[Federal Register Volume 86, Number 127 (Wednesday, July 7, 2021)]
[Notices]
[Page 35779]
[FR Doc No: 2021-14467]

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DEPARTMENT OF ENERGY

Federal Energy Regulatory Commission

Combined Notice of Filings

    Take notice that the Commission has received the following Natural
Gas Pipeline Rate and Refund Report filings:

    Docket Number: PR21-52-000.
    Applicants: Washington 10 Storage Corporation.
    Description: Tariff filing per 284.123(e)+(g)/: Notice of
Cancellation of Statement of Operating Conditions to be effective 8/1/
2021.
    Filed Date: 6/25/2021.
    Accession Number:<PHONE_NUMBER>93.
    Comments Due: 5 p.m. ET 7/16/2021.
    284.123(g) Protests Due: 5 p.m. ET 7/30/2021.

    Docket Number: PR21-53-000.
    Applicants: Moss Bluff Hub, LLC.
    Description: Tariff filing per 284.123(b),(e)/: Updates to Tariff
Contact Person to be effective 7/29/2021.
    Filed Date: 6/29/2021.
    Accession Number:<PHONE_NUMBER>56.
    Comments/Protests Due: 5 p.m. ET 7/20/2021.

    Docket Numbers: RP21-917-000.
    Applicants: Steckman Ridge, LP.
    Description: Sec.  4(d) Rate Filing: Steckman Ridge Updates to
Tariff Contact Person to be effective 7/29/2021.
    Filed Date: 6/29/21.
    Accession Number: 20210629-5065.
    Comments Due: 5 p.m. ET 7/12/21.

    Docket Numbers: RP21-918-000.
    Applicants: Big Sandy Pipeline, LLC.
    Description: Sec.  4(d) Rate Filing: Big Sandy EPC 2021 to be
effective 8/1/2021.
    Filed Date: 6/29/21.
    Accession Number: 20210629-5164.
    Comments Due: 5 p.m. ET 7/12/21.

    The filings are accessible in the Commission's eLibrary system
(https://elibrary.ferc.gov/idmws/search/fercgensearch.asp) by querying
the docket number.
    Any person desiring to intervene or protest in any of the above
proceedings must file in accordance with Rules 211 and 214 of the
Commission's Regulations (18 CFR 385.211 and 385.214) on or before 5:00
p.m. Eastern time on the specified comment date. Protests may be
considered, but intervention is necessary to become a party to the
proceeding.
    eFiling is encouraged. More detailed information relating to filing
requirements, interventions, protests, service, and qualifying
facilities filings can be found at: http://www.ferc.gov/docs-filing/efiling/filing-req.pdf. For other information, call<PHONE_NUMBER>
(toll free). For TTY, call<PHONE_NUMBER>.

    Dated: June 30, 2021.
Debbie-Anne A. Reese,
Deputy Secretary.
[FR Doc. 2021-14467 Filed 7-6-21; 8:45 am]
BILLING CODE 6717-01-P


Decrease in Insulating gas j Inventory = (pounds of insulating gas j
stored in containers, but not in energized equipment, at the
beginning of the year) - (pounds of insulating gas j stored in
containers, but not in energized equipment, at the end of the year).
Acquisitions of Insulating gas j = (pounds of each insulating gas j
purchased from chemical producers or distributors in bulk) + (pounds
of each insulating gas j purchased from equipment manufacturers or
distributors with or inside equipment, including hermetically
sealed-pressure switchgear) + (pounds of each insulating gas j
returned to facility after off-site recycling).
Disbursements of Insulating gas j = (pounds of each insulating gas j
in bulk and contained in equipment that is sold to other entities) +
(pounds of each insulating gas j returned to suppliers) + (pounds of
each insulating gas j sent off site for recycling) + (pounds of each
insulating gas j sent off-site for destruction).
Net Increase in Total Nameplate Capacity of Equipment Operated
containing insulating gas j = (The Nameplate Capacity of new
equipment containing insulating gas j in pounds, including
hermetically sealed-pressure switchgear) - (Nameplate Capacity of
retiring equipment containing insulating gas j in pounds, including
hermetically sealed-pressure switchgear). (Note that

Nameplate Capacity refers to the full and proper charge of equipment
rather than to the actual charge, which may reflect leakage).

    (b) Nameplate Capacity Adjustments. Users of closed-pressure
electrical equipment with a voltage capacity greater than 38 kV may
measure and adjust the nameplate capacity value specified by the
equipment manufacturer on the nameplate attached to that equipment, or
within the equipment manufacturer's official product specifications, by
following the requirements in paragraphs (b)(1) through (b)(10) of this
section. Users of other electrical equipment are not permitted to
adjust the nameplate capacity value of the other equipment.
    (1) If you elect to measure the nameplate capacity value(s) of one
or more pieces of electrical equipment with a voltage capacity greater
than 38 kV, you must measure the nameplate capacity values of all the
electrical equipment in your facility that has a voltage capacity
greater than 38 kV and that is installed or retired in that reporting
year and in subsequent reporting years.
    (2) You must adopt the measured nameplate capacity value for any
piece of equipment for which the absolute value of the difference
between the measured nameplate capacity value and the nameplate
capacity value most recently specified by the manufacturer equals or
exceeds two percent of the nameplate capacity value most recently
specified by the manufacturer.
    (3) You may adopt the measured nameplate capacity value for
equipment for which the absolute value of the difference between the
measured nameplate capacity value and the nameplate capacity value most
recently specified by the manufacturer is less than two percent of the
nameplate capacity value most recently specified by the manufacturer,
but if you elect to adopt the measured nameplate capacity for that
equipment, then you must adopt the measured nameplate capacity value
for all of the equipment for which the difference between the measured
nameplate capacity value and the nameplate capacity value most recently
specified by the manufacturer is less than two percent of the nameplate
capacity value most recently specified by the manufacturer. This
applies in the reporting year in which you first adopt the measured
nameplate capacity for the equipment and in subsequent reporting years.
    (4) Users of electrical equipment measuring the nameplate capacity
of any new electrical equipment must:
    (i) Record the amount of insulating gas in the equipment at the
time the equipment was acquired (pounds), either per information
provided by the manufacturer, or by transferring insulating gas from
the equipment to a gas container and measuring the amount of insulating
gas transferred. The equipment user is responsible for ensuring the gas
is accounted for consistent with the methodologies specified in
paragraphs (b)(4)(ii) through (b)(5) of this section. If no insulating
gas was in the device when it was acquired, record this value as zero.
    (ii) If insulating gas is added to the equipment subsequent to the
acquisition of the equipment to energize it the first time, transfer
the insulating gas to the equipment to reach the temperature-
compensated design operating pressure per manufacturer specifications
and measure and calculate the total amount of covered insulating gas
added to the device using one of the methods specified in paragraphs
(b)(4)(ii)(A) and (B) of this section.
    (A) To determine the amount of covered insulating gas transferred
to the electrical equipment, weigh the gas container being used to fill
the device prior to, and after, the addition of the covered insulating
gas to the electrical equipment, and subtract the second value (after-
transfer gas container weight) from the first value (prior-to-transfer
gas container weight). Account for any gas contained in hoses before
and after the transfer.
    (B) Connect a mass flow meter between the electrical equipment and
a gas cart. Transfer gas to the equipment to reach the temperature-
compensated design operating pressure per manufacturer specifications.
Close the connection to the GIE from the mass flow meter hose and
ensure that the gas trapped in the filling hose returns through the
mass flow meter. Calculate the amount of gas transferred from the mass
reading on the mass flow meter.
    (iii) Sum the results of paragraphs (b)(4)(i) and (ii) to obtain
the measured nameplate capacity for the new equipment.
    (5) Electrical equipment users measuring the nameplate capacity of
any retiring electrical equipment must:
    (i) Record the initial system pressure and vessel temperature prior
to removing any insulating gas.
    (ii) Convert the initial system pressure to a temperature-
compensated initial system pressure by using the temperature/pressure
curve for that insulating gas.
    (iii) If the temperature-compensated initial system pressure of the
electrical equipment does not match the temperature-compensated design
operating pressure specified by the equipment manufacturer, you may
either:
    (A) Add or remove insulating gas to/from the electrical equipment
until the manufacturer-specified value is reached, or
    (B) If the temperature-compensated initial system pressure of the
electrical equipment is no less than 90 percent of the temperature-
compensated design operating pressure specified by the manufacturer (in
absolute terms), use Equation DD-4 to calculate the nameplate capacity
based on the mass recorded under paragraph (b)(5)(vi) of this section.
    (iv) Follow one of the following processes, depending on the
methodology being used to measure the amount of gas recovered:
    (A) Connect a mass flow meter between the electrical equipment and
a gas cart; or
    (B) Weigh the gas container being used to receive the gas and
record this value.
    (v) Recover insulating gas from the electrical equipment until five
minutes after the pressure in the electrical equipment reaches the
blank-off pressure unless the integrity of the electrical equipment has
been compromised in such a way that air will be drawn into the
electrical equipment and gas cart if the electrical equipment is drawn
into a vacuum. If the integrity of the electrical equipment has been so
compromised, recover the insulating gas until the pressure in the
electrical equipment is no higher than zero pounds per square inch
gauge (0 psig).
    (vi) Record the amount of insulating gas recovered (pounds), either
based on the reading from the mass flow meter, or by weighing the gas
container that received the gas and subtracting the weight recorded
pursuant to paragraph (b)(5)(iv)(B) of this section from this value.
Account for any gas contained in hoses before and after the transfer.
The amount of gas recovered shall be the measured nameplate capacity
for the electrical equipment unless the final temperature-compensated
pressure of the electrical equipment exceeds 0.068 psia (3.5 Torr) or
the electrical equipment user is calculating the nameplate capacity
pursuant to paragraph (b)(5)(iii)(B) of this section, in which cases
the measured nameplate capacity shall be the result of Equation DD-4.
    (vii) If you are calculating the nameplate capacity pursuant to
paragraph (b)(5)(iii)(B), use Equation DD-4 to do so.

[GRAPHIC] [TIFF OMITTED] TP21JN22.055

Where:

NCC = Nameplate capacity of the equipment measured and calculated by
the equipment user (pounds).
Pi = Initial temperature-compensated pressure of the equipment,
based on the temperature-pressure curve for the insulating gas
(psia).
Pf = Final temperature-compensated pressure of the equipment, based
on the temperature-pressure curve for the insulating gas (psia).
This may be equated to zero if the final temperature-compensated
pressure of the equipment is equal to or lower than 0.068 psia (3.5
Torr).
PNC = Temperature-compensated pressure of the equipment at the
manufacturer-specified filling density of the equipment (i.e., at
the full and proper charge, psia).
MR = Mass of insulating gas recovered from the equipment, measured
in paragraph (b)(5)(vi) of this section (pounds).

    (viii) Record the final system pressure and vessel temperature.
    (6) Instead of measuring the nameplate capacity of electrical
equipment when it is retired, users may measure the nameplate capacity
of electrical equipment during maintenance activities that require
opening the gas compartment, but they must follow the procedures set
forth in paragraph (b)(5) of this section.
    (7) If the electrical equipment will remain energized, and the
electrical equipment user is adopting the user-measured nameplate
capacity, the electrical equipment user must affix a revised nameplate
capacity label, showing the revised nameplate value and the year the
nameplate capacity adjustment process was performed, to the device by
the end of the calendar year in which the process was completed. The
manufacturer's previous nameplate capacity label must remain visible
after the revised nameplate capacity label is affixed to the device.
    (8) For each piece of electrical equipment whose nameplate capacity
was adjusted during the reporting year, the revised nameplate capacity
value must be used in all provisions wherein the nameplate capacity is
required to be recorded, reported, or used in a calculation in this
subpart unless otherwise specified herein.
    (9) The nameplate capacity of a piece of electrical equipment may
only be adjusted more than once if the physical capacity of the device
has changed (e.g., replacement of bushings) after the initial
adjustment was performed, in which case the equipment user must adjust
the nameplate capacity pursuant to the provisions of this paragraph
(b).
    (10) Measuring devices used to measure the nameplate capacity of
electrical equipment under this paragraph (b) must meet the following
accuracy and precision requirements:
    (i) Flow meters must be certified by the manufacturer to be
accurate and precise to within one percent of the largest value that
the flow meter can, according to the manufacturer's specifications,
accurately record.
    (ii) Pressure gauges must be certified by the manufacturer to be
accurate and precise to within 0.5% of the largest value that the gauge
can, according to the manufacturer's specifications, accurately record.
    (iii) Temperature gauges must be certified by the manufacturer to
be accurate and precise to within +/-1.0 [deg]F.
    (iv) Scales must be certified by the manufacturer to be accurate
and precise to within one percent of the true weight.
0
89. Amend Sec.  98.304 by removing and reserving paragraph (a) and
revising paragraphs (b)(1), (2), and (4).
    The revisions read as follows:

Sec.  98.304  Monitoring and QA/QC requirements.

* * * * *
    (b) * * *
    (1) Review inputs to Equation DD-3 of this section to ensure inputs
and outputs to the company's system are included.
    (2) Do not enter negative inputs and confirm that negative
emissions are not calculated. However, the Decrease in fluorinated GHG
Inventory and the Net Increase in Total Nameplate Capacity may be
calculated as negative numbers.
* * * * *
    (4) Ensure that in addition to fluorinated GHG purchased from bulk
gas distributors, fluorinated GHG purchased from Original Equipment
Manufacturers (OEM) and fluorinated GHG returned to the facility from
off-site recycling are also accounted for among the total additions.
* * * * *
0
90. Revise Sec.  98.305 to read as follows:

Sec.  98.305  Procedures for estimating missing data.

    A complete record of all measured parameters used in the GHG
emissions calculations is required. Replace missing data, if needed,
based on data from equipment with a similar nameplate capacity for
fluorinated GHGs, and from similar equipment repair, replacement, and
maintenance operations.
0
91. Amend Sec.  98.306 by revising paragraphs (a) introductory text,
(d) through (l), and (n) introductory text and adding paragraphs (o)
through (r) to read as follows:

Sec.  98.306  Data reporting requirements.

* * * * *
    (a) Nameplate capacity of equipment (pounds) containing each
insulating gas:
* * * * *
    (d) Pounds of each insulating gas stored in containers, but not in
energized equipment, at the beginning of the year.
    (e) Pounds of each insulating gas stored in containers, but not in
energized equipment, at the end of the year.
    (f) Pounds of each insulating gas purchased in bulk from chemical
producers or distributors.
    (g) Pounds of each insulating gas purchased from equipment
manufacturers or distributors with or inside equipment, including
hermetically sealed-pressure switchgear.
    (h) Pounds of each insulating gas returned to facility after off-
site recycling.
    (i) Pounds of each insulating gas in bulk and contained in
equipment sold to other entities.
    (j) Pounds of each insulating gas returned to suppliers.
    (k) Pounds of each insulating gas sent off-site for recycling.
    (l) Pounds of each insulating gas sent off-site for destruction.
* * * * *
    (n) The number of insulating gas containing pieces of equipment in
each of the following equipment categories:
* * * * *
    (o) The total of the nameplate capacity values most recently
assigned by the electrical equipment manufacturer(s) to each of the
following groups of equipment:
    (1) All new equipment whose nameplate capacity values were measured
by the user under this subpart and for which the user adopted the user-
measured nameplate capacity value during the year.
    (2) All retiring equipment whose nameplate capacity values were
measured by the user under this subpart and for which the user adopted
the user-measured nameplate capacity value during the year.
    (p) The total of the nameplate capacity values measured by the

electrical equipment user for each of the following groups of
equipment:
    (1) All new equipment whose nameplate capacity values were measured
by the user under this subpart and for which the user adopted the user-
measured nameplate capacity value during the year.
    (2) All retiring equipment whose nameplate capacity values were
measured by the user under this subpart and for which the user adopted
the user-measured nameplate capacity value during the year.
    (q) For each unique insulating gas reported in paragraphs (a), (d)
through (l), and (n) of this section, an ID number or other appropriate
descriptor.
    (r) For each ID number or descriptor reported in paragraph (q) of
this section for each unique insulating gas, the name (as required in
Sec.  98.3(c)(4)(iii)(G)(1)) and weight percent of each fluorinated gas
in the insulating gas.
0
92. Revise Sec.  98.307 to read as follows:

Sec.  98.307  Records that must be retained.

    (a) In addition to the information required by Sec.  98.3(g), you
must retain records of the information reported and listed in Sec.
98.306.
    (b) For each piece of electrical equipment whose nameplate capacity
is measured by the equipment user, retain records of the following:
    (1) Equipment manufacturer name.
    (2) Year equipment was manufactured. If the date year the equipment
was manufactured cannot be determined, report a best estimate of the
year of manufacture and record how the estimated year was determined.
    (3) Manufacturer serial number. For any piece of equipment whose
serial number is unknown (e.g., the serial number does not exist or is
not visible), another unique identifier must be recorded as the
manufacturer serial number. The electrical equipment user must retain
documentation that allows for each electrical equipment to be readily
identifiable.
    (4) Equipment type (i.e., closed-pressure vs. hermetically sealed-
pressure).
    (5) Equipment voltage capacity (in kilovolts).
    (6) The name and GWP of each insulating gas used.
    (7) Nameplate capacity value (pounds), as specified by the
equipment manufacturer. The value must reflect the latest value
specified by the manufacturer during the reporting year.
    (8) Nameplate capacity value (pounds) measured by the equipment
user.
    (9) The date the nameplate capacity measurement process was
completed.
    (10) The measurements and calculations used to calculate the value
in paragraph (b)(8) of this section.
    (11) The temperature-pressure curve and/or other information used
to derive the initial and final temperature-adjusted pressures of the
equipment.
    (12) Whether or not the nameplate capacity value in paragraph
(b)(8) of this section has been adopted for the piece of electrical
equipment.
0
93. Amend Sec.  98.308 by revising the definition of ``Facility'' and
adding in alphabetical order definitions for ``Energized'',
``Insulating gas'', ``New equipment'', and ``Retired equipment'' to
read as follows:

Sec.  98.308  Definitions.

* * * * *
    Facility, with respect to an electric power system, means the
electric power system as defined in this paragraph. An electric power
system is comprised of all electric transmission and distribution
equipment insulated with or containing fluorinated GHGs that is linked
through electric power transmission or distribution lines and functions
as an integrated unit, that is owned, serviced, or maintained by a
single electric power transmission or distribution entity (or multiple
entities with a common owner), and that is located between {1{time} The
point(s) at which electric energy is obtained from an electricity
generating unit or a different electric power transmission or
distribution entity that does not have a common owner, and {2{time}
the point(s) at which any customer or another electric power
transmission or distribution entity that does not have a common owner
receives the electric energy. The facility also includes servicing
inventory for such equipment that contains fluorinated GHGs.
* * * * *
    Energized, for the purposes of this subpart, means connected
through busbars or cables to an electrical power system or fully-
charged, ready for service, and being prepared for connection to the
electrical power system. Energized equipment does not include spare gas
insulated equipment (including hermetically-sealed pressure switchgear)
in storage that has been acquired by the facility, and is intended for
use by the facility, but that is not being used or prepared for
connection to the electrical power system.
    Insulating gas, for the purposes of this subpart, means any
fluorinated GHG or fluorinated GHG mixture, including but not limited
to SF6 and PFCs, that is used as an insulating and/or arc-quenching gas
in electrical equipment.
    New equipment, for the purposes of this subpart, means any gas
insulated equipment, including hermetically-sealed pressure switchgear,
that is not energized at the beginning of the reporting year, but is
energized at the end of the reporting year. This includes equipment
that has been transferred while in use, meaning it has been added to
the facility's inventory without being taken out of active service
(e.g., when the equipment is sold to or acquired by the facility while
remaining in place and continuing operation).
* * * * *
    Retired equipment, for the purposes of this subpart, means any gas
insulated equipment, including hermetically-sealed pressure switchgear,
that is energized at the beginning of the reporting year, but is not
energized at the end of the reporting year. This includes equipment
that has been transferred while in use, meaning it has been removed
from the facility's inventory without being taken out of active service
(e.g., when the equipment is acquired by a new facility while remaining
in place and continuing operation).

Subpart FF--Underground Coal Mines

0
94. Amend Sec.  98.323 by revising parameter ``MCFi'' of Equation FF-3
in paragraph (b) introductory text to read as follows:

Sec.  98.323  Calculating GHG emissions.

* * * * *
    (b) * * *

MCFi = Moisture correction factor for the measurement period,
volumetric basis.
= 1 when Vi and Ci are measured on a dry basis or if both are measured
on a wet basis.
= 1-(fH2O)i when Vi is measured on a wet basis and Ci is measured on a
dry basis.
= 1/[1-(fH2O)i] when Vi is measured on a dry basis and Ci is measured
on a wet basis.
* * * * *
0
95. Amend Sec.  98.326 by revising paragraph (t) to read as follows:

Sec.  98.326  Data reporting requirements.

* * * * *
    (t) Mine Safety and Health Administration (MSHA) identification
number for this coal mine.

Subpart GG--Zinc Production

0
96. Amend Sec.  98.333 by revising paragraph (b)(1) introductory text
to read as follows:

Sec.  98.333  Calculating GHG emissions.

* * * * *
    (b) * * *
    (1) For each Waelz kiln or electrothermic furnace at your facility
used for zinc production, you must determine the mass of carbon in each
carbon-containing material, other than fuel, that is fed, charged, or
otherwise introduced into each Waelz kiln and electrothermic furnace at
your facility for each year and calculate annual CO2 process
emissions from each affected unit at your facility using Equation GG-1
of this section. For electrothermic furnaces, carbon containing input
materials include carbon electrodes and carbonaceous reducing agents.
For Waelz kilns, carbon containing input materials include carbonaceous
reducing agents. If you document that a specific material contributes
less than 1 percent of the total carbon into the process, you do not
have to include the material in your calculation using Equation R-1 of
Sec.  98.183.
* * * * *
0
97. Amend Sec.  98.336 by adding paragraph (a)(6) and revising
paragraph (b)(6) to read as follows:

Sec.  98.336  Data reporting requirements.

* * * * *
    (a) * * *
    (6) Total amount of electric arc furnace dust annually consumed by
all Waelz kilns at the facility (tons).
    (b) * * *
    (6) Total amount of electric arc furnace dust annually consumed by
all Waelz kilns at the facility (tons).
* * * * *

Subpart HH--Municipal Solid Waste Landfills

0
98. Amend Sec.  98.343 by revising paragraph (a)(2) to read as follows:

Sec.  98.343  Calculating GHG emissions.

    (a) * * *
    (2) For years when material-specific waste quantity data are
available, apply Equation HH-1 of this section for each waste quantity
type and sum the CH4 generation rates for all waste types to
calculate the total modeled CH4 generation rate for the
landfill. Use the appropriate parameter values for k, DOC, MCF,
DOCF, and F shown in Table HH-1 of this subpart. The annual
quantity of each type of waste disposed must be calculated as the sum
of the daily quantities of waste (of that type) disposed. You may use
the uncharacterized MSW parameters for a portion of your waste
materials when using the material-specific modeling approach for mixed
waste streams that cannot be designated to a specific material type.
For years when waste composition data are not available, use the bulk
waste parameter values for k and DOC in Table HH-1 to this subpart for
the total quantity of waste disposed in those years.
* * * * *
0
99. Amend Sec.  98.346 by adding paragraphs (i)(6)(i) and (ii) to read
as follows:

Sec.  98.346  Data reporting requirements.

* * * * *
    (i) * * *
    (6) * * *
    (i) The percentage of total recovered CH4 that is sent
to each measurement location (decimal, must total to 1 across all
measurement locations at the facility).
    (ii) For each measurement location, the percentage of total
recovered CH4 that is sent to a flare, a landfill gas to
energy project, or an unknown option if gas is sent off-site for
destruction and the type of destruction technology is unknown (decimal,
must total to 1 for each measurement location).
* * * * *
0
100. Revise table HH-1 to subpart HH of part 98 to read as follows:

    Table HH-1 to Subpart HH of Part 98--Emissions Factors, Oxidation
                           Factors and Methods
------------------------------------------------------------------------
             Factor                  Default value           Units
------------------------------------------------------------------------
DOC and k values--Bulk waste option
------------------------------------------------------------------------
DOC (bulk waste)................  0.17..............  Weight fraction,
                                                       wet basis.
k (precipitation plus             0.055.............  yr-1
 recirculated leachate \a\ <20
 inches/year).
k (precipitation plus             0.111.............  yr-1
 recirculated leachate \a\ 20-40
 inches/year).
k (precipitation plus             0.142.............  yr-1
 recirculated leachate \a\ >40
 inches/year).
------------------------------------------------------------------------
DOC and k values--Modified bulk MSW option
------------------------------------------------------------------------
DOC (bulk MSW, excluding inerts   0.27..............  Weight fraction,
 and C&D waste).                                       wet basis.
DOC (inerts, e.g., glass,         0.00..............  Weight fraction,
 plastics, metal, concrete).                           wet basis.
DOC (C&D waste).................  0.08..............  Weight fraction,
                                                       wet basis.
k (bulk MSW, excluding inerts     0.02 to 0.057 \b\.  yr-1
 and C&D waste).
k (inerts, e.g., glass,           0.00..............  yr-1
 plastics, metal, concrete).
k (C&D waste)...................  0.02 to 0.04 \b\..  yr-1
------------------------------------------------------------------------
DOC and k values--Waste composition option
------------------------------------------------------------------------
DOC (food waste)................  0.15..............  Weight fraction,
                                                       wet basis.
DOC (garden)....................  0.2...............  Weight fraction,
                                                       wet basis.
DOC (paper).....................  0.4...............  Weight fraction,
                                                       wet basis.
DOC (wood and straw)............  0.43..............  Weight fraction,
                                                       wet basis.
DOC (textiles)..................  0.24..............  Weight fraction,
                                                       wet basis.
DOC (diapers)...................  0.24..............  Weight fraction,
                                                       wet basis.
DOC (sewage sludge).............  0.05..............  Weight fraction,
                                                       wet basis.
DOC (inerts, e.g., glass,         0.00..............  Weight fraction,
 plastics, metal, cement).                             wet basis.
DOC (Uncharacterized MSW).......  0.32..............  Weight fraction,
                                                       wet basis.
k (food waste)..................  0.06 to 0.185 \c\.  yr-1
k (garden)......................  0.05 to 0.10 \c\..  yr-1
k (paper).......................  0.04 to 0.06 \c\..  yr-1
k (wood and straw)..............  0.02 to 0.03 \c\..  yr-1

k (textiles)....................  0.04 to 0.06 \c\..  yr-1
k (diapers).....................  0.05 to 0.10 \c\..  yr-1
k (sewage sludge)...............  0.06 to 0.185 \c\.  yr-1
k (inerts, e.g., glass,           0.00..............  yr-1
 plastics, metal, concrete).
k (uncharacterized MSW).........  0.055 to 0.142....  yr-1
------------------------------------------------------------------------
Other parameters--All MSW landfills
------------------------------------------------------------------------
MCF.............................  1.................
DOCF............................  0.5...............
F...............................  0.5...............
OX..............................  See Table HH-4 of
                                   this subpart.
DE..............................  0.99..............
------------------------------------------------------------------------
\a\ Recirculated leachate (in inches/year) is the total volume of
  leachate recirculated from company records or engineering estimates
  divided by the area of the portion of the landfill containing waste
  with appropriate unit conversions. Alternatively, landfills that use
  leachate recirculation can elect to use the k value of 0.142 rather
  than calculating the recirculated leachate rate.
\b\ Use the lesser value when precipitation plus recirculated leachate
  is less than 20 inches/year. Use the greater value when precipitation
  plus recirculated leachate is greater than 40 inches/year. Use the
  average of the range of values when precipitation plus recirculated
  leachate is 20 to 40 inches/year (inclusive). Alternatively, landfills
  that use leachate recirculation can elect to use the greater value
  rather than calculating the recirculated leachate rate.
\c\ Use the lesser value when the potential evapotranspiration rate
  exceeds the mean annual precipitation rate plus recirculated leachate.
  Use the greater value when the potential evapotranspiration rate does
  not exceed the mean annual precipitation rate plus recirculated
  leachate. Alternatively, landfills that use leachate recirculation can
  elect to use the greater value rather than assessing the potential
  evapotranspiration rate or recirculated leachate rate.

Subpart OO--Suppliers of Industrial Greenhouse Gases

0
101. Amend Sec.  98.416 by revising paragraphs (c)(6) and (7) and
(d)(4) and adding paragraph (k) to read as follows:

Sec.  98.416  Data reporting requirements.

* * * * *
    (c) * * *
    (6) Harmonized tariff system (HTS) code of the fluorinated GHGs,
fluorinated HTFs, or nitrous oxide shipped.
    (7) Customs entry summary number and importer number for each
shipment.
* * * * *
    (d) * * *
    (4) Harmonized tariff system (HTS) code of the fluorinated GHGs,
fluorinated HTFs, or nitrous oxide shipped.
* * * * *
    (k) For nitrous oxide, saturated perfluorocarbons, and sulfur
hexafluoride, report the end use(s) for which each GHG is transferred
and the aggregated annual quantity of that GHG in metric tons that is
transferred to that end use application, if known.

Subpart PP-- Suppliers of Carbon Dioxide

0
102. Amend Sec.  98.420 by adding paragraph (a)(4) to read as follows:

Sec.  98.420  Definition of the source category.

    (a) * * *
    (4) Facilities with process units, including but not limited to
direct air capture (DAC), that capture a CO2 stream from
ambient air for purposes of supplying CO2 for commercial
applications or that capture and maintain custody of a CO2
stream in order to sequester or otherwise inject it underground.
* * * * *
0
103. Amend Sec.  98.422 by adding paragraph (e) to read as follows:

Sec.  98.422  GHGs to report.

* * * * *
    (e) Mass of CO2 captured from DAC process units.
    (1) Mass of CO2 captured from ambient air.
    (2) Mass of CO2 captured from any on-site heat and/or
electricity generation, where applicable.
0
104. Amend Sec.  98.423 by revising paragraphs (a)(3)(i) introductory
text and (a)(3)(ii) introductory text to read as follows:

Sec.  98.423  Calculating CO2 supply.

    (a) * * *
    (3) * * *
    (i) For facilities with production process units, DAC process
units, or production wells that capture or extract a CO2
stream and either measure it after segregation or do not segregate the
flow, calculate the total CO2 supplied in accordance with
Equation PP-3a in paragraph (a)(3).
* * * * *
    (ii) For facilities with production process units or DAC process
units that capture a CO2 stream and measure it ahead of
segregation, calculate the total CO2 supplied in accordance
with Equation PP-3b.
* * * * *
0
105. Amend Sec.  98.426 by adding paragraph (i) to read as follows:

Sec.  98.426  Data reporting requirements.

* * * * *
    (i) If you capture a CO2 stream at a facility with a DAC
process unit, report the annual quantity of on-site and off-site
electricity and heat generated for each DAC process unit as specified
in paragraphs (i)(1) through (3) of this section. The quantities
specified in paragraphs (i)(1) through (3) must be provided per energy
source if known and must represent the electricity and heat used for
the DAC process unit starting with air intake and ending with the
compressed CO2 stream (i.e., the CO2 stream ready
for supply for commercial applications or, if maintaining custody of
the stream, sequestration or injection of the stream underground).
    (1) Electricity excluding combined heat and power (CHP). If
electricity is provided to a dedicated meter for the DAC process unit,
report the annual quantity of electricity consumed, in megawatt hours
(MWh), and the information in paragraph (i)(1)(i) or (ii) of this
section.

    (i) If the electricity is sourced from a grid connection, report
the following information:
    (A) State where the facility with the DAC process unit is located.
    (B) County where the facility with the DAC process unit is located.
    (C) Name of the electric utility company that supplied the
electricity as shown on the last monthly bill issued by the utility
company during the reporting period.
    (D) Name of the electric utility company that delivered the
electricity. In states with regulated electric utility markets, this
will generally be the same utility reported under paragraph
(i)(1)(i)(C) of this section, but in states with deregulated electric
utility markets, this may be a different utility company.
    (E) Annual quantity of electricity consumed in MWh, calculated as
the sum of the total energy usage values specified in all billing
statements received during the reporting year. Most customers will
receive 12 monthly billing statements during the reporting year. Many
utilities bill their customers per kilowatt-hour (kWh); usage values on
bills that are based on kWh should be divided by 1,000 to report the
usage in MWh as required under this paragraph.
    (ii) If electricity is sourced from on-site or through a
contractual mechanism for dedicated off-site generation, for each
applicable energy source specified in paragraphs (i)(1)(ii)(A) through
(G) of this section, report the annual quantity of electricity
consumed, in MWh. If the on-site electricity source is natural gas,
oil, or coal, also indicate whether flue gas is also captured by the
DAC process unit.
    (A) Non-hydropower renewable sources including solar, wind,
geothermal and tidal.
    (B) Hydropower.
    (C) Natural gas.
    (D) Oil.
    (E) Coal.
    (F) Nuclear.
    (G) Other.
    (2) Heat excluding CHP. For each applicable energy source specified
in paragraphs (i)(2)(i) through (vii) of this section, report the
annual quantity of heat, steam, or other forms of thermal energy
sourced from on-site or through a contractual mechanism for dedicated
off-site generation, in megajoules (MJ). If the on-site heat source is
natural gas, oil, or coal, also indicate whether flue gas is also
captured by the DAC process unit.
    (i) Solar.
    (ii) Geothermal.
    (iii) Natural gas.
    (iv) Oil.
    (v) Coal.
    (vi) Nuclear.
    (vii) Other.
    (3) CHP--(i) Electricity from CHP. If electricity from CHP is
sourced from on-site or through a contractual mechanism for dedicated
off-site generation, for each applicable energy source specified in
paragraphs (i)(3)(i)(A) through (G) of this section, report the annual
quantity consumed, in MWh. If the on-site electricity source for CHP is
natural gas, oil, or coal, also indicate whether flue gas is also
captured by the DAC process unit.
    (A) Non-hydropower renewable sources including solar, wind,
geothermal and tidal.
    (B) Hydropower.
    (C) Natural gas.
    (D) Oil.
    (E) Coal.
    (F) Nuclear.
    (G) Other.
    (ii) Heat from CHP. For each applicable energy source specified in
paragraphs (i)(3)(ii)(A) through (G) of this section, report the
quantity of heat, steam, or other forms of thermal energy from CHP
sourced from on-site or through a contractual mechanism for dedicated
off-site generation, in MJ. If the on-site heat source is natural gas,
oil, or coal, also indicate whether flue gas is also captured by the
DAC process unit.
    (A) Solar.
    (B) Geothermal.
    (C) Natural gas.
    (D) Oil.
    (E) Coal.
    (F) Nuclear.
    (G) Other.
0
106. Amend Sec.  98.427 by revising paragraph (a) to read as follows:

Sec.  98.427  Records that must be retained.

* * * * *
    (a) The owner or operator of a facility containing production
process units or DAC process units must retain quarterly records of
captured or transferred CO2 streams and composition.
* * * * *

Subpart SS--Electrical Equipment Manufacture or Refurbishment

0
107. Revise Sec.  98.450 to read as follows:

Sec.  98.450  Definition of the source category.

    The electrical equipment manufacturing or refurbishment category
consists of processes that manufacture or refurbish gas-insulated
substations, circuit breakers, other switchgear, gas-insulated lines,
or power transformers (including gas-containing components of such
equipment) containing fluorinated GHGs, including but not limited to
sulfur-hexafluoride (SF6) and perfluorocarbons (PFCs). The processes
include equipment testing, installation, manufacturing, decommissioning
and disposal, refurbishing, and storage in gas cylinders and other
containers.
0
108. Revise Sec.  98.451 to read as follows:

Sec.  98.451  Reporting threshold.

    You must report GHG emissions under this subpart if your facility
contains an electrical equipment manufacturing or refurbishing process
and the facility meets the requirements of Sec.  98.2(a)(2). To
calculate total annual GHG emissions for comparison to the 25,000
metric ton CO2e per year emission threshold in Sec.  98.2(a)(2), follow
the requirements of Sec.  98.2(b), with one exception. Instead of
following the requirement of Sec.  98.453 to calculate emissions from
electrical equipment manufacture or refurbishment, you must calculate
emissions of each fluorinated GHG, including but not limited to SF6 and
PFCs, and then sum the emissions of each fluorinated GHG resulting from
manufacturing and refurbishing electrical equipment using Equation SS-1
of this subpart.
[GRAPHIC] [TIFF OMITTED] TP21JN22.056

Where:

E = Annual production process emissions for threshold applicability
purposes (metric tons CO2e).
Pj = Total annual purchases of insulating gas j (lbs).
GHGi,w = The weight fraction of fluorinated GHG i in
insulating gas j if insulating gas j is a gas mixture. If not a
mixture, use 1.
GWPi = Gas-appropriate GWP as provided in Table A-1 to
subpart A of this part.
EF = Emission factor for electrical transmission and distribution
equipment (lbs emitted/lbs purchased). For all gases, use an
emission factor of 0.1.

i = fluorinated GHG contained in the electrical transmission and
distribution equipment.
0.000453592 = conversion factor from lbs to metric tons.

0
109. Amend Sec.  98.452 by revising paragraph (a) to read as follows:

Sec.  98.452  GHGs to report.

    (a) You must report emissions of each fluorinated GHG, including
but not limited to SF6 and PFCs, at the facility level. Annual
emissions from the facility must include fluorinated GHG emissions from
equipment that is installed at an off-site electric power transmission
or distribution location whenever emissions from installation
activities (e.g., filling) occur before the title to the equipment is
transferred to the electric power transmission or distribution entity.
* * * * *
0
110. Amend Sec.  98.453 by:
0
a. Revising paragraph (a);
0
b. Removing and reserving paragraph (b); and
0
c. Revising paragraphs (c) through (g), (h) introductory text, and (i).
    The revisions read as follows:

Sec.  98.453  Calculating GHG emissions.

    (a) For each electrical equipment manufacturer or refurbisher,
estimate the annual emissions of each fluorinated GHG using the mass-
balance approach in Equation SS-2 of this section:
[GRAPHIC] [TIFF OMITTED] TP21JN22.057

Where:

User emissionsi = Annual emissions of each fluorinated
GHG i (pounds).
GHGi,w = The weight fraction of fluorinated GHG i in
insulating gas j if insulating gas j is a gas mixture, expressed as
a decimal fraction. If fluorinated GHG i is not part of a gas
mixture, use a value of 1.0.
Decrease in insulating gas j Inventory = (Pounds of insulating gas j
stored in containers at the beginning of the year) - (Pounds of
insulating gas j stored in containers at the end of the year).
Acquisitions of insulating gas j = (Pounds of each insulating gas j
purchased from chemical producers or suppliers in bulk) + (Pounds of
each insulating gas j returned by equipment users) + (Pounds of each
insulating gas j returned to site after off-site recycling).
Disbursements of insulating gas j = (Pounds of each insulating gas j
contained in new equipment delivered to customers) + (Pounds of each
insulating gas j delivered to equipment users in containers) +
(Pounds of each insulating gas j returned to suppliers) + (Pounds of
each insulating gas j sent off site for recycling) + (Pounds of each
insulating gas j sent off-site for destruction).
* * * * *
    (c) Estimate the disbursements of each insulating gas j (including,
but not limited to SF6 and PFCs) sent to customers in new
equipment or cylinders or sent off-site for other purposes including
for recycling, for destruction or to be returned to suppliers using
Equation SS-3 of this section:
[GRAPHIC] [TIFF OMITTED] TP21JN22.058

Where:

DGHG = The annual disbursement of each insulating gas j
sent to customers in new equipment or cylinders or sent off-site for
other purposes including for recycling, for destruction or to be
returned to suppliers.
Qp = The mass of each insulating gas j charged into
equipment or containers over the period p sent to customers or sent
off-site for other purposes including for recycling, for destruction
or to be returned to suppliers.
n = The number of periods in the year.

    (d) Estimate the mass of each insulating gas j (including, but not
limited to SF6 and PFCs) disbursed to customers in new
equipment or cylinders over the period p by monitoring the mass flow of
each insulating gas j into the new equipment or cylinders using a
flowmeter, or by weighing containers before and after gas from
containers is used to fill equipment or cylinders, or by using the
nameplate capacity of the equipment.
    (e) If the mass of insulating gas j disbursed to customers in new
equipment or cylinders over the period p is estimated by weighing
containers before and after gas from containers is used to fill
equipment or cylinders, estimate this quantity using Equation SS-4 of
this section:
[GRAPHIC] [TIFF OMITTED] TP21JN22.059

Where:

Qp = The mass of each insulating gas j charged into
equipment or containers over the period p sent to customers or sent
off-site for other purposes including for recycling, for destruction
or to be returned to suppliers.
MB = The mass of the contents of the containers used to
fill equipment or cylinders at the beginning of period p.
ME = The mass of the contents of the containers used to
fill equipment or cylinders at the end of period p.
EL = The mass of each insulating gas j emitted during the
period p downstream of the containers used to fill equipment or
cylinders and in cases where a flowmeter is used, downstream of the
flowmeter during the period p (e.g., emissions from hoses or other
flow lines that connect the container to the equipment or cylinder
that is being filled).

    (f) If the mass of each insulating gas j (including, but not
limited to SF6 and PFCs) disbursed to customers in new
equipment or cylinders over the period p is determined using a
flowmeter, estimate this quantity using Equation SS-5 of this section:
[GRAPHIC] [TIFF OMITTED] TP21JN22.060

Where:

Qp = The mass of each insulating gas j (including, but
not limited to SF6 and PFCs) charged into equipment or
containers over the period p sent to customers or sent off-site for
other purposes including for recycling, for destruction or to be
returned to suppliers.
Mmr = The mass of each insulating gas j that has flowed
through the flowmeter during the period p.
EL = The mass of each insulating gas j emitted during the
period p downstream of the containers used to fill equipment or
cylinders and in cases where a flowmeter is used, downstream of the
flowmeter during the period p (e.g., emissions from hoses or other
flow lines that connect the container to the equipment that is being
filled).

    (g) Estimate the mass of each insulating gas j emitted during the
period p downstream of the containers used to fill equipment or
cylinders (e.g., emissions from hoses or other flow lines that connect
the container to the equipment or cylinder that is being filled) using
Equation SS-6 of this section:
[GRAPHIC] [TIFF OMITTED] TP21JN22.061

Where:

EL = The mass of each fluorinated GHG (including, but not
limited to SF6 and PFCs) or fluorinated GHG mixture
emitted during the period p downstream of the containers used to
fill equipment or cylinders and in cases where a flowmeter is used,
downstream of the flowmeter during the period p (e.g., emissions
from hoses or other flow lines that connect the container to the
equipment or cylinder that is being filled).
FCi = The total number of fill operations over the period
p for the valve-hose combination Ci.
EFCi = The emission factor for the valve-hose combination
Ci.
n = The number of different valve-hose combinations C used during
the period p.

    (h) If the mass of each insulating gas j disbursed to customers in
new equipment or cylinders over the period p is determined by using the
nameplate capacity, or by using the nameplate capacity of the equipment
and calculating the partial shipping charge, use the methods in either
paragraph (h)(1) or (h)(2) of this section.
* * * * *
    (i) Estimate the annual emissions of each insulating gas j from the
equipment that is installed at an off-site electric power transmission
or distribution location before the title to the equipment is
transferred by using Equation SS-7 of this section:
[GRAPHIC] [TIFF OMITTED] TP21JN22.062

Where:

EI = Total annual emissions of each insulating gas j from equipment
installation at electric transmission or distribution facilities.
GHGi,w = The weight fraction of fluorinated GHG i in
insulating gas j if insulating gas j is a gas mixture, expressed as
a decimal fraction. If the GHG i is not part of a gas mixture, use a
value of 1.0.
MF = The total annual mass of each insulating gas j, in
pounds, used to fill equipment during equipment installation at
electric transmission or distribution facilities.
MC = The total annual mass of each insulating gas j, in
pounds, used to charge the equipment prior to leaving the electrical
equipment manufacturer facility.
NI = The total annual nameplate capacity of the
equipment, in pounds, installed at electric transmission or
distribution facilities.
0
111. Amend Sec.  98.454 by removing and reserving paragraph (a) and
revising paragraphs (b), (d) through (f), and (h)(1) through (4).
    The revisions read as follows:

Sec.  98.454  Monitoring and QA/QC requirements.

* * * * *
    (b) Ensure that all the quantities required by the equations of
this subpart have been measured using either flowmeters with an
accuracy and precision of 1 percent of full scale or better
or scales with an accuracy and precision of 1 percent of
the filled weight (gas plus tare) of the containers of each insulating
gas that are typically weighed on the scale. For scales that are
generally used to weigh cylinders containing 115 pounds of gas when
full, this equates to 1 percent of the sum of 115 pounds
and approximately 120 pounds tare, or slightly more than 2
pounds. Account for the tare weights of the containers. You may accept
gas masses or weights provided by the gas supplier (e.g., for the
contents of cylinders containing new gas or for the heels remaining in
cylinders returned to the gas supplier) if the supplier provides
documentation verifying that accuracy standards are met; however, you
remain responsible for the accuracy of these masses and weights under
this subpart.
* * * * *
    (d) For purposes of Equations SS-6 of this subpart, the emission
factor for the valve-hose combination (EFC) must be
estimated using measurements and/or engineering assessments or
calculations based on chemical engineering principles or physical or
chemical laws or properties. Such assessments or calculations may be
based on, as applicable, the internal volume of hose or line that is
open to the atmosphere during coupling and decoupling activities, the
internal pressure of the hose or line, the time the hose or line is
open to the atmosphere during coupling and decoupling activities, the
frequency with which the hose or line is purged and the flow rate
during purges. You must develop a value for EFc (or use an
industry-developed value) for each combination of hose and valve
fitting, to use in Equation SS-6 of this subpart. The value for
EFC must be determined for each combination of hose and
valve fitting of a given diameter or size. The calculation must be
recalculated annually to account for changes to the specifications of
the valves or hoses that may occur throughout the year.
    (e) Electrical equipment manufacturers and refurbishers must
account for emissions of each insulating gas that occur as a result of
unexpected events or accidental losses, such as a malfunctioning hose
or leak in the flow line, during the filling of equipment or containers
for disbursement by including these losses in the estimated mass of
each insulating gas emitted downstream of the container or flowmeter
during the period p.
    (f) If the mass of each insulating gas j disbursed to customers in
new equipment over the period p is determined by assuming that it is
equal to the equipment's nameplate capacity or, in cases where
equipment is shipped

with a partial charge, equal to its partial shipping charge, equipment
samples for conducting the nameplate capacity tests must be selected
using the following stratified sampling strategy in this paragraph. For
each make and model, group the measurement conditions to reflect
predictable variability in the facility's filling practices and
conditions (e.g., temperatures at which equipment is filled). Then,
independently select equipment samples at random from each make and
model under each group of conditions. To account for variability, a
certain number of these measurements must be performed to develop a
robust and representative average nameplate capacity (or shipping
charge) for each make, model, and group of conditions. A Student T
distribution calculation should be conducted to determine how many
samples are needed for each make, model, and group of conditions as a
function of the relative standard deviation of the sample measurements.
To determine a sufficiently precise estimate of the nameplate capacity,
the number of measurements required must be calculated to achieve a
precision of one percent of the true mean, using a 95 percent
confidence interval. To estimate the nameplate capacity for a given
make and model, you must use the lowest mean value among the different
groups of conditions, or provide justification for the use of a
different mean value for the group of conditions that represents the
typical practices and conditions for that make and model. Measurements
can be conducted using SF6, another gas, or a liquid. Re-
measurement of nameplate capacities should be conducted every five
years to reflect cumulative changes in manufacturing methods and
conditions over time.
* * * * *
    (h) * * *
    (1) Review inputs to Equation SS-2 of this subpart to ensure inputs
and outputs to the company's system are included.
    (2) Do not enter negative inputs and confirm that negative
emissions are not calculated. However, the decrease in the inventory
for each insulating gas may be calculated as negative.
    (3) Ensure that for each insulating gas, the beginning-of-year
inventory matches the end-of-year inventory from the previous year.
    (4) Ensure that for each insulating gas, in addition to the
insulating gas purchased from bulk gas distributors, the insulating gas
returned from equipment users with or inside equipment and the
insulating gas returned from off-site recycling are also accounted for
among the total additions.
0
112. Amend Sec.  98.456 by revising paragraphs (a) through (k) and (n)
through (s) and adding paragraphs (u) and (v) to read as follows:

Sec.  98.456  Data reporting requirements.

* * * * *
    (a) Pounds of each insulating gas stored in containers at the
beginning of the year.
    (b) Pounds of each insulating gas stored in containers at the end
of the year.
    (c) Pounds of each insulating gas purchased in bulk.
    (d) Pounds of each insulating gas returned by equipment users with
or inside equipment.
    (e) Pounds of each insulating gas returned to site from off site
after recycling.
    (f) Pounds of each insulating gas inside new equipment delivered to
customers.
    (g) Pounds of each insulating gas delivered to equipment users in
containers.
    (h) Pounds of each insulating gas returned to suppliers.
    (i) Pounds of each insulating gas sent off site for destruction.
    (j) Pounds of each insulating gas sent off site to be recycled.
    (k) The nameplate capacity of the equipment, in pounds, delivered
to customers with insulating gas inside, if different from the quantity
in paragraph (f) of this section.
* * * * *
    (n) The total number of fill operations for each hose and valve
combination, or, FCi of Equation SS-6 of this subpart.
    (o) If the mass of each insulating gas disbursed to customers in
new equipment over the period p is determined according to the methods
required in Sec.  98.453(h), report the mean value of nameplate
capacity in pounds for each make, model, and group of conditions.
    (p) If the mass of each insulating gas disbursed to customers in
new equipment over the period p is determined according to the methods
required in Sec.  98.453(h), report the number of samples and the upper
and lower bounds on the 95-percent confidence interval for each make,
model, and group of conditions.
    (q) Pounds of each insulating gas used to fill equipment at off-
site electric power transmission or distribution locations, or
MF, of Equation SS-7 of this subpart.
    (r) Pounds of each insulating gas used to charge the equipment
prior to leaving the electrical equipment manufacturer or refurbishment
facility, or MC, of Equation SS-7 of this subpart.
    (s) The nameplate capacity of the equipment, in pounds, installed
at off-site electric power transmission or distribution locations used
to determine emissions from installation, or NI, of Equation
SS-7 of this subpart.
* * * * *
    (u) For each unique insulating gas reported in paragraphs (a)
through (j) and (o) through (r) of this section, an ID number or other
appropriate descriptor.
    (v) For each ID number or descriptor reported in paragraph (u) of
this section for each unique insulating gas, the name (as required in
Sec.  98.3(c)(4)(iii)(G)(1)) and weight percent of each fluorinated gas
in the insulating gas.
0
113. Revise Sec.  98.458 to read as follows:

Sec.  98.458  Definitions.

    Except as specified in this section, all terms used in this subpart
have the same meaning given in the CAA and subpart A of this part.
    Insulating gas, for the purposes of this subpart, means any
fluorinated GHG or fluorinated GHG mixture, including but not limited
to SF6 and PFCs, that is used as an insulating and/or arc-
quenching gas in electrical equipment.

Subpart UU--Injection of Carbon Dioxide

0
114. Amend Sec.  98.470 by redesignating paragraph (c) as paragraph (d)
and adding new paragraph (c) to read as follows:

Sec.  98.470  Definition of the source category.

* * * * *
    (c) If you report under subpart VV of this part for a well or group
of wells, you are not required to report under this subpart for that
well or group of wells.
* * * * *
0
115. Add subpart VV to read as follows:

Subpart VV--Geologic Sequestration of Carbon Dioxide With Enhanced
Oil Recovery Using ISO 27916

Sec.
98.480 Definition of the source category.
98.481 Reporting threshold.
98.482 GHGs to report.
98.483 Calculating CO2 geologic sequestration.
98.484 Monitoring and QA/QC requirements.
98.485 Procedures for estimating missing data.
98.486 Data reporting requirements.
98.487 Records that must be retained.
98.488 EOR Operations Management Plan.
98.489 Definitions.

Subpart VV--Geologic Sequestration of Carbon Dioxide With Enhanced
Oil Recovery Using ISO 27916

Sec.  98.480  Definition of the source category.

    (a) This source category pertains to carbon dioxide
(CO2) that is injected in enhanced recovery operations for
oil and other hydrocarbons (CO2-EOR) in which all of the
following apply:
    (1) You are using the International Standards Organization (ISO)
standard designated as CSA/ANSI ISO 27916:2019 (incorporated by
reference, see Sec.  98.7) as a method of quantifying geologic
sequestration of CO2 in association with EOR operations.
    (2) You are not reporting under subpart UU of this part.
    (3) You are not reporting under subpart RR of this part.
    (b) This source category does not include wells permitted as Class
VI under the Underground Injection Control program.
    (c) If you are subject to only this subpart, you are not required
to report emissions under subpart C of this part or any other subpart
listed in Sec.  98.2(a)(1) or (a)(2).

Sec.  98.481  Reporting threshold.

    (a) You must report under this subpart if your CO2-EOR
project uses CSA/ANSI ISO 27916:2019 (incorporated by reference, see
Sec.  98.7) as a method of quantifying geologic sequestration of
CO2 in association with CO2-EOR operations. There
is no threshold for reporting.
    (b) The requirements of Sec.  98.2(i) do not apply to this subpart.
Once a CO2-EOR project becomes subject to the requirements
of this subpart, you must continue for each year thereafter to comply
with all requirements of this subpart, including the requirement to
submit annual reports until the facility has met the requirements of
paragraphs (b)(1) and (2) of this section and submitted a notification
to discontinue reporting according to paragraph (b)(3) of this section.
    (1) Discontinuation of reporting under this subpart must follow the
requirements set forth under Clause 10 of CSA/ANSI ISO 27916:2019.
    (2) CO2-EOR project termination is completed when all of
the following occur:
    (i) Cessation of CO2 injection.
    (ii) Cessation of hydrocarbon production from the project
reservoir; and
    (iii) Wells are plugged and abandoned unless otherwise required by
the appropriate regulatory authority.
    (3) You must notify the Administrator of your intent to cease
reporting and provide a copy of the CO2-EOR project
termination documentation.

Sec.  98.482  GHGs to report.

    You must report the following from Clause 8 of CSA/ANSI ISO
27916:2019 (incorporated by reference, see Sec.  98.7):
    (a) The mass of CO2 received by the CO2-EOR
project.
    (b) The mass of CO2 loss from the CO2-EOR
project operations.
    (c) The mass of native CO2 produced and captured.
    (d) The mass of CO2 produced and sent off-site.
    (e) The mass of CO2 loss from the EOR complex.
    (f) The mass of CO2 stored in association with
CO2-EOR.

Sec.  98.483  Calculating CO2 geologic sequestration.

    You must calculate CO2 sequestered using the following
quantification principles from Clause 8.2 of CSA/ANSI ISO 27916:2019
(incorporated by reference, see Sec.  98.7).
    (a) You must calculate the mass of CO2 stored in
association with CO2-EOR (mstored) in the
reporting year by subtracting the mass of CO2 loss from
operations and the mass of CO2 loss from the EOR complex
from the total mass of CO2 input (as specified in Equation
VV-1 of this section).
[GRAPHIC] [TIFF OMITTED] TP21JN22.063

Where:

mstored = the annual quantity of associated storage in
metric tons of CO2 mass.
minput = the total mass of CO2
mreceived by the EOR project plus mnative (see
Clause 8.3 and paragraph (c) of this section), metric tons. Native
CO2 produced and captured in the CO2-EOR
project (mnative) can be quantified and included in
minput.
mloss operations = the total mass of CO2 loss
from project operations (see Clauses 8.4.1 through 8.4.5 and
paragraph (d) of this section), metric tons.
mloss EOR complex = the total mass of CO2 loss
from the EOR complex (see Clause 8.4.6), metric tons.

    (b) The manner by which associated storage is quantified must
assure completeness and preclude double counting. The annual mass of
CO2 that is recycled and reinjected into the EOR complex
must not be quantified as associated storage. Loss from the
CO2 recycling facilities must be quantified.
    (c) You must quantify the total mass of CO2 input
(minput) in the reporting year according to paragraphs
(c)(1) through (3) of this section.
    (1) You must include the total mass of CO2 received at
the custody transfer meter by the CO2-EOR project
(mreceived).
    (2) The CO2 stream received (including CO2
transferred from another CO2-EOR project) must be metered.
    (i) The native CO2 recovered and included as
mnative must be documented.
    (ii) CO2 delivered to multiple CO2-EOR
projects must be allocated among those CO2-EOR projects.
    (3) The sum of the quantities of allocated CO2 must not
exceed the total quantities of CO2 received.
    (d) You must calculate the total mass of CO2 from
project operations (mloss operations) in the reporting year
as specified in Equation VV-2 of this section.

[GRAPHIC] [TIFF OMITTED] TP21JN22.066

Where:

mloss leakage facilities = Loss of CO2 due to
leakage from production, handling, and recycling CO2-EOR
facilities (infrastructure including wellheads), metric tons.
mloss vent/flare = Loss of CO2 from venting/
flaring from production operations, metric tons.
mloss entrained = Loss of CO2 due to
entrainment within produced gas/oil/water when this CO2
is not separated and reinjected, metric tons.
mloss transfer = Loss of CO2 due to any
transfer of CO2 outside the CO2-EOR project,
metric tons. You must quantify any CO2 that is
subsequently produced from the EOR complex and transferred offsite.

Sec.  98.484  Monitoring and QA/QC requirements.

    You must use the applicable monitoring and quality assurance
requirements set forth in Clause 6.2 of CSA/ANSI ISO 27916:2019
(incorporated by reference, see Sec.  98.7).

Sec.  98.485  Procedures for estimating missing data.

    Whenever the value of a parameter is unavailable or the quality
assurance procedures set forth in Sec.  98.484 cannot be followed, you
must follow the procedures set forth in Clause 9.2 of CSA/ANSI ISO
27916:2019 (incorporated by reference, see Sec.  98.7).

Sec.  98.486  Data reporting requirements.

    In addition to the information required by Sec.  98.3(c), the
annual report shall contain the following information, as applicable:
    (a) The annual quantity of associated storage in metric tons of
CO2 (mstored).
    (b) The density of CO2 if volumetric units are converted
to mass in order to be reported for annual quantity of CO2
stored.
    (c) The annual quantity of CO2 input (minput)
and the information in paragraphs (c)(1) and (2) of this section.
    (1) The annual total mass of CO2 received at the custody
transfer meter by the CO2-EOR project, including
CO2 transferred from another CO2-EOR project
(mreceived).
    (2) The annual mass of native CO2 produced and captured
in the CO2-EOR project (mnative).
    (d) The annual mass of CO2 that is recycled and
reinjected into the EOR complex.
    (e) The annual total mass of CO2 loss from project
operations (mloss operations), and the information in
paragraphs (e)(1) through (4) of this section.
    (1) Loss of CO2 due to leakage from production,
handling, and recycling CO2-EOR facilities (infrastructure
including wellheads) (mloss leakage facilities).
    (2) Loss of CO2 from venting/flaring from production
operations (mloss vent/flare).
    (3) Loss of CO2 due to entrainment within produced gas/
oil/water when this CO2 is not separated and reinjected
(mloss entrained).
    (4) Loss of CO2 due to any transfer of CO2
outside the CO2-EOR project (mloss transfer).
    (f) The total mass of CO2 loss from the EOR complex
(mloss EOR complex).
    (g) Annual documentation that contains the following components as
described in Clause 4.4 of CSA/ANSI ISO 27916:2019 (incorporated by
reference, see Sec.  98.7):
    (1) The formulas used to quantify the annual mass of associated
storage, including the mass of CO2 delivered to the
CO2-EOR project and losses during the period covered by the
documentation (see Clause 8 and Annex B).
    (2) The methods used to estimate missing data and the amounts
estimated as described in Clause 9.2.
    (3) The approach and method for quantification utilized by the
operator, including accuracy, precision, and uncertainties (see Clause
8 and Annex B).
    (4) A statement describing the nature of validation or verification
including the date of review, process, findings, and responsible person
or entity.
    (5) Source of each CO2 stream quantified as associated
storage (see Clause 8.3).
    (6) A description of the procedures used to detect and characterize
the total CO2 leakage from the EOR complex.
    (7) If only the mass of anthropogenic CO2 is considered
for mstored, a description of the derivation and application
of anthropogenic CO2 allocation ratios for all the terms
described in Clauses 8.1 to 8.4.6.
    (8) Any documentation provided by a qualified independent engineer
or geologist, who certifies that the documentation provided, including
the mass balance calculations as well as information regarding
monitoring and containment assurance, is accurate and complete.
    (h) Any changes made within the reporting year to containment
assurance and monitoring approaches and procedures in the EOR
operations management plan.

Sec.  98.487  Records that must be retained.

    You must follow the record retention requirements specified by
Sec.  98.3(g). In addition to the records required by Sec.  98.3(g),
you must comply with the record retention requirements in Clause 9.1 of
CSA/ANSI ISO 27916:2019 (incorporated by reference, see Sec.  98.7).

Sec.  98.488  EOR Operations Management Plan.

    (a) You must prepare and update, as necessary, a general EOR
operations management plan that provides a description of the EOR
complex and engineered system (see Clause 4.3 (a)), establishes that
the EOR complex is adequate to provide safe, long-term containment of
CO2, and includes site-specific and other information
including:
    (1) Geologic characterization of the EOR complex.
    (2) A description of the facilities within the CO2-EOR
project.
    (3) A description of all wells and other engineered features in the
CO2-EOR project.
    (4) The operations history of the project reservoir.
    (5) The information set forth in Clauses 5 and 6 of CSA/ANSI ISO
27916:2019 (incorporated by reference, see Sec.  98.7).
    (b) You must prepare initial documentation at the beginning of the
quantification period, and include the following as described in the
EOR operations management plan:
    (1) A description of the EOR complex and engineered systems (see
Clause 5).
    (2) The initial containment assurance (see Clause 6.1.2).
    (3) The monitoring program (see Clause 6.2).
    (4) The quantification method to be used (see Clause 8 and Annex
B).
    (5) The total mass of previously injected CO2 (if any)
within the EOR complex at the beginning of the CO2-EOR
project (see Clause 8.5 and Annex B).
    (c) The EOR operation management plan in paragraph (a) of this
section and initial documentation in paragraph (b) of this section must
be submitted to the Administrator with the annual report covering the
first reporting year that the facility reports under this subpart. In
addition, any documentation provided by a qualified independent
engineer or geologist, who certifies that the documentation provided is
accurate and complete, must also be provided to the Administrator.
    (d) If the EOR operations management plan is updated, the updated
EOR management plan must be submitted to the Administrator with the
annual report covering the first reporting year for which the updated
EOR operation management plan is applicable.

Sec.  98.489  Definitions.

    Except as provided in paragraphs (a) and (b) of this section, all
terms used in this subpart have the same meaning given in the Clean Air
Act and subpart A of this part.
    (a) Additional terms and definitions are provided in Clause 3 of
CSA/ANSI ISO 27916:2019 (incorporated by reference, see Sec.  98.7).
    (b) All references in this subpart preceded by the word Clause
refer to the Clauses in CSA/ANSI ISO 27916:2019.

[FR Doc. 2022-09660 Filed 6-17-22; 8:45 am]
BILLING CODE 6560-50-P


[Federal Register Volume 74, Number 115 (Wednesday, June 17, 2009)]
[Notices]
[Pages 28771-28772]
[FR Doc No: E9-14233]

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

DEPARTMENT OF TRANSPORTATION

Federal Aviation Administration

[Summary Notice No. PE-2009-23]

Petition for Exemption; Summary of Petition Received

AGENCY: Federal Aviation Administration (FAA), DOT.

ACTION: Notice of petition for exemption received.

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

SUMMARY: This notice contains a summary of a petition seeking relief
from specified requirements of 14 CFR. The purpose of this notice is to
improve the public's awareness of, and participation in, this aspect of
FAA's regulatory activities. Neither publication of this notice nor the
inclusion or omission of information in the summary is intended to
affect the legal status of the petition or its final disposition.

DATE: Comments on this petition must identify the petition docket
number involved and must be received on or before July 17, 2009.

ADDRESSES: You may send comments identified by Docket Number FAA-2009-
0291 using any of the following methods:
     Government-wide rulemaking Web site: Go to http://www.regulations.gov and follow the instructions for sending your
comments electronically.
     Mail: Send comments to the Docket Management Facility;
U.S. Department of Transportation (DOT), 1200 New Jersey Avenue, SE.,
West Building Ground Floor, Room W12-140, Washington, DC 20590.
     Fax: Fax comments to the Docket Management Facility at
202-493-2251.
     Hand Delivery: Bring comments to the Docket Management
Facility in

Room W12-140 of the West Building Ground Floor at 1200 New Jersey
Avenue, SE., Washington, DC, between 9 a.m. and 5 p.m., Monday through
Friday, except Federal holidays.
    Privacy: We will post all comments we receive, without change, to
http://www.regulations.gov, including any personal information you
provide. Using the search function of our docket Web site, anyone can
find and read the comments received into any of our dockets, including
the name of the individual sending the comment (or signing the comment
for an association, business, labor union, etc.). You may review DOT's
complete Privacy Act Statement in the Federal Register published on
April 11, 2000 (65 FR 19477-78).
    Docket: To read background documents or comments received, go to
http://www.regulations.gov at any time or to the Docket Management
Facility in Room W12-140 of the West Building Ground Floor at 1200 New
Jersey Avenue, SE., Washington, DC, between 9 a.m. and 5 p.m., Monday
through Friday, except Federal holidays.

FOR FURTHER INFORMATION CONTACT Laverne Brunache<PHONE_NUMBER> or
Tyneka Thomas<PHONE_NUMBER>, Office of Rulemaking, Federal Aviation
Administration, 800 Independence Avenue, SW., Washington, DC 20591.
    This notice is published pursuant to 14 CFR 11.85.

    Issued in Washington, DC, on June 12, 2009.
Pamela Hamilton-Powell,
Director, Office of Rulemaking.

Petition for Exemption

    Docket No.: FAA-2009-0291.
    Petitioner: Embry-Riddle.
    Section of 14 CFR Affected: 14 CFR 141.77(c)(2).
    Description of Relief Sought: Embry-Riddle has petitioned the
Federal Aviation Administration to permit 100 percent of their students
from their part 142 training center to transfer to an equivalent
curriculum under their part 141 pilot school certificate.

[FR Doc. E9-14233 Filed 6-16-09; 8:45 am]
BILLING CODE 4910-13-P


[Federal Register Volume 82, Number 131 (Tuesday, July 11, 2017)]
[Proposed Rules]
[Pages 31928-31929]
[FR Doc No: 2017-14483]

========================================================================
Proposed Rules
                                                Federal Register
________________________________________________________________________

This section of the FEDERAL REGISTER contains notices to the public of
the proposed issuance of rules and regulations. The purpose of these
notices is to give interested persons an opportunity to participate in
the rule making prior to the adoption of the final rules.

========================================================================

Federal Register / Vol. 82, No. 131 / Tuesday, July 11, 2017 /
Proposed Rules

DEPARTMENT OF HOMELAND SECURITY

Coast Guard

33 CFR Chapter I

46 CFR Chapters I and III

49 CFR Chapter IV

[Docket No. USCG-2017-0656]

Commercial Fishing Safety Advisory Committee--Input To Support
Regulatory Reform of Coast Guard Regulations--New Task

AGENCY: U.S. Coast Guard, Department of Homeland Security.

ACTION: Announcement of new task assignment for the Commercial Fishing
Safety Advisory Committee (CFSAC); teleconference meeting.

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

SUMMARY: The U.S. Coast Guard is issuing a new task to the Commercial
Fishing Safety Advisory Committee (CFSAC). The U.S. Coast Guard is
asking CFSAC to help the agency identify existing regulations,
guidance, and collections of information (that fall within the scope of
the Committee's charter) for possible repeal, replacement, or
modification. This tasking is in response to the issuance of Executive
Orders 13771, ``Reducing Regulation and Controlling Regulatory Costs;
13777, ``Enforcing the Regulatory Reform Agenda;'' and 13783,
``Promoting Energy Independence and Economic Growth.'' The full
Committee is scheduled to meet by teleconference on July 27, 2017, to
discuss this tasking. This teleconference will be open to the public.
The U.S. Coast Guard will consider CFSAC recommendations as part of the
process of identifying regulations, guidance, and collections of
information to be repealed, replaced, or modified pursuant to the three
Executive Orders discussed above.

DATES: The full Committee is scheduled to meet by teleconference on
July 27, 2017, from 1 p.m. to 2 p.m. EDT. Please note that this
teleconference may adjourn early if the Committee has completed its
business.

ADDRESSES: To join the teleconference or to request special
accommodations, contact the individual listed in the FOR FURTHER
INFORMATION CONTACT section no later than 1 p.m. on July 24, 2017. The
number of teleconference lines is limited and will be available on a
first-come, first-served basis.
    Instructions: Submit comments on the task statement at any time,
including orally at the teleconference, but if you want Committee
members to review your comments before the teleconference, please
submit your comments no later than July 24, 2017. You must include the
words ``Department of Homeland Security'' and the docket number for
this action. Written comments may also be submitted using the Federal
e-Rulemaking Portal at http://www.regulations.gov. If you encounter
technical difficulties with comment submission, contact the individual
listed in the FOR FURTHER INFORMATION CONTACT section of this notice.
Comments received will be posted without alteration at http://www.regulations.gov, including any personal information provided. You
may review Regulations.gov's Privacy and Security Notice at https://www.regulations.gov/privacyNotice.
    Docket Search: For access to the docket or to read documents or
comments related to this notice, go to http://www.regulations.gov,
insert ``USCG-2017-0656'' in the Search box, press Enter, and then
click on the item you wish to view.

FOR FURTHER INFORMATION CONTACT: Mr. Jack Kemerer, Alternate Designated
Federal Officer of the Commercial Fishing Safety Advisory Committee,
(202) 372-1249, or email<EMAIL_ADDRESS>or Mr. Jonathan
Wendland, telephone<PHONE_NUMBER>, or email
<EMAIL_ADDRESS>
SUPPLEMENTARY INFORMATION:

New Task to the Committee

    The U.S. Coast Guard is issuing a new task to CFSAC to provide
recommendations on whether existing regulations, guidance, and
information collections (that fall within the scope of the Committee's
charter) should be repealed, replaced, or modified. CFSAC will then
provide advice and recommendations on the assigned task and submit a
final recommendation report to the U.S. Coast Guard.

Background

    On January 30, 2017, President Trump issued Executive Order 13771,
``Reducing Regulation and Controlling Regulatory Costs.'' Under that
Executive Order, for every one new regulation issued, at least two
prior regulations must be identified for elimination, and the cost of
planned regulations must be prudently managed and controlled through a
budgeting process. On February 24, 2017, the President issued Executive
Order 13777, ``Enforcing the Regulatory Reform Agenda.'' That Executive
Order directs agencies to take specific steps to identify and alleviate
unnecessary regulatory burdens placed on the American people. On March
28, 2017, the President issued Executive Order 13783, ``Promoting
Energy Independence and Economic Growth.'' Executive Order 13783
promotes the clean and safe development of our Nation's vast energy
resources, while at the same time avoiding agency actions that
unnecessarily encumber energy production.
    When implementing the regulatory offsets required by Executive
Order 13771, each agency head is directed to prioritize, to the extent
permitted by law, those regulations that the agency's Regulatory Reform
Task Force identifies as outdated, unnecessary, or ineffective in
accordance with Executive Order 13777. As part of this process to
comply with all three Executive Orders, the U.S. Coast Guard is
reaching out through multiple avenues to interested individuals to
gather their input about what regulations, guidance, and information
collections, they believe may need to be repealed, replaced, or
modified. On June 8, 2017, the U.S. Coast Guard issued a general notice
in the Federal Register requesting comments from interested individuals
regarding their recommendations, 82 FR 26632. In addition to this
general solicitation, the U.S. Coast Guard also wants to leverage the
expertise of its Federal Advisory Committees and is issuing similar
tasks to each of its Committees. A detailed discussion of each of the
Executive orders and information on where U.S. Coast Guard regulations,
guidance, and information

collections are found is in the June 8th notice.

The Task

    CFSAC is tasked to:
    Provide input to the U.S. Coast Guard on all existing regulations,
guidance, and information collections that fall within the scope of the
Committee's charter.
    1. One or more subcommittees/working groups, as needed, will be
established to work on this tasking in accordance with the Committee
charter and bylaws. The subcommittee(s) shall terminate upon the
approval and submission of a final recommendation to the U.S. Coast
Guard from the parent Committee.
    2. Review regulations, guidance, and information collections and
provide recommendations whether an existing rule, guidance, or
information collection should be repealed, replaced or modified. If the
Committee recommends modification, please provide specific
recommendations for how the regulation, guidance, or information
collection should be modified. Recommendations should include an
explanation on how and to what extent repeal, replacement or
modification will reduce costs or burdens to industry and the extent to
which risks to health or safety would likely increase.
    a. Identify regulations, guidance, or information collections that
potentially impose the following types of burden on the industry:
    i. Regulations, guidance, or information collections imposing
administrative burdens on the industry.
    ii. Regulations, guidance, or information collections imposing
burdens in the development or use of domestically produced energy
resources. ``Burden,'' for the purposes of compliance with Executive
Order 13783, means ``to unnecessarily obstruct, delay, curtail, or
otherwise impose significant costs on the siting, permitting,
production, utilization, transmission, or delivery of energy
resources.''
    b. Identify regulations, guidance, or information collections that
potentially impose the following types of costs on the industry:
    i. Regulations, guidance, or information collections imposing costs
that are outdated (such as due to technological advancement), or are no
longer necessary.
    ii. Regulations, guidance, or information collections imposing
costs which are no longer enforced as written or which are ineffective.
    iii. Regulations, guidance, or information collections imposing
costs tied to reporting or recordkeeping requirements that impose
burdens that exceed benefits. Explain why the reporting or
recordkeeping requirement is overly burdensome, unnecessary, or how it
could be modified.
    c. Identify regulations, guidance, and information collections that
the Committee believes have led to the elimination of jobs or inhibits
job creation within a particular industry.
    3. All regulations, guidance, and information collections, or parts
thereof, recommended by the Committee should be described in sufficient
detail (by section, paragraph, sentence, clause, etc.) so that it can
readily be identified. Data (quantitative or qualitative) should be
provided to support and illustrate the impact, cost, or burden, as
applicable, for each recommendation. If the data is not readily
available, the Committee should include information as to how such
information can be obtained either by the Committee or directly by the
Coast Guard.

Public Participation

    All meetings associated with this tasking, both full Committee
meetings and subcommittee/working groups, are open to the public. A
public oral comment period will be held during the July 27, 2017,
teleconference. Public comments or questions will be taken at the
discretion of the Designated Federal Officer; commenters are requested
to limit their comments to 3 minutes. Please contact the individual
listed in the FOR FURTHER INFORMATION CONTACT section, to register as a
commenter. Subcommittee meetings held in association with this tasking
will be announced as they are scheduled through notices posted to
http://homeport.uscg.mil/cfivsac and uploaded as supporting documents
in the electronic docket for this action, [USCG-2017-0656], at
Regulations.gov.

J.F. Williams,
Captain, U.S. Coast Guard, Director of Inspections and Compliance.
[FR Doc. 2017-14483 Filed 7-10-17; 8:45 am]
 BILLING CODE 9110-04-P