(2) 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 (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.
    (c) If you previously met the source category definition for
subpart UU for your CO2-EOR project and then began using
CSA/ANSI ISO 27916:2019 as a method of quantifying geologic
sequestration of CO2 in association with CO2-EOR
operations during a reporting year, you must report under subpart UU
for the portion of the year before you began using CSA/ANSI ISO
27916:2019 and report under subpart VV for the portion of the year
after you began using CSA/ANSI ISO 27916:2019.

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] TP22MY23.012

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
(g)(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.
    (A) The native CO2 recovered and included as
mnative must be documented.
    (B) 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] TP22MY23.013

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) and
incorporated herein by reference.
    (b) All references in this subpart preceded by the word Clause
refer to the Clauses in CSA/ANSI ISO 27916:2019.
0
45. Add subpart WW to read as follows:
Subpart WW--Coke Calciners
Sec.
98.490 Definition of source category.
98.491 Reporting threshold.
98.492 GHGs to report.
98.493 Calculating GHG emissions.
98.494 Monitoring and QA/QC requirements.
98.495 Procedures for estimating missing data.
98.496 Data reporting requirements.
98.497 Records that must be retained.
98.498 Definitions.

Sec.  98.490  Definition of source category.

    (a) A coke calciner is a process unit that heats petroleum coke to
high temperatures in the absence of air or oxygen for the purpose of
removing impurities or volatile substances in the petroleum coke
feedstock.
    (b) This source category consists of rotary kilns, rotary hearth
furnaces, or similar process units used to calcine petroleum coke and
also includes afterburners or other emission control systems used to
treat the coke calcining unit's process exhaust gas.

Sec.  98.491  Reporting threshold.

    You must report GHG emissions under this subpart if your facility
contains a coke calciner and the facility meets the requirements of
either Sec.  98.2(a)(1) or (2).

Sec.  98.492  GHGs to report.

    You must report:
    (a) CO2, CH4, and N2O emissions
from each coke calcining unit under this subpart.

    (b) CO2, CH4, and N2O emissions
from auxiliary fuel used in the coke calcining unit and afterburner, if
applicable, or other control system used to treat the coke calcining
unit's process off-gas under subpart C of this part (General Stationary
Fuel Combustion Sources) by following the requirements of subpart C.

Sec.  98.493  Calculating GHG emissions.

    (a) Calculate GHG emissions required to be reported in Sec.
98.492(a) using the applicable methods in paragraph (b) of this
section.
    (b) For each coke calcining unit, calculate GHG emissions according
to the applicable provisions in paragraphs (b)(1) through (4) of this
section.
    (1) If you operate and maintain a CEMS that measures CO2
emissions according to subpart C of this part, you must calculate and
report CO2 emissions under this subpart by following the
Tier 4 Calculation Methodology specified in Sec.  98.33(a)(4) and all
associated requirements for Tier 4 in subpart C of this part (General
Stationary Fuel Combustion Sources). Auxiliary fuel use CO2
emissions should be calculated in accordance with subpart C of this
part and subtracted from the CO2 CEMS emissions to determine
process CO2 emissions. Other coke calcining units must
either install a CEMS that complies with the Tier 4 Calculation
Methodology in subpart C of this part or follow the requirements of
paragraph (b)(2) of this section.
    (2) Calculate the CO2 emissions from the coke calcining
unit using monthly measurements and Equation WW-1 of this section.
[GRAPHIC] [TIFF OMITTED] TP22MY23.014

Where:

CO2 = Annual CO2 emissions (metric tons
CO2/year).
m = Month index.
Min,m = Mass of green coke fed to the coke calcining unit
in month ``m'' from facility records (metric tons/year).
CCGC.m = Mass fraction carbon content of green coke fed
to the coke calcining unit from facility measurement data in month
``m'' (metric ton carbon/metric ton green coke). If measurements are
made more frequently than monthly, determine the monthly average as
the arithmetic average for all measurements made during the calendar
month.
Mout,m = Mass of marketable petroleum coke produced by
the coke calcining unit in month ``m'' from facility records (metric
tons petroleum coke/year).
Mdust,m = Mass of petroleum coke dust removed from the
process through the dust collection system of the coke calcining
unit in month ``m'' from facility records (metric ton petroleum coke
dust/year). For coke calcining units that recycle the collected
dust, the mass of coke dust removed from the process is the mass of
coke dust collected less the mass of coke dust recycled to the
process.
CCMPC,m = Mass fraction carbon content of marketable
petroleum coke produced by the coke calcining unit in month ``m''
from facility measurement data (metric ton carbon/metric ton
petroleum coke). If measurements are made more frequently than
monthly, determine the monthly average as the arithmetic average for
all measurements made during the calendar month.
44 = Molecular weight of CO2 (kg/kg-mole).
12 = Atomic weight of C (kg/kg-mole).

    (3) Calculate CH4 emissions using Equation WW-2 of this
section.
[GRAPHIC] [TIFF OMITTED] TP22MY23.015

Where:

CH4 = Annual methane emissions (metric tons
CH4/year).
CO2 = Annual CO2 emissions calculated in
paragraph (b)(1) or (2) of this section, as applicable (metric tons
CO2/year).
EmF1 = Default CO2 emission factor for
petroleum coke from Table C-1 of subpart C of this part (General
Stationary Fuel Combustion Sources) (kg CO2/MMBtu).
EmF2 = Default CH4 emission factor for
``Petroleum Products (All fuel types in Table C-1)'' from Table C-2
of subpart C of this part (General Stationary Fuel Combustion
Sources) (kg CH4/MMBtu).

    (4) Calculate N2O emissions using Equation WW-3 of this
section.
    (Eq. WW-3)
    [GRAPHIC] [TIFF OMITTED] TP22MY23.016

Where:

N2O = Annual nitrous oxide emissions (metric tons
N2O/year).
CO2 = Annual CO2 emissions calculated in
paragraph (b)(1) or (2) of this section, as applicable (metric tons
CO2/year).
EmF1 = Default CO2 emission factor for
petroleum coke from Table C-1 of subpart C of this part (General
Stationary Fuel Combustion Sources) (kg CO2/MMBtu).
EmF3 = Default N2O emission factor for
``Petroleum Products (All fuel types in Table C-1)'' from Table C-2
of subpart C of this part (kg N2O/MMBtu).

Sec.  98.494  Monitoring and QA/QC requirements.

    (a) Flow meters, gas composition monitors, and heating value
monitors that are associated with sources that use a CEMS to measure
CO2 emissions according to subpart C of this part or that
are associated with stationary combustion sources must meet the
applicable monitoring and QA/QC requirements in Sec.  98.34.
    (b) Determine the mass of petroleum coke monthly as required by
Equation WW-1 of this subpart using mass measurement equipment meeting
the requirements for commercial weighing equipment as described in
Specifications, Tolerances, and Other Technical Requirements For
Weighing and Measuring Devices, NIST Handbook 44 (2022) (incorporated
by reference, see Sec.  98.7). Calibrate the measurement device
according to the procedures specified by NIST handbook 44 (incorporated
by reference, see Sec.  98.7) or the procedures specified by the
manufacturer. Recalibrate either biennially or at the minimum frequency
specified by the manufacturer.
    (c) Determine the carbon content of petroleum coke as required by
Equation WW-1 of this subpart using any one of the following methods.
Calibrate the measurement device according to procedures specified by
the method or procedures specified by the measurement device
manufacturer.
    (1) ASTM D3176-15 Standard Practice for Ultimate Analysis of Coal
and Coke (incorporated by reference, see Sec.  98.7).
    (2) ASTM D5291-16 Standard Test Methods for Instrumental
Determination of Carbon, Hydrogen, and Nitrogen in Petroleum Products
and Lubricants (incorporated by reference, see Sec.  98.7).
    (3) ASTM D5373-21 Standard Test Methods for Determination of
Carbon, Hydrogen, and Nitrogen in Analysis Samples of Coal and Carbon
in Analysis

Samples of Coal and Coke (incorporated by reference, see Sec.  98.7).
    (d) The owner or operator shall document the procedures used to
ensure the accuracy of the monitoring systems used including but not
limited to calibration of weighing equipment, flow meters, and other
measurement devices. The estimated accuracy of measurements made with
these devices shall also be recorded.

Sec.  98.495  Procedures for estimating missing data.

    A complete record of all measured parameters used in the GHG
emissions calculations is required (e.g., concentrations, flow rates,
fuel heating values, carbon content values). Therefore, whenever a
quality-assured value of a required parameter is unavailable (e.g., if
a CEMS malfunctions during unit operation or if a required sample is
not taken), a substitute data value for the missing parameter shall be
used in the calculations.
    (a) For missing auxiliary fuel use data, use the missing data
procedures in subpart C of this part.
    (b) For each missing value of mass or carbon content of coke,
substitute the arithmetic average of the quality-assured values of that
parameter immediately preceding and immediately following the missing
data incident. If the ``after'' value is not obtained by the end of the
reporting year, you may use the ``before'' value for the missing data
substitution. If, for a particular parameter, no quality-assured data
are available prior to the missing data incident, the substitute data
value shall be the first quality-assured value obtained after the
missing data period.
    (c) For missing CEMS data, you must use the missing data procedures
in Sec.  98.35.

Sec.  98.496  Data reporting requirements.

    In addition to the reporting requirements of Sec.  98.3(c), you
must report the information specified in paragraphs (a) through (i) of
this section for each coke calcining unit.
    (a) The unit ID number (if applicable).
    (b) Maximum rated throughput of the unit, in metric tons coke
calcined/stream day.
    (c) The calculated CO2, CH4, and
N2O annual process emissions, expressed in metric tons of
each pollutant emitted.
    (d) A description of the method used to calculate the
CO2 emissions for each unit (e.g., CEMS or Equation WW-1).
    (e) Annual mass of green coke fed to the coke calcining unit from
facility records (metric tons/year).
    (f) Annual mass of marketable petroleum coke produced by the coke
calcining unit from facility records (metric tons/year).
    (g) Annual mass of petroleum coke dust removed from the process
through the dust collection system of the coke calcining unit from
facility records (metric tons/year) and an indication of whether coke
dust is recycled to the unit (e.g., all dust is recycled, a portion of
the dust is recycled, or none of the dust is recycled).
    (h) Annual average mass fraction carbon content of green coke fed
to the coke calcining unit from facility measurement data (metric tons
C per metric ton green coke).
    (i) Annual average mass fraction carbon content of marketable
petroleum coke produced by the coke calcining unit from facility
measurement data (metric tons C per metric ton petroleum coke).

Sec.  98.497  Records that must be retained.

    In addition to the records required by Sec.  98.3(g), you must
retain the records specified in paragraphs (a) and (b) of this section.
    (a) The records of all parameters monitored under Sec.  98.494.
    (b) Verification software records. You must keep a record of the
file generated by the verification software specified in Sec.  98.5(b)
for the applicable data specified in paragraphs (b)(1) through (5) of
this section. Retention of this file satisfies the recordkeeping
requirement for the data in paragraphs (b)(1) through (5) of this
section.
    (1) Monthly mass of green coke fed to the coke calcining unit from
facility records (metric tons/year) (Equation WW-1 of Sec.  98.493).
    (2) Monthly mass of marketable petroleum coke produced by the coke
calcining unit from facility records (metric tons/year) (Equation WW-
1).
    (3) Monthly mass of petroleum coke dust removed from the process
through the dust collection system of the coke calcining unit from
facility records (metric tons/year) (Equation WW-1).
    (4) Average monthly mass fraction carbon content of green coke fed
to the coke calcining unit from facility measurement data (metric tons
C per metric ton green coke) (Equation WW-1).
    (5) Average monthly mass fraction carbon content of marketable
petroleum coke produced by the coke calcining unit from facility
measurement data (metric tons C per metric ton petroleum coke)
(Equation WW-1).

Sec.  98.498  Definitions.

    All terms used in this subpart have the same meaning given in the
Clean Air Act and subpart A of this part.
0
46. Add subpart XX to read as follows:
Subpart XX--Calcium Carbide Production
Sec.
98.500 Definition of the source category.
98.501 Reporting threshold.
98.502 GHGs to report.
98.503 Calculating GHG emissions.
98.504 Monitoring and QA/QC requirements.
98.505 Procedures for estimating missing data.
98.506 Data reporting requirements.
98.507 Records that must be retained.
98.508 Definitions.

Sec.  98.500  Definition of the source category.

    The calcium carbide production source category consists of any
facility that produces calcium carbide.

Sec.  98.501  Reporting threshold.

    You must report GHG emissions under this subpart if your facility
contains a calcium carbide production process and the facility meets
the requirements of either Sec.  98.2(a)(1) or (2).

Sec.  98.502  GHGs to report.

    You must report:
    (a) Process CO2 emissions from each calcium carbide
process unit or furnace used for the production of calcium carbide.
    (b) CO2, CH4, and N2O emissions
from each stationary combustion unit following the requirements of
subpart C of this part. You must report these emissions under subpart C
of this part (General Stationary Fuel Combustion Sources) by following
the requirements of subpart C.

Sec.  98.503  Calculating GHG emissions.

    You must calculate and report the annual process CO2
emissions from each calcium carbide process unit not subject to
paragraph (c) of this section using the procedures in either paragraph
(a) or (b) of this section.
    (a) Calculate and report under this subpart the combined process
and combustion CO2 emissions by operating and maintaining
CEMS according to the Tier 4 Calculation Methodology in Sec.
98.33(a)(4) and all associated requirements for Tier 4 in subpart C of
this part (General Stationary Fuel Combustion Sources).
    (b) Calculate and report under this subpart the annual process
CO2 emissions from the calcium carbide process unit using
the carbon mass balance procedure specified in paragraphs (b)(1) and
(2) of this section.
    (1) For each calcium carbide process unit, determine the annual
mass of carbon in each carbon-containing input and output material for
the calcium carbide process unit and estimate annual process
CO2 emissions from the

calcium carbide process unit using Equation XX-1 of this section.
Carbon-containing input materials include carbon electrodes and
carbonaceous reducing agents. If you document that a specific input or
output material contributes less than 1 percent of the total carbon
into or out of the process, you do not have to include the material in
your calculation using Equation XX-1 of this section.
[GRAPHIC] [TIFF OMITTED] TP22MY23.017

[GRAPHIC] [TIFF OMITTED] TP22MY23.018

Where:

ECO2 = Annual process CO2 emissions from an
individual calcium carbide process unit (metric tons).
44/12 = Ratio of molecular weights, CO2 to carbon.
2000/2205 = Conversion factor to convert tons to metric tons.
Mreducing agenti = Annual mass of reducing agent i fed,
charged, or otherwise introduced into the calcium carbide process
unit (tons).
Creducing agenti = Carbon content in reducing agent i
(percent by weight, expressed as a decimal fraction).
Melectrodem = Annual mass of carbon electrode m consumed
in the calcium carbide process unit (tons).
Celectrodem = Carbon content of the carbon electrode m
(percent by weight, expressed as a decimal fraction).
Mproduct outgoingk = Annual mass of alloy product k
tapped from the calcium carbide process unit (tons).
Cproduct outgoingk = Carbon content in alloy product k
(percent by weight, expressed as a decimal fraction).
Mnon-product outgoingl = Annual mass of non-product
outgoing material l removed from the calcium carbide unit (tons).
Cnon-product outgoingl = Carbon content in non-product
outgoing material l (percent by weight, expressed as a decimal
fraction).

    (2) Determine the combined annual process CO2 emissions
from the calcium carbide process units at your facility using Equation
XX-2 of this section.
[GRAPHIC] [TIFF OMITTED] TP22MY23.019

Where:

CO2 = Annual process CO2 emissions from
calcium carbide process units at a facility used for the production
of calcium carbide (metric tons).
ECO2k = Annual process CO2 emissions
calculated from calcium carbide process unit k calculated using
Equation XX-1 of this section (metric tons).
k = Total number of calcium carbide process units at facility.

    (c) If all GHG emissions from a calcium carbide process unit are
vented through the same stack as any combustion unit or process
equipment that reports CO2 emissions using a CEMS that
complies with the Tier 4 Calculation Methodology in subpart C of this
part (General Stationary Fuel Combustion Sources), then the calculation
methodology in paragraph (b) of this section must not be used to
calculate process emissions. The owner or operator must report under
this subpart the combined stack emissions according to the Tier 4
Calculation Methodology in Sec.  98.33(a)(4) and all associated
requirements for Tier 4 in subpart C of this part.

Sec.  98.504  Monitoring and QA/QC requirements.

    If you determine annual process CO2 emissions using the
carbon mass balance procedure in Sec.  98.503(b), you must meet the
requirements specified in paragraphs (a) and (b) of this section.
    (a) Determine the annual mass for each material used for the
calculations of annual process CO2 emissions using Equation
XX-1 of this subpart by summing the monthly mass for the material
determined for each month of the calendar year. The monthly mass may be
determined using plant instruments used for accounting purposes,
including either direct measurement of the quantity of the material
placed in the unit or by calculations using process operating
information.
    (b) For each material identified in paragraph (a) of this section,
you must determine the average carbon content of the material consumed,
used, or produced in the calendar year using the methods specified in
either paragraph (b)(1) or (2) of this section. If you document that a
specific process input or output contributes less than one percent of
the total mass of carbon into or out of the process, you do not have to
determine the monthly mass or annual carbon content of that input or
output.
    (1) Information provided by your material supplier.
    (2) Collecting and analyzing at least three representative samples
of the material inputs and outputs each year. The carbon content of the
material must be analyzed at least annually using the standard methods
(and their QA/QC procedures) specified in paragraphs (b)(2)(i) and (ii)
of this section, as applicable.
    (i) ASTM D5373-08 Standard Test Methods for Instrumental
Determination of Carbon, Hydrogen, and Nitrogen in Laboratory Samples
of Coal (incorporated by reference, see Sec.  98.7), for analysis of
carbonaceous reducing agents and carbon electrodes.
    (ii) ASTM C25-06, Standard Test Methods for Chemical Analysis of
Limestone, Quicklime, and Hydrated Lime (incorporated by reference, see
Sec.  98.7) for analysis of materials such as limestone or dolomite.

Sec.  98.505  Procedures for estimating missing data.

    A complete record of all measured parameters used in the GHG
emissions calculations in Sec.  98.503 is required. Therefore, whenever
a quality-assured value of a required parameter is unavailable, a
substitute data value for the missing parameter must be used in the
calculations as specified in the paragraphs (a) and (b) of this
section. You must document and keep records of the procedures used for
all such estimates.

    (a) If you determine CO2 emissions for the calcium
carbide process unit at your facility using the carbon mass balance
procedure in Sec.  98.503(b), 100 percent data availability is required
for the carbon content of the input and output materials. You must
repeat the test for average carbon contents of inputs according to the
procedures in Sec.  98.504(b) if data are missing.
    (b) For missing records of the monthly mass of carbon-containing
inputs and outputs, the substitute data value must be based on the best
available estimate of the mass of the inputs and outputs from all
available process data or data used for accounting purposes, such as
purchase records.

Sec.  98.506  Data reporting requirements.

    In addition to the information required by Sec.  98.3(c), each
annual report must contain the information specified in paragraphs (a)
through (h) of this section, as applicable:
    (a) Annual facility calcium carbide production capacity (tons).
    (b) The annual facility production of calcium carbide (tons).
    (c) Total number of calcium carbide process units at facility used
for production of calcium carbide.
    (d) Annual facility consumption of petroleum coke (tons).
    (e) Each end use of any calcium carbide produced and sent off site.
    (f) If the facility produces acetylene on site, provide the
information in paragraphs (f)(1), (2), and (3) of this section.
    (1) The annual production of acetylene at the facility (tons).
    (2) The annual quantity of calcium carbide used for the production
of acetylene at the facility (tons).
    (3) Each end use of any acetylene produced on-site.
    (g) If a CEMS is used to measure CO2 emissions, then you
must report under this subpart the relevant information required by
Sec.  98.36 for the Tier 4 Calculation Methodology and the information
specified in paragraphs (g)(1) and (2) of this section.
    (1) Annual CO2 emissions (in metric tons) from each
calcium carbide process unit.
    (2) Identification number of each process unit.
    (h) If a CEMS is not used to measure CO2 process
emissions, and the carbon mass balance procedure is used to determine
CO2 emissions according to the requirements in Sec.
98.503(b), then you must report the information specified in paragraphs
(h)(1) through (3) of this section.
    (1) Annual process CO2 emissions (in metric tons) from
each calcium carbide process unit.
    (2) List the method used for the determination of carbon content
for each input and output material included in the calculation of
annual process CO2 emissions for each calcium carbide
process unit (e.g., supplier provided information, analyses of
representative samples you collected).
    (3) If you use the missing data procedures in Sec.  98.505(b), you
must report for each calcium carbide production process unit how
monthly mass of carbon-containing inputs and outputs with missing data
were determined and the number of months the missing data procedures
were used.

Sec.  98.507  Records that must be retained.

    In addition to the records required by Sec.  98.3(g), you must
retain the records specified in paragraphs (a) through (d) of this
section for each calcium carbide process unit, as applicable.
    (a) If a CEMS is used to measure CO2 emissions according
to the requirements in Sec.  98.503(a), then you must retain under this
subpart the records required for the Tier 4 Calculation Methodology in
Sec.  98.37 and the information specified in paragraphs (a)(1) through
(3) of this section.
    (1) Monthly calcium carbide process unit production quantity
(tons).
    (2) Number of calcium carbide processing unit operating hours each
month.
    (3) Number of calcium carbide processing unit operating hours in a
calendar year.
    (b) If the carbon mass balance procedure is used to determine
CO2 emissions according to the requirements in Sec.
98.503(b)(2), then you must retain records for the information
specified in paragraphs (b)(1) through (5) of this section.
    (1) Monthly calcium carbide process unit production quantity
(tons).
    (2) Number of calcium carbide process unit operating hours each
month.
    (3) Number of calcium carbide process unit operating hours in a
calendar year.
    (4) Monthly material quantity consumed, used, or produced for each
material included for the calculations of annual process CO2
emissions (tons).
    (5) Average carbon content determined and records of the supplier
provided information or analyses used for the determination for each
material included for the calculations of annual process CO2
emissions.
    (c) You must keep records that include a detailed explanation of
how company records of measurements are used to estimate the carbon
input and output to each calcium carbide process unit, including
documentation of specific input or output materials excluded from
Equation XX-1 of this subpart that contribute less than 1 percent of
the total carbon into or out of the process. You also must document the
procedures used to ensure the accuracy of the measurements of materials
fed, charged, or placed in a calcium carbide process unit including,
but not limited to, calibration of weighing equipment and other
measurement devices. The estimated accuracy of measurements made with
these devices must also be recorded, and the technical basis for these
estimates must be provided.
    (d) Verification software records. You must keep a record of the
file generated by the verification software specified in Sec.  98.5(b)
for the applicable data specified in paragraphs (d)(1) through (13) of
this section. Retention of this file satisfies the recordkeeping
requirement for the data in paragraphs (d)(1) through (8) of this
section.
    (1) Carbon content in reducing agent (percent by weight, expressed
as a decimal fraction) (Equation XX-1 of Sec.  98.503).
    (2) Annual mass of reducing agent fed, charged, or otherwise
introduced into the calcium carbide process unit (tons) (Equation XX-
1).
    (3) Carbon content of carbon electrode (percent by weight,
expressed as a decimal fraction) (Equation XX-1).
    (4) Annual mass of carbon electrode consumed in the calcium carbide
process unit (tons) (Equation XX-1).
    (5) Carbon content in product (percent by weight, expressed as a
decimal fraction) (Equation XX-1).
    (6) Annual mass of product produced/tapped in the calcium carbide
process unit (tons) (Equation XX-1).
    (7) Carbon content in non-product outgoing material (percent by
weight, expressed as a decimal fraction) (Equation XX-1).
    (8) Annual mass of non-product outgoing material removed from
calcium carbide process unit (tons) (Equation XX-1).

Sec.  98.508  Definitions.

    All terms used of this subpart have the same meaning given in the
Clean Air Act and subpart A of this part.
0
47. Add subpart YY to read as follows:
Subpart YY--Caprolactam, Glyoxal, and Glyoxylic Acid Production
Sec.
98.510 Definition of source category.
98.511 Reporting threshold.
98.512 GHGs to report.
98.513 Calculating GHG emissions.
98.514 Monitoring and QA/QC requirements.

98.515 Procedures for estimating missing data.
98.516 Data reporting requirements.
98.517 Records that must be retained.
98.518 Definitions.

Sec.  98.510  Definition of source category.

    This source category includes any facility that produces
caprolactam, glyoxal, or glyoxylic acid. This source category excludes
the production of glyoxal through the LaPorte process (i.e., the gas-
phase catalytic oxidation of ethylene glycol with air in the presence
of a silver or copper catalyst).

Sec.  98.511  Reporting threshold.

    You must report GHG emissions under this subpart if your facility
meets the requirements of either Sec.  98.2(a)(1) or (2) and the
definition of source category in Sec.  98.510.

Sec.  98.512  GHGs to report.

    (a) You must report N2O process emissions from the
production of caprolactam, glyoxal, and glyoxylic acid as required by
this subpart.
    (b) You must report under subpart C of this part (General
Stationary Fuel Combustion Sources) the emissions of CO2,
CH4, and N2O from each stationary combustion unit
by following the requirements of subpart C.

Sec.  98.513  Calculating GHG emissions.

    (a) You must determine annual N2O process emissions from
each caprolactam, glyoxal, and glyoxylic acid process line using the
appropriate default N2O generation factor(s) from Table YY-1
to this subpart, the site-specific N2O destruction factor(s)
for each N2O abatement device, and site-specific production
data according to paragraphs (b) through (e) of this section.
    (b) You must determine the total annual amount of product i
(caprolactam, glyoxal, or glyoxylic acid) produced on each process line
t (metric tons product), according to Sec.  98.514(b).
    (c) If process line t exhausts to any N2O abatement
technology j, you must determine the destruction efficiency for each
N2O abatement technology according to paragraph (c)(1) or
(2) of this section.
    (1) Use the control device manufacturer's specified destruction
efficiency.
    (2) Estimate the destruction efficiency through process knowledge.
Examples of information that could constitute process knowledge include
calculations based on material balances, process stoichiometry, or
previous test results provided the results are still relevant to the
current vent stream conditions. You must document how process knowledge
(if applicable) was used to determine the destruction efficiency.
    (d) If process line t exhausts to any N2O abatement
technology j, you must determine the abatement utilization factor for
each N2O abatement technology according to paragraph (d)(1)
or (2) of this section.
    (1) If the abatement technology j has no downtime during the year,
use 1.
    (2) If the abatement technology j was not operational while product
i was being produced on process line t, calculate the abatement
utilization factor according to Equation YY-1 of this subpart.
[GRAPHIC] [TIFF OMITTED] TP22MY23.020

Where:

AFj = Monthly abatement utilization factor of
N2O abatement technology j from process unit t (fraction
of time that abatement technology is operating).
Ti = Total number of hours during month that product i
(caprolactam, glyoxal, or glyoxylic acid), was produced from process
unit t (hours).
Ti,j = Total number of hours during month that product i
(caprolactam, glyoxal, or glyoxylic acid), was produced from process
unit t during which N2O abatement technology j was
operational (hours).

    (e) You must calculate N2O emissions for each product i
from each process line t and each N2O control technology j
according to Equation YY-2 of this subpart.
[GRAPHIC] [TIFF OMITTED] TP22MY23.021

Where:

EN2Ot = Monthly process emissions of N2O,
metric tons (mt) from process line t.
EFi = N2O generation factor for product i
(caprolactam, glyoxal, or glyoxylic acid), kg N2O/mt of
product produced, as shown in Table YY-1 to this subpart.
Pi = Monthly production of product i, (caprolactam,
glyoxal, or glyoxylic acid), mt.
DEj = Destruction efficiency of N2O abatement
technology type j, fraction (decimal fraction of N2O
removed from vent stream).
AFj = Monthly abatement utilization factor for
N2O abatement technology type j, fraction, calculated
using Equation YY-1 of this subpart.
0.001 = Conversion factor from kg to metric tons.

Sec.  98.514  Monitoring and QA/QC requirements.

    (a) You must determine the total monthly amount of caprolactam,
glyoxal, and glyoxylic acid produced. These monthly amounts are
determined according to the methods in paragraph (a)(1) or (2) of this
section.
    (1) Direct measurement of production (such as using flow meters,
weigh scales, etc.).
    (2) Existing plant procedures used for accounting purposes (i.e.,
dedicated tank-level and acid concentration measurements).
    (b) You must determine the annual amount of caprolactam, glyoxal,
and glyoxylic acid produced. These annual amounts are determined by
summing the respective monthly quantities determined in paragraph (a)
of this section.

Sec.  98.515  Procedures for estimating missing data.

    A complete record of all measured parameters used in the GHG
emissions calculations is required. Therefore, whenever a quality-
assured value of a required parameter is unavailable, a substitute data
value for the missing parameter must be used in the calculations as
specified in paragraphs (a) and (b) of this section.
    (a) For each missing value of caprolactam, glyoxal, or glyoxylic
acid production, the substitute data must be the best available
estimate based on all available process data or data used for
accounting purposes (such as sales records).
    (b) For missing values related to the N2O abatement
device, assuming that the operation is generally constant from year to
year, the substitute data value should be the most recent quality-
assured value.

Sec.  98.516  Data reporting requirements.

    In addition to the information required by Sec.  98.3(c), each
annual report must contain the information specified in paragraphs (a)
through (j) of this section.
    (a) Process line identification number.
    (b) Annual process N2O emissions from each process line
according to paragraphs (b)(1) through (3) of this section.
    (1) N2O from caprolactam production (metric tons).

    (2) N2O from glyoxal production (metric tons).
    (3) N2O from glyoxylic acid production (metric tons).
    (c) Annual production quantities from all process lines at the
caprolactam, glyoxal, or glyoxylic acid production facility according
to paragraphs (c)(1) through (3) of this section.
    (1) Caprolactam production (metric tons).
    (2) Glyoxal production (metric tons).
    (3) Glyoxylic acid production (metric tons).
    (d) Annual production capacity from all process lines at the
caprolactam, glyoxal, or glyoxylic acid production facility, as
applicable, in paragraphs (d)(1) through (3) of this section.
    (1) Caprolactam production capacity (metric tons).
    (2) Glyoxal production capacity (metric tons).
    (3) Glyoxylic acid production capacity (metric tons).
    (e) Number of process lines at the caprolactam, glyoxal, or
glyoxylic acid production facility, by product, in paragraphs (e)(1)
through (3) of this section.
    (1) Total number of process lines producing caprolactam.
    (2) Total number of process lines producing glyoxal.
    (3) Total number of process lines producing glyoxylic acid.
    (f) Number of operating hours in the calendar year for each process
line at the caprolactam, glyoxal, or glyoxylic acid production facility
(hours).
    (g) N2O abatement technologies used (if applicable) and
date of installation of abatement technology at the caprolactam,
glyoxal, or glyoxylic acid production facility.
    (h) Monthly abatement utilization factor for each N2O
abatement technology at the caprolactam, glyoxal, or glyoxylic acid
production facility.
    (i) Number of times in the reporting year that missing data
procedures were followed to measure production quantities of
caprolactam, glyoxal, or glyoxylic acid (months).
    (j) Annual percent N2O emission reduction per chemical
produced at the caprolactam, glyoxal, or glyoxylic acid production
facility, as applicable, in paragraphs (j)(1) through (3) of this
section.
    (1) Annual percent N2O emission reduction for
caprolactam production.
    (2) Annual percent N2O emission reduction for glyoxal
production.
    (3) Annual percent N2O emission reduction for glyoxylic
acid production.

Sec.  98.517  Records that must be retained.

    In addition to the information required by Sec.  98.3(g), you must
retain the records specified in paragraphs (a) through (d) of this
section for each caprolactam, glyoxal, or glyoxylic acid production
facility:
    (a) Documentation of how accounting procedures were used to
estimate production rate.
    (b) Documentation of how process knowledge was used to estimate
abatement technology destruction efficiency (if applicable).
    (c) Documentation of the procedures used to ensure the accuracy of
the measurements of all reported parameters, including but not limited
to, calibration of weighing equipment, flow meters, and other
measurement devices. The estimated accuracy of measurements made with
these devices must also be recorded, and the technical basis for these
estimates must be provided.
    (d) You must keep a record of the file generated by the
verification software specified in Sec.  98.5(b) for the applicable
data specified in paragraphs (d)(1) through (3) of this section.
Retention of this file satisfies the recordkeeping requirement for the
data in paragraphs (d)(1) through (3) of this section.
    (1) Monthly production quantity of caprolactam from all process
lines at the caprolactam, glyoxal, or glyoxylic acid production
facility.
    (2) Monthly production quantity of glyoxal from all process lines
at the caprolactam, glyoxal, or glyoxylic acid production facility.
    (3) Monthly production quantity of glyoxylic acid from all process
lines at the caprolactam, glyoxal, or glyoxylic acid production
facility.

Sec.  98.518  Definitions.

    All terms used in this subpart have the same meaning given in the
Clean Air Act and subpart A of this part.

       Table YY-1 to Subpart YY of Part 98--N2O Generation Factors
------------------------------------------------------------------------
                                                         N2O generation
                        Product                            factor \a\

------------------------------------------------------------------------
Caprolactam...........................................               9.0
Glyoxal...............................................             5,200
Glyoxylic acid........................................             1,000
------------------------------------------------------------------------
\a\ Generation factors in units of kilograms of N2O emitted per metric
  ton of product produced.

0
48. Add subpart ZZ to read as follows:
Subpart ZZ--Ceramics Manufacturing
Sec.
98.520 Definition of the source category.
98.521 Reporting threshold.
98.522 GHGs to report.
98.523 Calculating GHG emissions.
98.524 Monitoring and QA/QC requirements.
98.525 Procedures for estimating missing data.
98.526 Data reporting requirements.
98.527 Records that must be retained.
98.528 Definitions.

Sec.  98.520  Definition of the source category.

    (a) The ceramics manufacturing source category consists of any
facility that uses nonmetallic, inorganic materials, many of which are
clay-based, to produce ceramic products such as bricks and roof tiles,
wall and floor tiles, table and ornamental ware (household ceramics),
sanitary ware, refractory products, vitrified clay pipes, expanded clay
products, inorganic bonded abrasives, and technical ceramics (e.g.,
aerospace, automotive, electronic, or biomedical applications). For the
purposes of this subpart, ceramics manufacturing processes include
facilities that annually consume at least 2,000 tons of carbonates or
20,000 tons of clay, which is heated to a temperature sufficient to
allow the calcination reaction to occur, and operate a ceramics
manufacturing process unit.
    (b) A ceramics manufacturing process unit is a kiln, dryer, or oven
used to calcine clay or other carbonate-based materials for the
production of a ceramics product.

Sec.  98.521  Reporting threshold.

    You must report GHG emissions under this subpart if your facility
contains a ceramics manufacturing process and the facility meets the
requirements of either Sec.  98.2(a)(1) or (2).

Sec.  98.522  GHGs to report.

    You must report:
    (a) CO2 process emissions from each ceramics process
unit (e.g., kiln, dryer, or oven).
    (b) CO2 combustion emissions from each ceramics process
unit.
    (c) CH4 and N2O combustion emissions from
each ceramics process unit. You must calculate and report these
emissions under subpart C of this part (General Stationary Fuel
Combustion Sources) by following the requirements of subpart C of this
part.
    (d) CO2, CH4, and N2O combustion
emissions from each stationary fuel combustion unit other than kilns,
dryers, or ovens. You must report these emissions under subpart C of
this part (General Stationary Fuel Combustion Sources) by following the
requirements of subpart C of this part.

Sec.  98.523  Calculating GHG emissions.

    You must calculate and report the annual process CO2
emissions from each ceramics process unit using the procedures in
paragraphs (a) through (c) of this section.

    (a) For each ceramics process unit that meets the conditions
specified in Sec.  98.33(b)(4)(ii) or (iii), you must calculate and
report under this subpart the combined process and combustion
CO2 emissions by operating and maintaining a CEMS to measure
CO2 emissions according to the Tier 4 Calculation
Methodology specified in Sec.  98.33(a)(4) and all associated
requirements for Tier 4 in subpart C of this part (General Stationary
Fuel Combustion Sources).
    (b) For each ceramics process unit that is not subject to the
requirements in paragraph (a) of this section, calculate and report the
process and combustion CO2 emissions from the ceramics
process unit separately by using the procedures specified in paragraphs
(b)(1) through (6) of this section, except as specified in paragraph
(c) of this section.
    (1) For each carbonate-based raw material charged to the ceramics
process unit, either obtain the mass fractions of any carbonate-based
minerals from the supplier of the raw material or by sampling the raw
material, or use a default value of 1.0 as the mass fraction for the
raw material.
    (2) Determine the quantity of each carbonate-based raw material
charged to the ceramics process unit.
    (3) Apply the appropriate emission factor for each carbonate-based
raw material charged to the ceramics process unit. Table ZZ-1 to this
subpart provides emission factors based on stoichiometric ratios for
carbonate-based minerals.
    (4) Use Equation ZZ-1 of this section to calculate process mass
emissions of CO2 for each ceramics process unit:
[GRAPHIC] [TIFF OMITTED] TP22MY23.022

Where:

ECO2 = Annual process CO2 emissions (metric
tons/year).
MFi = Annual average decimal mass fraction of carbonate-
based mineral i in carbonate-based raw material j.
Mj = Annual mass of the carbonate-based raw material j
consumed (tons/year).
2000/2205 = Conversion factor to convert tons to metric tons.
EFi = Emission factor for the carbonate-based mineral i,
(metric tons CO2/metric ton carbonate, see Table ZZ-1 of
this subpart).
Fi = Decimal fraction of calcination achieved for
carbonate-based mineral i, assumed to be equal to 1.0.
i = Index for carbonate-based mineral in each carbonate-based raw
material.
j = Index for carbonate-based raw material.

    (5) Determine the combined annual process CO2 emissions
from the ceramic process units at your facility using Equation ZZ-2 of
this subpart:
[GRAPHIC] [TIFF OMITTED] TP22MY23.023

Where:

CO2 = Annual process CO2 emissions from
ceramic process units at a facility (metric tons).
ECO2k = Annual process CO2 emissions
calculated from ceramic process unit k calculated using Equation ZZ-
1 of this subpart (metric tons).
k = Total number of ceramic process units at facility.

    (6) Calculate and report under subpart C of this part (General
Stationary Fuel Combustion Sources) the combustion CO2
emissions in the ceramics process unit according to the applicable
requirements in subpart C of this part.
    (c) As an alternative to data provided by either the raw material
supplier or a lab analysis, a value of 1.0 can be used for the mass
fraction (MFi) of carbonate-based mineral i in each
carbonate-based raw material j in Equation ZZ-1 of this subpart. The
use of 1.0 for the mass fraction assumes that the carbonate-based raw
material comprises 100% of one carbonate-based mineral.

Sec.  98.524  Monitoring and QA/QC requirements.

    (a) You must measure annual amounts of carbonate-based raw
materials charged to each ceramics process unit from monthly
measurements using plant instruments used for accounting purposes, such
as calibrated scales or weigh hoppers. Total annual mass charged to
ceramics process units at the facility must be compared to records of
raw material purchases for the year.
    (b) Unless you use the default value of 1.0 for the mass fraction
of a carbonate-based mineral, you must measure carbonate-based mineral
mass fractions at least annually to verify the mass fraction data
provided by the supplier of the raw material; such measurements must be
based on sampling and chemical analysis using consensus standards that
specify X-ray fluorescence.
    (c) Unless you use the default value of 1.0 for the mass fraction
of a carbonate-based mineral, you must determine the annual average
mass fraction for the carbonate-based mineral in each carbonate-based
raw material by calculating an arithmetic average of the monthly data
obtained from raw material suppliers or sampling and chemical analysis.
    (d) Unless you use the default value of 1.0 for the calcination
fraction of a carbonate-based mineral, you must determine on an annual
basis the calcination fraction for each carbonate-based mineral
consumed based on sampling and chemical analysis using an industry
consensus standard. If performed, this chemical analysis must be
conducted using an x-ray fluorescence test or other enhanced testing
method published by an industry consensus standards organization (e.g.,
ASTM, ASME, API, etc.).

Sec.  98.525  Procedures for estimating missing data.

    A complete record of all measured parameters used in the GHG
emissions calculations in Sec.  98.523 is required. If the monitoring
and quality assurance procedures in Sec.  98.524 cannot be followed and
data is unavailable, you must use the most appropriate of the missing
data procedures in paragraphs (a) and (b) of this section in the
calculations. You must document and keep records of the procedures used
for all such missing value estimates.
    (a) If the CEMS approach is used to determine combined process and
combustion CO2 emissions, the missing data procedures in
Sec.  98.35 apply.
    (b) For missing data on the monthly amounts of carbonate-based raw
materials charged to any ceramics process unit, use the best available
estimate(s) of the parameter(s) based on all available process data or
data used for accounting purposes, such as purchase records.
    (c) For missing data on the mass fractions of carbonate-based
minerals in the carbonate-based raw materials, assume that the mass
fraction of a carbonate-based mineral is 1.0, which assumes that one
carbonate-based mineral comprises 100 percent of the carbonate-based
raw material.

Sec.  98.526  Data reporting requirements.

    In addition to the information required by Sec.  98.3(c), each
annual report must contain the information specified in paragraphs (a)
through (c) of this section, as applicable:
    (a) The total number of ceramics process units at the facility and
the number of units that operated during the reporting year.

    (b) If a CEMS is used to measure CO2 emissions from
ceramics process units, then you must report under this subpart the
relevant information required under Sec.  98.36 for the Tier 4
Calculation Methodology and the following information specified in
paragraphs (b)(1) through (3) of this section.
    (1) The annual quantity of each carbonate-based raw material
charged to each ceramics process unit and for all units combined
(tons).
    (2) Annual quantity of each type of ceramics product manufactured
by each ceramics process unit and by all units combined (tons).
    (3) Annual production capacity for each ceramics process unit
(tons).
    (c) If a CEMS is not used to measure CO2 emissions from
ceramics process units and process CO2 emissions are
calculated according to the procedures specified in Sec.  98.523(b),
then you must report the following information specified in paragraphs
(c)(1) through (7) of this section.
    (1) Annual process emissions of CO2 (metric tons) for
each ceramics process unit and for all units combined.
    (2) The annual quantity of each carbonate-based raw material
charged to all units combined (tons).
    (3) Results of all tests used to verify each carbonate-based
mineral mass fraction for each carbonate-based raw material charged to
a ceramics process unit, as specified in paragraphs (c)(3)(i) through
(iii) of this section.
    (i) Date of test.
    (ii) Method(s) and any variations used in the analyses.
    (iii) Mass fraction of each sample analyzed.
    (4) Method used to determine the decimal mass fraction of
carbonate-based mineral, unless you used the default value of 1.0
(e.g., supplier provided information, analyses of representative
samples you collected).
    (5) Annual quantity of each type of ceramics product manufactured
by each ceramics process unit and by all units combined (tons).
    (6) Annual production capacity for each ceramics process unit
(tons).
    (7) If you use the missing data procedures in Sec.  98.525(b), you
must report for each applicable ceramics process unit the number of
times in the reporting year that missing data procedures were followed
to measure monthly quantities of carbonate-based raw materials or mass
fraction of the carbonate-based minerals (months).

Sec.  98.527  Records that must be retained.

    In addition to the records required by Sec.  98.3(g), you must
retain the records specified in paragraphs (a) through (d) of this
section for each ceramics process unit, as applicable.
    (a) If a CEMS is used to measure CO2 emissions according
to the requirements in Sec.  98.523(a), then you must retain under this
subpart the records required under Sec.  98.37 for the Tier 4
Calculation Methodology and the information specified in paragraphs
(a)(1) and (2) of this section.
    (1) Monthly ceramics production rate for each ceramics process unit
(tons).
    (2) Monthly amount of each carbonate-based raw material charged to
each ceramics process unit (tons).
    (b) If process CO2 emissions are calculated according to
the procedures specified in Sec.  98.523(b), you must retain the
records in paragraphs (b)(1) through (6) of this section.
    (1) Monthly ceramics production rate for each ceramics process unit
(metric tons).
    (2) Monthly amount of each carbonate-based raw material charged to
each ceramics process unit (metric tons).
    (3) Data on carbonate-based mineral mass fractions provided by the
raw material supplier for all raw materials consumed annually and
included in calculating process emissions in Equation ZZ-1 of this
subpart, if applicable.
    (4) Results of all tests, if applicable, used to verify the
carbonate-based mineral mass fraction for each carbonate-based raw
material charged to a ceramics process unit, including the data
specified in paragraphs (b)(4)(i) through (v) of this section.
    (i) Date of test.
    (ii) Method(s), and any variations of methods, used in the
analyses.
    (iii) Mass fraction of each sample analyzed.
    (iv) Relevant calibration data for the instrument(s) used in the
analyses.
    (v) Name and address of laboratory that conducted the tests.
    (5) Each carbonate-based mineral mass fraction for each carbonate-
based raw material, if a value other than 1.0 is used to calculate
process mass emissions of CO2.
    (6) Number of annual operating hours of each ceramics process unit.
    (c) All other documentation used to support the reported GHG
emissions.
    (d) Verification software records. You must keep a record of the
file generated by the verification software specified in Sec.  98.5(b)
for the applicable data specified in paragraphs (d)(1) through (3) of
this section. Retention of this file satisfies the recordkeeping
requirement for the data in paragraphs (d)(1) through (3) of this
section.
    (1) Annual average decimal mass fraction of each carbonate-based
mineral in each carbonate-based raw material for each ceramics process
unit (specify the default value, if used, or the value determined
according to Sec.  98.524) (percent by weight, expressed as a decimal
fraction) (Equation ZZ-1 of Sec.  98.523).
    (2) Annual mass of each carbonate-based raw material charged to
each ceramics process unit (tons) (Equation ZZ-1 of this subpart).
    (3) Decimal fraction of calcination achieved for each carbonate-
based raw material for each ceramics process unit (specify the default
value, if used, or the value determined according to Sec.  98.524)
(percent by weight, expressed as a decimal fraction) (Equation ZZ-1 of
this subpart).

Sec.  98.528  Definitions.

    All terms used of this subpart have the same meaning given in the
Clean Air Act and subpart A of this part.

Table ZZ-1 to Subpart ZZ of Part 98--CO2 Emission Factors for Carbonate-
                           Based Raw Materials
------------------------------------------------------------------------
                                                 CO2 emission factor \a\
          Carbonate            Mineral name(s)
------------------------------------------------------------------------
BaCO3........................  Witherite,                          0.223
                                Barium
                                carbonate.
CaCO3........................  Limestone,                          0.440
                                Calcium
                                Carbonate,
                                Calcite,
                                Aragonite.
Ca(Fe,Mg,Mn)(CO3)2...........  Ankerite \b\...               0.408-0.476
CaMg(CO3)2...................  Dolomite.......                     0.477
FeCO3........................  Siderite.......                     0.380
K2CO3........................  Potassium                           0.318
                                carbonate.
Li2CO3.......................  Lithium                             0.596
                                carbonate.
MgCO3........................  Magnesite......                     0.522
MnCO3........................  Rhodochrosite..                     0.383
Na2CO3.......................  Sodium                              0.415
                                carbonate,
                                Soda ash.

SrCO3........................  Strontium                           0.298
                                carbonate,
                                Strontianite.
------------------------------------------------------------------------
\a\ Emission factors are in units of metric tons of CO2 emitted per
  metric ton of carbonate-based mineral.
\b\ Ankerite emission factors are based on a formula weight range that
  assumes Fe, Mg, and Mn are present in amounts of at least 1.0 percent.

[FR Doc. 2023-10047 Filed 5-19-23; 8:45 am]
BILLING CODE 6560-50-P


[Federal Register: May 8, 2008 (Volume 73, Number 90)]
[Notices]
[Page 26106]
[DOCID:fr08my08-76]

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DEPARTMENT OF ENERGY

Federal Energy Regulatory Commission

[Docket No. ER08-650-000]

Mountain Wind Power, LLC; Notice of Issuance of Order

April 30, 2008.
    Mountain Wind Power, LLC (Mountain Wind) filed an application for
market-based rate authority, with an accompanying rate tariff. The
proposed market-based rate tariff provides for the sale of energy and
capacity at market-based rates. Mountain Wind also requested waivers of
various Commission regulations. In particular, Mountain Wind requested
that the Commission grant blanket approval under 18 CFR Part 34 of all
future issuances of securities and assumptions of liability by Mountain
Wind.
    On April 9, 2008, pursuant to delegated authority, the Director,
Division of Tariffs and Market Development-West, granted the requests
for blanket approval under Part 34 (Director's Order). The Director's
Order also stated that the Commission would publish a separate notice
in the Federal Register establishing a period of time for the filing of
protests. Accordingly, any person desiring to be heard concerning the
blanket approvals of issuances of securities or assumptions of
liability by Mountain Wind, should file a protest with the Federal
Energy Regulatory Commission, 888 First Street, NE., Washington, DC
20426, in accordance with Rules 211 and 214 of the Commission's Rules
of Practice and Procedure. 18 CFR 385.211, 385.214 (2004). The
Commission encourages the electronic submission of protests using the
FERC Online link at http://www.ferc.gov.
    Notice is hereby given that the deadline for filing protests is May
9, 2008.
    Absent a request to be heard in opposition to such blanket
approvals by the deadline above, Mountain Wind is authorized to issue
securities and assume obligations or liabilities as a guarantor,
indorser, surety, or otherwise in respect of any security of another
person; provided that such issuance or assumption is for some lawful
object within the corporate purposes of Mountain Wind, compatible with
the public interest, and is reasonably necessary or appropriate for
such purposes.
    The Commission reserves the right to require a further showing that
neither public nor private interests will be adversely affected by
continued approvals of Mountain Wind's issuance of securities or
assumptions of liability.
    Copies of the full text of the Director's Order are available from
the Commission's Public Reference Room, 888 First Street, NE.,
Washington, DC 20426. The Order may also be viewed on the Commission's
Web site at http://www.ferc.gov, using the eLibrary link. Enter the
docket number excluding the last three digits in the docket number
filed to access the document. Comments, protests, and interventions may
be filed electronically via the Internet in lieu of paper. See 18 CFR
385.2001(a)(1)(iii) and the instructions on the Commission's Web site
under the ``e-Filing'' link. The Commission strongly encourages
electronic filings.

Kimberly D. Bose,
Secretary.
 [FR Doc. E8-10166 Filed 5-7-08; 8:45 am]

BILLING CODE 6717-01-P


[Federal Register Volume 77, Number 224 (Tuesday, November 20, 2012)]
[Proposed Rules]
[Pages 69572-69573]
[FR Doc No: 2012-28132]

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DEPARTMENT OF TRANSPORTATION

Federal Aviation Administration

14 CFR Part 25

[Docket No. FAA-2012-1215; Notice No. 25-12-12-SC]

Special Conditions: Embraer S.A., Model EMB-550 Airplanes; Flight
Envelope Protection: High Speed Limiting

AGENCY: Federal Aviation Administration (FAA), DOT.

ACTION: Notice of proposed special conditions.

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SUMMARY: This action proposes special conditions for the Embraer S.A.
Model EMB-550 airplane. This airplane will have a novel or unusual
design feature, specifically an electronic flight control system which
contains fly-by-wire control laws, including envelope protections, for
the overspeed protection and roll limiting function. The applicable
airworthiness regulations do not contain adequate or appropriate safety
standards for this design feature. These proposed special conditions
contain the additional safety standards that the Administrator
considers necessary to establish a level of safety equivalent to that
established by the existing airworthiness standards.

DATES: Send your comments on or before January 4, 2013.

ADDRESSES: Send comments identified by docket number FAA-2012-1215
using any of the following methods:
     Federal eRegulations Portal: Go to http://www.regulations.gov/ and follow the online instructions for sending
your comments electronically.
     Mail: Send comments to Docket Operations, M-30, U.S.
Department of Transportation (DOT), 1200 New Jersey Avenue SE., Room
W12-140, West Building Ground Floor, Washington, DC 20590-0001.
     Hand Delivery or Courier: Take comments to Docket
Operations in Room W12-140 of the West Building Ground Floor at 1200
New Jersey Avenue SE., Washington, DC, between 8 a.m. and 5 p.m.,
Monday through Friday, except federal holidays.
     Fax: Fax comments to Docket Operations at<PHONE_NUMBER>.
    Privacy: The FAA will post all comments it receives, without
change, to http://www.regulations.gov/, including any personal
information the commenter provides. Using the search function of the
docket Web site, anyone can find and read the electronic form of all
comments received into any FAA docket, including the name of the
individual sending the comment (or signing the comment for an
association, business, labor union, etc.). DOT's complete Privacy Act
Statement can be found in the Federal Register published on April 11,
2000 (65 FR 19477-19478), as well as at http://DocketsInfo.dot.gov/.
    Docket: Background documents or comments received may be read at
http://www.regulations.gov/ at any time. Follow the online instructions
for accessing the docket or go to the Docket Operations 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: Joe Jacobsen, FAA, Airplane and Flight
Crew Interface Branch, ANM-111, Transport Airplane Directorate,
Aircraft Certification Service, 1601 Lind Avenue SW., Renton,
Washington 98057-3356; telephone<PHONE_NUMBER>; facsimile<PHONE_NUMBER>.

SUPPLEMENTARY INFORMATION:

Comments Invited

    We invite interested people to take part in this rulemaking by
sending written comments, data, or views. The most helpful comments
reference a specific portion of the special conditions, explain the
reason for any recommended change, and include supporting data.
    We will consider all comments we receive on or before the closing
date for comments. We may change these special conditions based on the
comments we receive.

Background

    On May 14, 2009, Embraer S.A. applied for a type certificate for
their new Model EMB-550 airplane. The Model EMB-550 airplane is the
first of a new family of jet airplanes designed for corporate flight,
fractional, charter, and private owner operations. The aircraft has a
conventional configuration with a low wing and T-tail empennage. The
primary structure is metal with composite empennage and control
surfaces. The Model EMB-550 airplane is designed for 8 passengers, with
a maximum of 12 passengers. It is equipped with two Honeywell HTF7500-E
medium bypass ratio turbofan engines mounted on aft fuselage pylons.
Each engine produces approximately 6,540 pounds of thrust for normal
takeoff. The primary flight controls consist of hydraulically powered
fly-by-wire elevators, aileron and rudder, controlled by the pilot or
copilot sidestick.
    The longitudinal control law design of the Embraer S.A. Model EMB-
550 airplane incorporates an overspeed protection system in the normal
mode. This mode prevents the pilot from inadvertently or intentionally
exceeding a speed approximately equivalent to VFC or
attaining VDF. Current Title 14 Code of Federal Regulations
(14 CFR) part 25 do not relate to a high speed limiter that might
preclude or modify flying qualities assessments in the overspeed
region.

Type Certification Basis

    Under the provisions of 14 CFR 21.17, Embraer S.A. must show that
the Model EMB-550 airplane meets the applicable provisions of part 25,
as amended by Amendments 25-1 through 25-127 thereto.
    If the Administrator finds that the applicable airworthiness
regulations (i.e., 14 CFR part 25) do not contain adequate or
appropriate safety standards for the Model EMB-550 airplane because of
a novel or unusual design feature, special conditions are prescribed
under the provisions of Sec.  21.16.
    Special conditions are initially applicable to the model for which
they are issued. Should the type certificate for that model be amended
later to include any other model that incorporates the same or similar
novel or unusual design feature, the special conditions would also
apply to the other model under Sec.  21.101.
    In addition to the applicable airworthiness regulations and special
conditions, the Model EMB-550 airplane must comply with the fuel vent
and exhaust emission requirements of 14 CFR part 34 and the noise
certification requirements of 14 CFR part 36 and the FAA must issue a
finding of regulatory adequacy under Sec.  611 of Public Law 92-574,
the ``Noise Control Act of 1972.''
    The FAA issues special conditions, as defined in 14 CFR 11.19, in
accordance with Sec.  11.38, and they become part of the type-
certification basis under Sec.  21.17(a)(2).

Novel or Unusual Design Features

    The Model EMB-550 airplane will incorporate the following novel or
unusual design feature: An electronic flight control system which
contains fly-by-wire control laws, including envelope protections, for
the overspeed protection and roll limiting function. Current part 25
requirements do not contain appropriate standards for high speed
protection systems.

Discussion

    As further discussed previously, a special condition is necessary
in addition to the requirements of Sec.  25.143 for the operation of
the high speed protection. The general intent is that the overspeed
protection does not impede normal maneuvering and speed control and
that the overspeed protection does not restrict or prevent emergency
maneuvering. Therefore, these proposed special conditions contain the
additional safety standards that the Administrator considers necessary
to establish a level of safety equivalent to that established by the
existing airworthiness standards.

Applicability

    As discussed above, these special conditions are applicable to the
Model EMB-550 airplane. Should Embraer S.A. apply at a later date for a
change to the type certificate to include another model incorporating
the same novel or unusual design feature, the special conditions would
apply to that model as well.

Conclusion

    This action affects only certain novel or unusual design features
on one model of airplanes. It is not a rule of general applicability.

List of Subjects in 14 CFR Part 25

    Aircraft, Aviation safety, Reporting and recordkeeping
requirements.

    The authority citation for these special conditions is as follows:

    Authority:  49 U.S.C. 106(g), 40113, 44701, 44702, 44704.

The Proposed Special Conditions

    Accordingly, the Federal Aviation Administration (FAA) proposes the
following special conditions as part of the type certification basis
for Embraer S.A. Model EMB-550 airplanes.
    1. In addition to Sec.  25.143, the following requirement applies:
Operation of the high speed limiter during all routine and descent
procedure flight must not impede normal attainment of speeds up to
overspeed warning.

    Issued in Renton, Washington, on November 14, 2012.
Ali Bahrami,
Manager, Transport Airplane Directorate, Aircraft Certification
Service.
[FR Doc. 2012-28132 Filed 11-19-12; 8:45 am]
BILLING CODE 4910-13-P


[Federal Register Volume 81, Number 165 (Thursday, August 25, 2016)]
[Notices]
[Page 58550]
[FR Doc No: 2016-20015]

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DEPARTMENT OF TRANSPORTATION

Federal Aviation Administration

Agency Information Collection Activities: Requests for Comments;
Clearance of Renewed Approval of Information Collection: Aviation
Medical Examiner Program

AGENCY: Federal Aviation Administration (FAA), DOT.

ACTION: Notice and request for comments.

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SUMMARY: In accordance with the Paperwork Reduction Act of 1995, FAA
invites public comments about our intention to request the Office of
Management and Budget (OMB) approval to renew a previously approved
information collection. This collection is necessary in order to
determine applicants' qualifications for certification as Aviation
Medical Examiners (AMEs).

DATES: Written comments should be submitted by October 24, 2016.

ADDRESSES: Send comments to the FAA at the following address: Ronda
Thompson, Room 441, Federal Aviation Administration, ASP-110, 950
L'Enfant Plaza SW., Washington, DC 20024.
    Public Comments Invited: You are asked to comment on any aspect of
this information collection, including (a) Whether the proposed
collection of information is necessary for FAA's performance; (b) the
accuracy of the estimated burden; (c) ways for FAA to enhance the
quality, utility and clarity of the information collection; and (d)
ways that the burden could be minimized without reducing the quality of
the collected information. The agency will summarize and/or include
your comments in the request for OMB's clearance of this information
collection.

FOR FURTHER INFORMATION CONTACT: Ronda Thompson by email at:
<EMAIL_ADDRESS>
SUPPLEMENTARY INFORMATION:
    OMB Control Number: 2120-0604.
    Title: Aviation Medical Examiner Program.
    Form Numbers: FAA form 8520-2.
    Type of Review: Renewal of an information collection.
    Background: 14 CFR part 183 describes the requirements for
delegating to private physicians the authority to conduct physical
examinations on persons wishing to apply for their airmen medical
certificate. This collection of information is for the purpose of
obtaining essential information concerning the applicants' professional
and personal qualifications. The FAA uses the information to screen and
select the designees who serve as aviation medical examiners.
    Respondents: Approximately 450 applicants annually.
    Frequency: Information is collected on occasion.
    Estimated Average Burden per Response: 30 minutes.
    Estimated Total Annual Burden: 225 hours.

    Issued in Washington, DC, on August 17, 2016.
Ronda Thompson,
FAA Information Collection Clearance Officer, Performance, Policy, and
Records Management Branch, ASP-110.
[FR Doc. 2016-20015 Filed 8-24-16; 8:45 am]
 BILLING CODE 4910-13-P