in the
seventh line, ``011'' should read ``001''.
[FR Doc. Z8-734 Filed 3-19-08; 8:45 am]

BILLING CODE 1505-01-D