definitions of the ``Energy Industry'' or ``Manufacturing Industries
  and Construction''. In all fuels except for coal the values for these
  two categories are identical. For coal combustion, those who fall
  within the IPCC ``Energy Industry'' category may employ a value of 1g
  of CH4/mmBtu.

* * * * *

Subpart E--[AMENDED]

0
8. Section 98.53 is amended by:
0
a. Revising paragraph (b)(3) and paragraph (d) introductory text.
0
b. Revising paragraph (e) and Equation E-2.
0
c. Revising the parameters ``DF'' and ``AF'' of Equation E-3a.
0
d. Revising the parameters ``DF1'', ``AF1'',
``DF2'', ``AF2'', ``DFN'', and
``AFN'' of Equation E-3b.
0
e. Revising the parameters ``DFN'', ``AFN'', and
``FCN'' of Equation E-3c.

Sec.  98.53  Calculating GHG emissions.

* * * * *
    (b) * * *
    (3) You must measure the adipic acid production rate during the
test and calculate the production rate for the test period in tons per
hour.
* * * * *
    (d) If the adipic acid production unit exhausts to any
N2O abatement technology ``N'', you must determine the
destruction efficiency according to paragraphs (d)(1), (d)(2), or
(d)(3) of this section.
* * * * *
    (e) If the adipic acid production unit exhausts to any
N2O abatement technology ``N'', you must determine the
annual amount of adipic acid produced while N2O abatement
technology ``N'' is operating according to Sec.  98.54(f). Then you
must calculate the abatement factor for N2O abatement
technology ``N'' according to Equation E-2 of this section.
[GRAPHIC] [TIFF OMITTED] TP02AP13.000

* * * * *
    (g) * * *
    (1) * * *
* * * * *

DF = Destruction efficiency of N2O abatement technology
``N'' (decimal fraction of N2O removed from vent stream).
AF = Abatement utilization factor of N2O abatement
technology ``N'' (decimal fraction of time that the abatement
technology is operating).

* * * * *
    (2) * * *
* * * * *
DF1 = Destruction efficiency of N2O abatement
technology 1 (decimal fraction of N2O removed from vent
stream).
AF1 = Abatement utilization factor of N2O
abatement technology 1 (decimal fraction of time that abatement
technology 1 is operating).
DF2 = Destruction efficiency of N2O abatement
technology 2 (decimal fraction of N2O removed from vent
stream).
AF2 = Abatement utilization factor of N2O
abatement technology 2 (decimal fraction of time that abatement
technology 2 is operating).
DFN = Destruction efficiency of N2O abatement
technology ``N'' (decimal fraction of N2O removed from
vent stream).
AFN = Abatement utilization factor of N2O
abatement technology ``N'' (decimal fraction of time that abatement
technology N is operating).

* * * * *
    (3) * * *
* * * * *
DFN = Destruction efficiency of N2O abatement
technology ``N'' (decimal fraction of N2O removed from
vent stream).
AFN = Abatement utilization factor of N2O
abatement technology ``N'' (decimal fraction of time that the
abatement technology is operating).
FCN = Fraction control factor of N2O abatement
technology ``N'' (decimal fraction of total emissions from unit
``z'' that are sent to abatement technology ``N'').

* * * * *
0
9. Section 98.54 is amended by revising paragraphs (e) and (f) to read
as follows:

Sec.  98.54  Monitoring and QA/QC requirements.

* * * * *
    (e) You must determine the monthly amount of adipic acid produced.
You must also determine the monthly amount of adipic acid produced
during which N2O abatement technology is operating. These
monthly amounts are determined according to the methods in paragraphs
(c)(1) or (c)(2) of this section.
    (f) You must determine the annual amount of adipic acid produced.
You must also determine the annual amount of adipic acid produced
during which N2O abatement technology is operating. These
are determined by summing the respective monthly adipic acid production
quantities determined in paragraph (e) of this section.

Subpart G--[AMENDED]

0
10. Section 98.73 is amended by:
0
a. Revising paragraph (b)(4) introductory text and revising Equation G-
4.
0
b. Revising Equation G-5 and by removing parameter ``n'' of Equation G-
5 and adding in its place parameter ``j''.

Sec.  98.73  Calculating GHG emissions.

* * * * *
    (b) * * *
    (4) You must calculate the annual process CO2 emissions
from each ammonia processing unit k at your facility according to
Equation G-4 of this section:
[GRAPHIC] [TIFF OMITTED] TN02AP13.015

* * * * *
    (5) * * *

[GRAPHIC] [TIFF OMITTED] TN02AP13.016

* * * * *

j = Total number of ammonia processing units.

* * * * *
0
11. Section 98.75 is amended by revising paragraph (b) to read as
follows:

Sec.  98.75  Procedures for estimating missing data.

* * * * *
    (b) For missing feedstock supply rates used to determine monthly
feedstock consumption or monthly waste recycle stream quantity, you
must determine the best available estimate(s) of the parameter(s),
based on all available process data.
0
12. Section 98.76 is amended by revising paragraphs (a) introductory
text, (b) introductory text, and (b)(13) to read as follows:

Sec.  98.76  Data reporting requirements.

* * * * *
    (a) If a CEMS is used to measure CO2 emissions, then you
must report the relevant information required under Sec.  98.36 for the
Tier 4 Calculation Methodology and the information in paragraphs (a)(1)
and (a)(2) of this section:
* * * * *
    (b) If a CEMS is not used to measure emissions, then you must
report all of the following information in this paragraph (b):
* * * * *
    (13) Annual CO2 emissions (metric tons) from the steam
reforming of a hydrocarbon or the gasification of solid and liquid raw
material at the ammonia manufacturing process unit used to produce urea
and the method used to determine the CO2 consumed in urea
production.

Subpart H--[AMENDED]

0
13. Section 98.86 is amended by revising paragraph (a)(2) to read as
follows:

Sec.  98.86  Data reporting requirements.

* * * * *
    (a) * * *
    (2) Annual facility cement production.
* * * * *

Subpart K--[AMENDED]

0
14. Section 98.113 is amended by revising Equation K-3 and by removing
the parameter ``2000/2205'' of Equation K-3 and adding in its place the
parameter ``2/2205'' to read as follows:

Sec.  98.113  Calculating GHG emissions.

* * * * *
    (d) * * *
    (1) * * *
    [GRAPHIC] [TIFF OMITTED] TP02AP13.001

* * * * *

2/2205 = Conversion factor to convert kg CH4/ton of
product to metric tons CH4.

* * * * *
0
15. Section 98.116 is amended by adding paragraph (e)(2) to read as
follows:

Sec.  98.116  Data reporting requirements.

* * * * *
    (e) * * *
    (2) Annual process CH4 emissions (in metric tons) from
each EAF used for the production of any ferroalloy listed in Table K-1
of this subpart.
* * * * *

Subpart L--[AMENDED]

0
16. Section 98.126 is amended by revising paragraphs (j) introductory
text, (j)(1), and (j)(3)(i) to read as follows:

Sec.  98.126  Data reporting requirements.

* * * * *
    (j) Special provisions for reporting years 2011, 2012, and 2013
only. For reporting years 2011, 2012, and 2013, the owner or operator
of a facility must comply with paragraphs (j)(1), (j)(2), and (j)(3) of
this section.
    (1) Timing. The owner or operator of a facility is not required to
report the data elements at Sec.  98.3(c)(4)(iii) and paragraphs
(a)(2), (a)(3), (a)(4), (a)(6), (b), (c), (d), (e), (f), (g), and (h)
of this section until the later of March 31, 2015 or the date set forth
for that data element at Sec.  98.3(c)(4)(vii) and Table A-7 of Subpart
A of this part.
* * * * *
    (3) * * *
    (i) If you choose to use a default GWP rather than your best
estimate of the GWP for fluorinated GHGs whose GWPs are not listed in
Table A-1 of Subpart A of this part, use a default GWP of 10,000 for
fluorinated GHGs that are fully fluorinated GHGs and use a default GWP
of 2000 for other fluorinated GHGs.
* * * * *

Subpart N--[AMENDED]

0
17. Section 98.143 is amended by:
0
a. Revising the introductory text.
0
b. Revising paragraph (b) introductory text.
0
c. Revising the parameters ``MFi'' and ``Fi'' of
Equation N-1.

Sec.  98.143  Calculating GHG emissions.

    You must calculate and report the annual process CO2
emissions from each continuous glass melting furnace using the
procedure in paragraphs (a) through (c) of this section.
* * * * *
    (b) For each continuous glass melting furnace that is not subject
to the requirements in paragraph (a) of this section, calculate and
report the process and combustion CO2 emissions from the
glass melting furnace by using either the procedure in paragraph (b)(1)
of this section or the procedure in paragraph (b)(2) of this section,
except as specified in paragraph (c) of this section.
* * * * *
    (2) * * *
    (iv) * * *
* * * * *

MFi = Annual average decimal mass fraction of carbonate-
based mineral i in carbonate-based raw material i.

* * * * *
Fi = Decimal fraction of calcination achieved for
carbonate-based raw material i, assumed to be equal to 1.0.

* * * * *
0
18. Section 98.144 is amended by revising paragraph (b) to read as
follows:

Sec.  98.144  Monitoring and QA/QC requirements.

* * * * *

    (b) 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 shall be based on
sampling and chemical analysis using consensus standards that specify
X-ray fluorescence. For measurements made in years prior to the
emissions reporting year 2014, you may also use ASTM D3682-01
(Reapproved 2006) Standard Test Method for Major and Minor Elements in
Combustion Residues from Coal Utilization Processes (incorporated by
reference, see Sec.  98.7) or ASTM D6349-09 Standard Test Method for
Determination of Major and Minor Elements in Coal, Coke, and Solid
Residues from Combustion of Coal and Coke by Inductively Coupled
Plasma--Atomic Emission Spectrometry (incorporated by reference, see
Sec.  98.7).
* * * * *
0
19. Section 98.146 is amended by revising paragraphs (b)(4), (b)(6),
and (b)(7) to read as follows:

Sec.  98.146  Data reporting requirements.

* * * * *
    (b) * * *
    (4) Carbonate-based mineral decimal mass fraction for each
carbonate-based raw material charged to a continuous glass melting
furnace.
* * * * *
    (6) The decimal fraction of calcination achieved for each
carbonate-based raw material, if a value other than 1.0 is used to
calculate process mass emissions of CO2.
    (7) Method used to determine decimal fraction of calcination.
* * * * *
0
20. Section 98.147 is amended by revising paragraph (b)(5) to read as
follows:

Sec.  98.147  Records that must be retained.

* * * * *
    (b) * * *
    (5) The decimal fraction of calcination achieved for each
carbonate-based raw material, if a value other than 1.0 is used to
calculate process mass emissions of CO2.
* * * * *

Subpart O--[AMENDED]

0
21. Section 98.153 is amended by:
0
a. Revising paragraph (c) introductory text.
0
b, Revising paragraph (d) introductory text.
0
c. Revising the parameter ``ED'' of Equation O-5.

Sec.  98.153  Calculating GHG emissions.

* * * * *
    (c) For HCFC-22 production facilities that do not use a destruction
device or that have a destruction device that is not directly connected
to the HCFC-22 production equipment, HFC-23 emissions shall be
estimated using Equation O-4 of this section:
* * * * *
    (d) For HCFC-22 production facilities that use a destruction device
connected to the HCFC-22 production equipment, HFC-23 emissions shall
be estimated using Equation O-5 of this section:
* * * * *

ED = Mass of HFC-23 emitted annually from destruction
device (metric tons), calculated using Equation O-8 of this section.

* * * * *
0
22. Section 98.154 is amended by revising paragraph (j) to read as
follows:

Sec.  98.154  Monitoring and QA/QC requirements.

* * * * *
    (j) The number of sources of equipment type t with screening values
less than 10,000 ppmv shall be the difference between the number of
leak sources of equipment type t that could emit HFC-23 and the number
of sources of equipment type t with screening values greater than or
equal to 10,000 ppmv as determined under paragraph (i) of this section.
* * * * *
0
23. Section 98.156 is amended by revising paragraph (c) to read as
follows:

Sec.  98.156  Data reporting requirements.

* * * * *
    (c) Each HFC-23 destruction facility shall report the concentration
(mass fraction) of HFC-23 measured at the outlet of the destruction
device during the facility's annual HFC-23 concentration measurements
at the outlet of the device. If the concentration of HFC-23 is below
the detection limit of the measuring device, report the detection limit
and that the concentration is below the detection limit.
* * * * *

Subpart P--[AMENDED]

0
24. Section 98.163 is amended by:
0
a. Revising paragraph (b) introductory text.
0
b. Revising the parameters ``Fdstkn'', ``CCn'',
and ``MWn'' of Equation P-1.
0
c. Revising the parameters ``Fdstkn'' and ``CCn''
of Equation P-2.
0
d. Revising the parameters ``Fdstkn'' and ``CCn''
of Equation P-3.

Sec.  98.163  Calculating GHG emissions.

* * * * *
    (b) Fuel and feedstock material balance approach. Calculate and
report CO2 emissions as the sum of the annual emissions
associated with each fuel and feedstock used for hydrogen production by
following paragraphs (b)(1) through (b)(3) of this section. The carbon
content and molecular weight shall be obtained from the analyses
conducted in accordance with Sec.  98.164(b)(2), (b)(3), or (b)(4), as
applicable, or from the missing data procedures in Sec.  98.165. If the
analyses are performed annually, then the annual value shall be used as
the monthly average. If the analyses are performed more frequently than
monthly, use the arithmetic average of values obtained during the month
as the monthly average.
    (1) * * *
* * * * *

Fdstkn = Volume of the gaseous fuel or feedstock used in
month n (scf (at standard conditions of 68 [deg]F and atmospheric
pressure) of fuel or feedstock).
CCn = Average carbon content of the gaseous fuel and
feedstock for month n (kg carbon per kg of fuel or feedstock).
MWn = Average molecular weight of the gaseous fuel or
feedstock for month n (kg/kg-mole).

* * * * *
    (2) * * *
* * * * *

Fdstkn = Volume of the liquid fuel or feedstock used in
month n (gallons of fuel or feedstock).
CCn = Average carbon content of the liquid fuel or
feedstock, for month n (kg carbon per gallon of fuel or feedstock).
* * * * *
    (3) * * *
* * * * *

Fdstkn = Mass of solid fuel or feedstock used in month n
(kg of fuel or feedstock).
CCn = Average carbon content of the solid fuel or
feedstock, for month n (kg carbon per kg of fuel or feedstock).

* * * * *
0
25. Section 98.164 is amended by:
0
a. Revising paragraphs (b)(3),(b)(4), and (b)(5) introductory text.
0
b. Removing paragraphs (c) and (d).

Sec.  98.164  Monitoring and QA/QC requirements.

* * * * *
    (b) * * *
    (3) Determine the carbon content of fuel oil, naphtha, and other
liquid fuels and feedstocks at least monthly, except annually for
standard liquid hydrocarbon fuels and feedstocks having consistent
composition, or upon delivery for liquid fuels and feedstocks delivered
by bulk transport (e.g., by truck or rail).

    (4) Determine the carbon content of coal, coke, and other solid
fuels and feedstocks at least monthly, except annually for standard
solid hydrocarbon fuels and feedstocks having consistent composition,
or upon delivery for solid fuels and feedstocks delivered by bulk
transport (e.g., by truck or rail).
    (5) You must use the following applicable methods to determine the
carbon content for all fuels and feedstocks, and molecular weight of
gaseous fuels and feedstocks. Alternatively, you may use the results of
chromatographic analysis of the fuel and feedstock, provided that the
chromatograph is operated, maintained, and calibrated according to the
manufacturer's instructions; and the methods used for operation,
maintenance, and calibration of the chromatograph are documented in the
written monitoring plan for the unit under Sec.  98.3(g)(5).
* * * * *
0
26. Section 98.166 is amended by revising paragraphs (a)(2) and (a)(3)
to read as follows:

Sec.  98.166  Data reporting requirements.

* * * * *
    (a) * * *
    (2) Annual quantity of hydrogen produced (metric tons) for each
process unit.
    (3) Annual quantity of ammonia produced (metric tons), if
applicable, for each process unit.
* * * * *
0
27. Section 98.167 is amended by adding paragraphs (c) and (d) to read
as follows:

Sec.  98.167  Records that must be retained.

* * * * *
    (c) For units using the calculation methodologies described
98.163(b), the records required under Sec.  98.3(g) must include both
the company records and a detailed explanation of how company records
are used to estimate the following:
    (1) Fuel and feedstock consumption, when solid fuel and feedstock
is combusted and a CEMS is not used to measure GHG emissions.
    (2) Fossil fuel consumption, when, pursuant to Sec.  98.33(e), the
owner or operator of a unit that uses CEMS to quantify CO2
emissions and that combusts both fossil and biogenic fuels separately
reports the biogenic portion of the total annual CO2
emissions.
    (3) Sorbent usage, if the methodology in Sec.  98.33(d) is used to
calculate CO2 emissions from sorbent.
    (d) The owner or operator must document the procedures used to
ensure the accuracy of the estimates of fuel and feedstock usage and
sorbent usage (as applicable) in Sec.  98.163(b), including, but not
limited to, calibration of weighing equipment, fuel and feedstock 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.

Subpart Q--[AMENDED]

0
28. Section 98.170 is amended by revising the first sentence to read as
follows:

Sec.  98.170  Definition of the source category.

    The iron and steel production source category includes facilities
with any of the following processes: taconite iron ore processing,
integrated iron and steel manufacturing, cokemaking not colocated with
an integrated iron and steel manufacturing process, direct reduction
furnaces not collocated with an integrated iron and steel manufacturing
process, and electric arc furnace (EAF) steelmaking not colocated with
an integrated iron and steel manufacturing process. * * *
0
29. Section 98.173 is amended by:
0
a. Revising the parameters ``(Fs)'', ``(Csf)'',
``(Fg)'', ``(Fl)'', ``(C0)'',
``(Cp)'', and ``(CR)'' of Equation Q-1 in
paragraph (b)(1)(i).
0
b. Revising the parameters ``(CIron)'',
``(CScrap)'', ``(CFlux)'',
``(CCarbon)'', ``(CSteel)'',
``(CSlag)'', and ``(CR)'' of Equation Q-2 in
paragraph (b)(1)(ii).
0
c. Revising the parameters ``(CCoal)'',
``(CCoke)'', and ``(CR)'' of Equation Q-3 in
paragraph (b)(1)(iii).
0
d. Revising the parameters ``(Fg)'', ``(CFeed)'',
``(CSinter)'', and ``(CR)'' of Equation Q-4 in
paragraph (b)(1)(iv).
0
e. Revising paragraph (b)(1)(v).
0
f. Revising Equation Q-6 and revising the parameters
``(CSteelin)'', ``(CSteelout)'', and
``(CR)'' of Equation Q-6 in paragraph (b)(1)(vi).
0
g. Revising the parameters ``(Fg)'', ``(COre)'',
``(CCarbon)'', ``(COther)'',
``(CIron)'', ``(CNM)'', and ``(CR)''
of Equation Q-7 in paragraph (b)(1)(vii).
0
h. Revising paragraphs (c) and (d).

Sec.  98.173  Calculating GHG emissions.

* * * * *
    (b) * * *
    (1) * * *
    (i) * * *
* * * * *

(Fs) = Annual mass of the solid fuel used (metric tons).
(Csf) = Carbon content of the solid fuel, from the fuel
analysis (expressed as a decimal fraction).
(Fg) = Annual volume of the gaseous fuel used (scf).

* * * * *

(Fl) = Annual volume of the liquid fuel used (gallons).

* * * * *

(C0) = Carbon content of the greenball (taconite)
pellets, from the carbon analysis results (expressed as a decimal
fraction).

* * * * *

(Cp) = Carbon content of the fired pellets, from the
carbon analysis results (expressed as a decimal fraction).

* * * * *

(CR) = Carbon content of the air pollution control
residue, from the carbon analysis results (expressed as a decimal
fraction).

    (ii) * * *
* * * * *

(CIron) = Carbon content of the molten iron, from the
carbon analysis results (expressed as a decimal fraction).

* * * * *

(CScrap) = Carbon content of the ferrous scrap, from the
carbon analysis results (expressed as a decimal fraction).

* * * * *

(CFlux) = Carbon content of the flux materials, from the
carbon analysis results (expressed as a decimal fraction).

* * * * *

(CCarbon) = Carbon content of the carbonaceous materials,
from the carbon analysis results (expressed as a decimal fraction).

* * * * *

(CSteel) = Carbon content of the steel, from the carbon
analysis results (expressed as a decimal fraction).

* * * * *

(CSlag) = Carbon content of the slag, from the carbon
analysis (expressed as a decimal fraction).

* * * * *

(CR) = Carbon content of the air pollution control
residue, from the carbon analysis results (expressed as a decimal
fraction).

    (iii) * * *
* * * * *

(CCoal) = Carbon content of the coal, from the carbon
analysis results (expressed as a decimal fraction).

* * * * *

(CCoke) = Carbon content of the coke, from the carbon
analysis results (expressed as a decimal fraction).

* * * * *

(CR) = Carbon content of the air pollution control
residue, from the carbon analysis results (expressed as a decimal
fraction).

    (iv) * * *
* * * * *

(Fg) = Annual volume of the gaseous fuel used (scf).

* * * * *

(CFeed) = Carbon content of the mixed sinter feed
materials that form the bed entering the sintering machine, from the
carbon analysis results (expressed as a decimal fraction).

* * * * *

(CSinter) = Carbon content of the sinter pellets, from
the carbon analysis results (expressed as a decimal fraction).

* * * * *

(CR) = Carbon content of the air pollution control
residue, from the carbon analysis results (expressed as a decimal
fraction).

    (v) For EAFs, estimate CO2 emissions using Equation Q-5
of this section.
[GRAPHIC] [TIFF OMITTED] TN02AP13.017

Where:
CO2 = Annual CO2 mass emissions from the EAF
(metric tons).
44/12 = Ratio of molecular weights, CO2 to carbon.
(Iron) = Annual mass of direct reduced iron (if any) charged to the
furnace (metric tons).
(CIron) = Carbon content of the direct reduced iron, from
the carbon analysis results (expressed as a decimal fraction).
(Scrap) = Annual mass of ferrous scrap charged to the furnace
(metric tons).
(CScrap) = Carbon content of the ferrous scrap, from the
carbon analysis results (expressed as a decimal fraction).
(Flux) = Annual mass of flux materials (e.g., limestone, dolomite)
charged to the furnace (metric tons).
(CFlux) = Carbon content of the flux materials, from the
carbon analysis results (expressed as a decimal fraction).
(Electrode) = Annual mass of carbon electrode consumed (metric
tons).
(CElectrode) = Carbon content of the carbon electrode,
from the carbon analysis results (expressed as a decimal fraction).
(Carbon) = Annual mass of carbonaceous materials (e.g., coal, coke)
charged to the furnace (metric tons).
(CCarbon) = Carbon content of the carbonaceous materials,
from the carbon analysis results (expressed as a decimal fraction).
(Steel) = Annual mass of molten raw steel produced by the furnace
(metric tons).
(CSteel) = Carbon content of the steel, from the carbon
analysis results (expressed as a decimal fraction).
(Fg) = Annual volume of the gaseous fuel used (scf at 60
degrees F and one atmosphere).
(Cgf) = Average carbon content of the gaseous fuel, from
the fuel analysis results (kg C per kg of fuel).
(MW) = Molecular weight of the gaseous fuel (kg/kg-mole).
(MVC) = Molar volume conversion factor (836.6 scf per kg-mole at
standard conditions of 60 degrees F and one atmosphere).
(0.001) = Conversion factor from kg to metric tons.
(Slag) = Annual mass of slag produced by the furnace (metric tons).
(CSlag) = Carbon content of the slag, from the carbon
analysis results (expressed as a decimal fraction).
(R) = Annual mass of air pollution control residue collected (metric
tons).
(CR) = Carbon content of the air pollution control
residue, from the carbon analysis results (expressed as a decimal
fraction).

    (vi) * * *
    [GRAPHIC] [TIFF OMITTED] TP02AP13.002

* * * * *

(CSteelin) = Carbon content of the molten steel before
decarburization, from the carbon analysis results (expressed as a
decimal fraction).
(CSteelout) = Carbon content of the molten steel after
decarburization, from the carbon analysis results (expressed as a
decimal fraction).

* * * * *

(CR) = Carbon content of the air pollution control
residue, from the carbon analysis results (expressed as a decimal
fraction).

    (vii) * * *
* * * * *

(Fg) = Annual volume of the gaseous fuel used (scf).

* * * * *

(COre) = Carbon content of the iron ore or iron ore
pellets, from the carbon analysis results (expressed as a decimal
fraction).

* * * * *

(CCarbon) = Carbon content of the carbonaceous materials,
from the carbon analysis results (expressed as a decimal fraction).

* * * * *

(COther) = Average carbon content of the other materials
charged to the furnace, from the carbon analysis results (expressed
as a decimal fraction).

* * * * *

(CIron) = Carbon content of the iron, from the carbon
analysis results (expressed as a decimal fraction).

* * * * *

(CNM) = Carbon content of the non-metallic materials,
from the carbon analysis results (expressed as a decimal fraction).

* * * * *

(CR) = Carbon content of the air pollution control
residue, from the carbon analysis results (expressed as a decimal
fraction).

* * * * *
    (c) You must determine emissions of CO2 from the coke
pushing process in mtCO2e by multiplying the metric tons of
coal charged to the by-product recovery and non-recovery coke ovens
during the reporting period by 0.008.
    (d) If GHG emissions from a taconite indurating furnace, basic
oxygen furnace, non-recovery coke oven battery, sinter process, EAF,
decarburization vessel, or direct reduction furnace are vented through
a stack equipped with a CEMS that complies with the Tier 4 methodology
in subpart C of this part, or 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 shall not be
used to calculate process emissions. The owner

or operator shall report under this subpart the combined stack
emissions according to the Tier 4 Calculation Methodology in Sec.
98.33(a)(4) and comply with all associated requirements for Tier 4 in
subpart C of this part (General Stationary Fuel Combustion Sources).
0
30. Section 98.174 is amended by revising the last sentence of
paragraph (b)(1), and revising paragraph (c)(2), to read as follows:

Sec.  98.174  Monitoring and QA/QC requirements.

* * * * *
    (b) * * *
    (1) * * * Determine the mass rate of fuels using the procedures for
combustion units in Sec.  98.34. No determination of the mass of steel
output from decarburization vessels is required.
* * * * *
    (c) * * *
    (2)(i) For the exhaust from basic oxygen furnaces, EAFs,
decarburization vessels, and direct reduction furnaces, sample the
furnace exhaust for at least three complete production cycles that
start when the furnace is being charged and end after steel or iron and
slag have been tapped. For EAFs that produce both carbon steel and
stainless or specialty (low carbon) steel, develop an emission factor
for the production of both types of steel.
    (ii) For the exhaust from continuously charged EAFs, sample the
exhaust for a period spanning at least three hours. For EAFs that
produce both carbon steel and stainless or specialty (low carbon)
steel, develop an emission factor for the production of both types of
steel.
* * * * *
0
31. Section 98.175 is amended by revising paragraph (a) to read as
follows:

Sec.  98.175  Procedures for estimating missing data.

* * * * *
    (a) Except as provided in Sec.  98.174(b)(4), 100 percent data
availability is required for the carbon content of inputs and outputs
for facilities that estimate emissions using the carbon mass balance
procedure in Sec.  98.173(b)(1) or facilities that estimate emissions
using the site-specific emission factor procedure in Sec.
98.173(b)(2).
* * * * *
0
32. Section 98.176 is amended by revising paragraph (e) introductory
text to read as follows:

Sec.  98.176  Data reporting requirements.

* * * * *
    (e) If you use the carbon mass balance method in Sec.  98.173(b)(1)
to determine CO2 emissions, you must, except as provided in
Sec.  98.174(b)(4), report the following information for each process:
* * * * *
0
33. Section 98.177 is amended by revising paragraph (b) to read as
follows:

Sec.  98.177  Records that must be retained.

* * * * *
    (b) When the carbon mass balance method is used to estimate
emissions for a process, the monthly mass of each process input and
output that are used to determine the annual mass, except that no
determination of the mass of steel output from decarburization vessels
is required.
* * * * *

Subpart S--[AMENDED]

0
34. Section 98.190 is amended by revising paragraph (a) to read as
follows:

Sec.  98.190  Definition of the source category.

    (a) Lime manufacturing plants (LMPs) engage in the manufacture of a
lime product by calcination of limestone, dolomite, shells or other
calcareous substances as defined in 40 CFR 63.7081(a)(1).
* * * * *
0
35. Section 98.193 is amended by:
0
a. Revising paragraph (a).
0
b. Revising paragraph (b)(1).
0
c. Revising paragraph (b)(2) introductory text.
0
d. Revising paragraph (b)(2)(ii) introductory text.
0
e. Revising the parameters ``EFLKD,i,n'',
``CaOLKD,i,n'' and ``MgOLKD,i,n'' of Equation S-
2.
0
f. Revising paragraph (b)(2)(iii) introductory text.
0
g. Revising the parameters ``Ewaste,i'',
``CaOwaste,i'', ``MgOwaste,i'', and
``Mwaste,i'' of Equation S-3.
0
h. Revising paragraph (b)(2)(iv) introductory text.
0
i. Revising the parameters ``ECO2'',
``EFLKD,i,n'', ``MLKD,i,n'',
``Ewaste,i'', ``b'' and ``z'' of Equation S-4 to read as
follows:

Sec.  98.193  Calculating GHG emissions.

* * * * *
    (a) If all lime kilns meet the conditions specified in Sec.
98.33(b)(4)(ii) or (b)(4)(iii), you must calculate and report under
this subpart the combined process and combustion CO2
emissions from all lime kilns 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) * * *
    (1) Calculate and report under this subpart the combined process
and combustion CO2 emissions from all lime kilns by
operating and maintaining a CEMS to measure CO2 emissions
from all lime kilns 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).
    (2) Calculate and report process and combustion CO2
emissions from all lime kilns separately using the procedures specified
in paragraphs (b)(2)(i) through (b)(2)(v) of this section.
* * * * *
    (ii) You must calculate a monthly emission factor for each type of
calcined byproduct or waste sold (including lime kiln dust) using
Equation S-2 of this section:
* * * * *

EFLKD, i, n = Emission factor for calcined lime byproduct
or waste type i sold, for month n (metric tons CO2/ton
lime byproduct).
CaOLKD, i, n = Calcium oxide content for calcined lime
byproduct or waste type i sold, for month n (metric tons CaO/metric
ton lime).
MgOLKD, i ,n = Magnesium oxide content for calcined lime
byproduct or waste type i sold, for month n (metric tons MgO/metric
ton lime).

* * * * *
    (iii) You must calculate the annual CO2 emissions from
each type of calcined byproduct or waste that is not sold (including
lime kiln dust and scrubber sludge) using Equation S-3 of this section:
* * * * *

Ewaste, i = Annual CO2 emissions for calcined
lime byproduct or waste type i that is not sold (metric tons
CO2).

* * * * *

CaOwaste, i = Calcium oxide content for calcined lime
byproduct or waste type i that is not sold (metric tons CaO/metric
ton lime).
MgOwaste, i = Magnesium oxide content for calcined lime
byproduct or waste type i that is not sold (metric tons MgO/metric
ton lime).
Mwaste, i = Annual weight or mass of calcined byproducts
or wastes for lime type i that is not sold (tons).

* * * * *
    (iv) You must calculate annual CO2 process emissions for
all lime kilns using Equation S-4 of this section:
* * * * *

ECO2 = Annual CO2 process emissions from lime
production from all lime kilns (metric tons/year).

* * * * *

EFLKD, i, n = Emission factor of calcined byproducts or
wastes sold for lime type i in calendar month n, (metric tons
CO2/ton byproduct or waste) from Equation S-2 of this
section.
MLKD, i, n = Monthly weight or mass of calcined
byproducts or waste sold (such as lime kiln dust, LKD) for lime type
i in calendar month n (tons).
Ewaste, i = Annual CO2 emissions for calcined
lime byproduct or waste type i that is not sold (metric tons
CO2) from Equation S-3 of this section.

* * * * *

b = Number of calcined byproducts or wastes that are sold.
z = Number of calcined byproducts or wastes that are not sold.

* * * * *
0
36. Section 98.194 is amended by:
0
a. Revising paragraph (a).
0
b. Revising paragraph (b).
0
c. Revising paragraph (c) introductory text.

Sec.  98.194  Monitoring and QA/QC requirements.

    (a) You must determine the total quantity of each type of lime
product that is produced and each calcined byproduct or waste (such as
lime kiln dust) that is sold. The quantities of each should be directly
measured monthly with the same plant instruments used for accounting
purposes, including but not limited to, calibrated weigh feeders, rail
or truck scales, and barge measurements. The direct measurements of
each lime product shall be reconciled annually with the difference in
the beginning of and end of year inventories for these products, when
measurements represent lime sold.
    (b) You must determine the annual quantity of each calcined
byproduct or waste generated that is not sold by either direct
measurement using the same instruments identified in paragraph (a) of
this section or by using a calcined byproduct or waste generation rate.
    (c) You must determine the chemical composition (percent total CaO
and percent total MgO) of each type of lime product that is produced
and each type of calcined byproduct or waste sold according to
paragraph (c)(1) or (2) of this section. You must determine the
chemical composition of each type of lime product that is produced and
each type of calcined byproduct or waste sold on a monthly basis. You
must determine the chemical composition for each type of calcined
byproduct or waste that is not sold on an annual basis.
* * * * *
0
37. Section 98.195 is amended by revising paragraph (a).

Sec.  98.195  Procedures for estimating missing data.

* * * * *
    (a) For each missing value of the quantity of lime produced (by
lime type), and quantity of calcined byproduct or waste produced and
sold, the substitute data value shall be the best available estimate
based on all available process data or data used for accounting
purposes.
* * * * *
0
38. Section 98.196 is amended by revising paragraphs (a)(1), (a)(2),
(a)(4), (a)(5), (a)(7), (b)(1) through (b)(6), (b)(9), (b)(10),
(b)(11), and (b)(14) to read as follows:

Sec.  98.196  Data reporting requirements.

* * * * *
    (a) * * *
    (1) Method used to determine the quantity of lime that is produced
and quantity of lime that is sold.
    (2) Method used to determine the quantity of calcined lime
byproduct or waste sold.
* * * * *
    (4) Beginning and end of year inventories for calcined lime
byproducts or wastes sold, by type.
    (5) Annual amount of calcined lime byproduct or waste sold, by type
(tons).
* * * * *
    (7) Annual amount of calcined lime byproduct or waste that is not
sold, by type (tons).
* * * * *
    (b) * * *
    (1) Annual CO2 process emissions from all lime kilns
combined (metric tons).
    (2) Monthly emission factors (metric ton CO2/ton lime
product) for each lime product type produced.
    (3) Monthly emission factors for each calcined byproduct or waste
by lime type that is sold.
    (4) Standard method used (ASTM or NLA testing method) to determine
chemical compositions of each lime type produced and each calcined lime
byproduct or waste type.
    (5) Monthly results of chemical composition analysis of each type
of lime product produced and calcined byproduct or waste sold.
    (6) Annual results of chemical composition analysis of each type of
lime byproduct or waste that is not sold.
* * * * *
    (9) Method used to determine the quantity of calcined lime
byproduct or waste sold.
    (10) Monthly amount of calcined lime byproduct or waste sold, by
type (tons).
    (11) Annual amount of calcined lime byproduct or waste that is not
sold, by type (tons).
* * * * *
    (14) Beginning and end of year inventories for calcined lime
byproducts or wastes sold.
* * * * *

Subpart V--[AMENDED]

0
39. Section 98.222 is amended by revising paragraph (a) to read as
follows:

Sec.  98.222  GHGs to report.

    (a) You must report N2O process emissions from each
nitric acid train as required by this subpart.
* * * * *
0
40. Section 98.223 is amended by:
0
a. Revising paragraphs (b) introductory text, (b)(1), (b)(3), (d)
introductory text, and (e).
0
b. Revising parameters ``EN2Ot'', ``Pt'', ``DF'',
and ``AF'' of Equation V-3a.
0
c. Revising paragraph (g)(2) introductory text.
0
d. Revising parameters ``EN2Ot'', ``EFN2O, t'',
``Pt'', ``DF1'', ``AF1'',
``DF2'', ``AF2'', ``DFN'', and
``AFN'' of Equation V-3b.
0
e. Revising paragraph (g)(3) introductory text.
0
f. Revising parameters ``EN2Ot'', ``EFN2O, t'',
``Pt'', ``DFN'', ``AFN'', and
``FCN'' of Equation V-3c.
0
g. Revising parameter ``EN2Ot'' of Equation V-3d.
0
h. Revising paragraph (i).

Sec.  98.223  Calculating GHG emissions.

* * * * *
    (b) You must conduct an annual performance test for each nitric
acid train according to paragraphs (b)(1) through (b)(3) of this
section.
    (1) You must conduct the performance test at the absorber tail gas
vent, referred to as the test point, for each nitric acid train
according to Sec.  98.224(b) through (f). If multiple nitric acid
trains exhaust to a common abatement technology and/or emission point,
you must sample each process in the ducts before the emissions are
combined, sample each process when only one process is operating, or
sample the combined emissions when multiple processes are operating and
base the site-specific emission factor on the combined production rate
of the multiple nitric acid trains.
* * * * *
    (3) You must measure the production rate during the performance
test and

calculate the production rate for the test period in tons (100 percent
acid basis) per hour.
* * * * *
    (d) If nitric acid train ``t'' exhausts to any N2O
abatement technology ``N'', you must determine the destruction
efficiency for each N2O abatement technology ``N'' according
to paragraphs (d)(1), (d)(2), or (d)(3) of this section.
* * * * *
    (e) If nitric acid train ``t'' exhausts to any N2O
abatement technology ``N'', you must determine the annual amount of
nitric acid produced on nitric acid train ``t'' while N2O
abatement technology ``N'' is operating according to Sec.  98.224(f).
Then you must calculate the abatement utilization factor for each
N2O abatement technology ``N'' for each nitric acid train
``t'' according to Equation V-2 of this section.
* * * * *
    (g) * * *
    (1) * * *
* * * * *

EN2Ot = Annual N2O mass emissions from nitric
acid train ``t'' according to this Equation V-3a (metric tons).

* * * * *

Pt = Annual nitric acid production from nitric acid train
``t'' (ton acid produced, 100 percent acid basis).
DF = Destruction efficiency of N2O abatement technology N
that is used on nitric acid train ``t'' (decimal fraction of
N2O removed from vent stream).
AF = Abatement utilization factor of N2O abatement
technology ``N'' for nitric acid train ``t'' (decimal fraction of
annual production during which abatement technology is operating).

* * * * *
    (2) If multiple N2O abatement technologies are located
in series after your test point, you must use the emissions factor
(determined in Equation V-1 of this section), the destruction
efficiency (determined in paragraph (d) of this section), the annual
nitric acid production (determined in paragraph (i) of this section),
and the abatement utilization factor (determined in paragraph (e) of
this section), according to Equation V-3b of this section:
* * * * *

EN2Ot = Annual N2O mass emissions from nitric
acid train ``t'' according to this Equation V-3b (metric tons).
EFN2O, t = N2O emissions factor for nitric
acid train ``t'' (lb N2O/ton nitric acid produced).
Pt = Annual nitric acid produced from nitric acid train
``t'' (ton acid produced, 100 percent acid basis).
DF1 = Destruction efficiency of N2O abatement
technology 1 (decimal fraction of N2O removed from vent
stream).
AF1 = Abatement utilization factor of N2O
abatement technology 1 (decimal fraction of time that abatement
technology 1 is operating).
DF2 = Destruction efficiency of N2O abatement
technology 2 (decimal fraction of N2O removed from vent
stream).
AF2 = Abatement utilization factor of N2O
abatement technology 2 (decimal fraction of time that abatement
technology 2 is operating).
DFN = Destruction efficiency of N2O abatement
technology N (decimal fraction of N2O removed from vent
stream).
AFN = Abatement utilization factor of N2O
abatement technology N (decimal fraction of time that abatement
technology N is operating).

* * * * *
    (3) If multiple N2O abatement technologies are located
in parallel after your test point, you must use the emissions factor
(determined in Equation V-1 of this section), the destruction
efficiency (determined in paragraph (d) of this section), the annual
nitric acid production (determined in paragraph (i) of this section),
and the abatement utilization factor (determined in paragraph (e) of
this section), according to Equation V-3c of this section:
* * * * *

EN2Ot = Annual N2O mass emissions from nitric
acid train ``t'' according to this Equation V-3c (metric tons).
EFN2O, t = N2O emissions factor for nitric
acid train ``t'' (lb N2O/ton nitric acid produced).
Pt = Annual nitric acid produced from nitric acid train
``t'' (ton acid produced, 100 percent acid basis).
DFN = Destruction efficiency of N2O abatement
technology ``N'' (decimal fraction of N2O removed from
vent stream).
AFN = Abatement utilization factor of N2O
abatement technology ``N'' (decimal fraction of time that abatement
technology ``N'' is operating).
FCN = Fraction control factor of N2O abatement
technology ``N'' (decimal fraction of total emissions from nitric
acid train ``t'' that are sent to abatement technology ``N'').

* * * * *
    (4) * * *
* * * * *

EN2Ot = Annual N2O mass emissions from nitric
acid train ``t'' according to this Equation V-3d (metric tons).

* * * * *
    (i) You must determine the total annual amount of nitric acid
produced on each nitric acid train ``t'' (tons acid produced, 100
percent acid basis), according to Sec.  98.224(f).
0
41. Section 98.224 is amended by revising paragraphs (c) introductory
text, (e), and (f) to read as follows:

Sec.  98.224  Monitoring and QA/QC requirements.

* * * * *
    (c) You must determine the production rate(s) (100 percent acid
basis) from each nitric acid train during the performance test
according to paragraphs (c)(1) or (c)(2) of this section.
* * * * *
    (e) You must determine the total monthly amount of nitric acid
produced. You must also determine the monthly amount of nitric acid
produced while N2O abatement technology is operating from
each nitric acid train. These monthly amounts are determined according
to the methods in paragraphs (c)(1) or (2) of this section.
    (f) You must determine the annual amount of nitric acid produced.
You must also determine the annual amount of nitric acid produced while
N2O abatement technology is operating for each nitric acid
train. These annual amounts are determined by summing the respective
monthly nitric acid quantities determined in paragraph (e) of this
section.
0
42. Section 98.226 is amended by:
0
a. Revising paragraph (a) and paragraph (n) introductory text.
0
b. Adding and reserving paragraph (o).
0
c. Revising paragraph (p).

Sec.  98.226  Data reporting requirements.

* * * * *
    (a) Nitric Acid train identification number.
* * * * *
    (n) If you requested Administrator approval for an alternative
method of determining N2O emissions under Sec.
98.223(a)(2), each annual report must also contain the information
specified in paragraphs (n)(1) through (n)(4) of this section for each
nitric acid production facility.
* * * * *
    (o) [Reserved]
    (p) Fraction control factor for each abatement technology (percent
of total emissions from the nitric acid train that are sent to the
abatement technology) if Equation V-3c is used.

Subpart X--[AMENDED]

0
43. Section 98.242 is amended by revising paragraph (b)(2) to read as
follows:

Sec.  98.242  GHGs to report.

* * * * *
    (b) * * *
    (2) If you comply with Sec.  98.243(c), report CO2,
CH4, and N2O combustion

emissions under subpart C of this part (General Stationary Fuel
Combustion Sources) by following the requirements of subpart C for all
fuels, except emissions from burning petrochemical process off-gas in
any combustion unit are not to be reported under subpart C of this
part. Determine the applicable Tier in subpart C of this part (General
Stationary Fuel Combustion Sources) based on the maximum rated heat
input capacity of the stationary combustion source.
* * * * *
0
44. Section 98.243 is amended by:
0
a. Revising paragraph (b).
0
b. Revising paragraphs (c)(3) and (c)(4).
0
c. Revising the parameters ``Cg'',
``(Fgf)i, n'',
``(Pgp)i, n'', and
``(MWp)i'' of Equation X-1.
0
d. Removing the parameter ``(MWf)I'' of Equation
X-1 and adding parameter ``(MWf)i, n'' in its
place.
0
e. Revising paragraph (d)(3)(i).

Sec.  98.243  Calculating GHG emissions.

* * * * *
    (b) Continuous emission monitoring system (CEMS). Route all process
vent emissions and emissions from stationary combustion units that burn
any amount of process off-gas to one or more stacks and determine GHG
emissions as specified in paragraphs (b)(1) through (3) of this
section.
    (1) Determine CO2 emissions from each stack (except
flare stacks) according to the Tier 4 Calculation Methodology
requirements in subpart C of this part.
    (2) For each stack (except flare stacks) that includes emissions
from combustion of petrochemical process off-gas, calculate
CH4 and N2O emissions in accordance with subpart
C of this part (use Equation C-10 and the ``fuel gas'' emission factors
in Table C-2 of subpart C of this part.
    (3) For each flare, calculate CO2, CH4, and
N2O emissions using the methodology specified in Sec.
98.253(b)(1) through (b)(3).
    (c) * * *
    (3) Collect a sample of each feedstock and product at least once
per month and determine the carbon content of each sample according to
the procedures of Sec.  98.244(b)(4). If multiple valid carbon content
measurements are made during the monthly measurement period, average
them arithmetically. However, if a particular liquid or solid feedstock
is delivered in lots, and if multiple deliveries of the same feedstock
are received from the same supply source in a given calendar month,
only one representative sample is required. Alternatively, you may use
the results of analyses conducted by a feedstock supplier, or product
customer, provided the sampling and analysis is conducted at least once
per month using any of the procedures specified in Sec.  98.244(b)(4).
    (4) If you determine that the monthly average concentration of a
specific compound in a feedstock or product is greater than 99.5
percent by volume or mass, then as an alternative to the sampling and
analysis specified in paragraph (c)(3) of this section, you may
determine carbon content in accordance with paragraphs (c)(4)(i)
through (iii) of this section.
    (i) Calculate the carbon content assuming 100 percent of that
feedstock or product is the specific compound.
    (ii) Maintain records of any determination made in accordance with
this paragraph (c)(4) along with all supporting data, calculations, and
other information.
    (iii) Reevaluate determinations made under this paragraph (c)(4)
after any process change that affects the feedstock or product
composition. Keep records of the process change and the corresponding
composition determinations. If the feedstock or product composition
changes so that the average monthly concentration falls below 99.5
percent, you are no longer permitted to use this alternative method.
    (5) * * *
    (i) * * *
* * * * *

Cg = Annual net contribution to calculated emissions from
carbon (C) in gaseous materials, including streams containing
CO2 recovered for sale or use in another process (kg/yr).
(Fgf)i,n = Volume or mass of gaseous feedstock
i introduced in month ``n'' (scf or kg). If you measure mass, the
term (MWf)i/MVC is replaced with ``1''.

* * * * *

(MWf)i,n = Molecular weight of gaseous
feedstock i in month ``n''(kg/kg-mole).

* * * * *

(Pgp)i,n = Volume or mass of gaseous product i
produced in month ``n'' (scf or kg). If you measure mass, the term
(MWp)i/MVC is replaced with ``1''.

* * * * *

(MWp)i,n = Molecular weight of gaseous product
i in month ``n'' (kg/kg-mole).

* * * * *
    (d) * * *
    (3) * * *
    (i) For all gaseous fuels that contain ethylene process off-gas,
use the emission factors for ``Fuel Gas'' in Table C-2 of subpart C of
this part (General Stationary Fuel Combustion Sources).
* * * * *
0
45. Section 98.244 is amended by:
0
a. Revising the last sentence of paragraph (b)(4) introductory text,
and paragraphs (b)(4)(xiii), (b)(4)(xiv), and (b)(4)(xv)(A).
0
b. Adding paragraph (c).

Sec.  98.244  Monitoring and QA/QC requirements.

* * * * *
    (b) * * *
    (4) * * * Analyses conducted in accordance with methods specified
in paragraphs (b)(4)(i) through (b)(4)(xv) of this section may be
performed by the owner or operator, by an independent laboratory, by
the supplier of a feedstock, or by a product customer.
* * * * *
    (xiii) The results of chromatographic analysis of a feedstock or
product, provided that the chromatograph is operated, maintained, and
calibrated according to the manufacturer's instructions.
    (xiv) The results of mass spectrometer analysis of a feedstock or
product, provided that the mass spectrometer is operated, maintained,
and calibrated according to the manufacturer's instructions.
    (xv) * * *
    (A) An industry standard practice or a method published by a
consensus-based standards organization if such a method exists for
carbon black feedstock oils and carbon black products. Consensus-based
standards organizations include, but are not limited to, the following:
ASTM International (100 Barr Harbor Drive, P.O. Box CB700, West
Conshohocken, Pennsylvania 19428-B2959,<PHONE_NUMBER>, http://www.astm.org), the American National Standards Institute (ANSI, 1819 L
Street, NW., 6th floor, Washington, DC 20036,<PHONE_NUMBER>, http://www.ansi.org), the American Gas Association (AGA, 400 North Capitol
Street, NW., 4th Floor, Washington, DC 20001,<PHONE_NUMBER>, http://www.aga.org), the American Society of Mechanical Engineers (ASME, Three
Park Avenue, New York, NY 10016-5990,<PHONE_NUMBER>, http://www.asme.org), the American Petroleum Institute (API, 1220 L Street,
NW., Washington, DC 20005-4070,<PHONE_NUMBER>, http://www.api.org),
and the North American Energy Standards Board (NAESB, 801 Travis
Street, Suite 1675, Houston, TX 77002,<PHONE_NUMBER>, http://www.naesb.org). The method(s) used shall be documented in the
monitoring plan required under Sec.  98.3(g)(5).
* * * * *

    (c) If you comply with Sec.  98.243(b) or (d), conduct monitoring
and QA/QC for flares in accordance with Sec.  98.254.
0
46. Section 98.245 is revised to read as follows:

Sec.  98.245  Procedures for estimating missing data.

    For missing feedstock and product flow rates, use the same
procedures as for missing fuel usage as specified in Sec.  98.35(b)(2).
For missing feedstock and product carbon contents and missing molecular
weights for gaseous feedstocks and products, use the same procedures as
for missing carbon contents and missing molecular weights for fuels as
specified in Sec.  98.35(b)(1). For missing flare data, follow the
procedures in Sec.  98.255(b) and (c).
0
47. Section 98.246 is amended by:
0
a. Revising paragraphs (a)(6), (a)(8), (a)(9), (a)(11) introductory
text, (b)(2), (b)(4), and (b)(5).
0
b. Removing and reserving paragraphs (b)(5)(i) through (iv), and
(b)(6).
0
c. Revising paragraph (c)(4).

Sec.  98.246  Data reporting requirements.

* * * * *
    (a) * * *
    (6) For each feedstock and product, provide the information
specified in paragraphs (a)(6)(i) through (a)(6)(iii) of this section.
    (i) Name of each method used to determine carbon content or
molecular weight in accordance with 98.244(b)(4);
    (ii) Description of each type of device (e.g., flow meter, weighing
device) used to determine flow or mass in accordance 98.244(b)(1)
through (3).
    (iii) Identification of each method (i.e., method number, title, or
other description) used to determine flow or mass in accordance with
98.244(b)(1) through (3).
* * * * *
    (8) Identification of each combustion unit that burned both process
off-gas and supplemental fuel, including combustion units that are not
part of the petrochemical process unit.
    (9) If you comply with the alternative to sampling and analysis
specified in Sec.  98.243(c)(4), the number of days during which off-
specification product was produced, and if applicable, the date of any
process change that reduced the composition to less than 99.5 percent.
* * * * *
    (11) If you determine carbon content or composition of a feedstock
or product using a method under Sec.  98.244(b)(4)(xv)(B), report the
information listed in paragraphs (a)(11)(i) through (a)(11)(iii) of
this section. Include the information in paragraph (a)(11)(i) of this
section in each annual report. Include the information in paragraphs
(a)(11)(ii) and (a)(11)(iii) of this section only in the first
applicable annual report, and provide any changes to this information
in subsequent annual reports.
* * * * *
    (b) * * *
    (2) For CEMS used on stacks that include emissions from stationary
combustion units that burn any amount of off-gas from the petrochemical
process, report the relevant information required under Sec.
98.36(c)(2) and (e)(2)(vi) for the Tier 4 calculation methodology.
Sections Sec.  98.36(c)(2)(ii) and (c)(2)(ix) do not apply for the
purposes of this subpart.
    (3) For CEMS used on stacks that do not include emissions from
stationary combustion units, report the information required under
Sec.  98.36(b)(6), (b)(7), and Sec.  98.36(e)(2)(vi).
    (4) For each CEMS monitoring location that meets the conditions in
paragraph (b)(2) or (3) of this section, provide an estimate based on
engineering judgment of the fraction of the total CO2
emissions that is attributable to the petrochemical process unit.
    (5) For each CEMS monitoring location that meets the conditions in
paragraph (b)(2) of this section, report the CH4 and
N2O emissions expressed in metric tons of each gas. For each
CEMS monitoring location provide an estimate based on engineering
judgment of the fraction of the total CH4 and N2O
emissions that is attributable to combustion of off-gas from the
petrochemical process unit.
    (i) [Reserved]
    (ii)[Reserved]
    (iii) [Reserved]
    (iv)[Reserved]
    (6) [Reserved]
* * * * *
    (c) * * *
    (4) Name and annual quantity of each feedstock (metric tons).
* * * * *
    48. Section 98.247 is amended by revising paragraphs (b)
introductory text and (b)(2) to read as follows:

Sec.  98.247  Records that must be retained.

* * * * *
    (b) If you comply with the mass balance methodology in Sec.
98.243(c), then you must retain records of the information listed in
paragraphs (b)(1) through (b)(4) of this section.
* * * * *
    (2) Start and end times for time periods when off-specification
product is produced, if you comply with the alternative methodology in
Sec.  98.243(c)(4) for determining carbon content of product.
* * * * *
0
49. Section 98.248 is amended by revising the definition of ``Product''
to read as follows:

Sec.  98.248  Definitions.

* * * * *
    Product, as used in Sec.  98.243, means each of the following
carbon-containing outputs from a process: The petrochemical, recovered
byproducts, and liquid organic wastes that are not combusted onsite.
Product does not include process vent emissions, fugitive emissions, or
wastewater.

Subpart Y--[AMENDED]

0
50. Section 98.252 is amended by revising the parenthetical phrase
preceding the last two sentences in paragraph (a) introductory text,
and revising paragraph (i), to read as follows:

Sec.  98.252  GHGs to report.

* * * * *
    (a) * * * (Use the default CH4 and N2O
emission factors for ``Fuel Gas'' in Table C-2 of this part. For Tier
3, use either the default high heat value for fuel gas in Table C-1 of
subpart C of this part or a calculated HHV, as allowed in Equation C-8
of subpart C of this part.) * * *
* * * * *
    (i) CO2 emissions from non-merchant hydrogen production
process units (not including hydrogen produced from catalytic reforming
units) following the calculation methodologies, monitoring and QA/QC
methods, missing data procedures, reporting requirements, and
recordkeeping requirements of subpart P of this part.
0
51. Section 98.253 is amended by:
0
a. Revising the parameter ``EmFCH4'' to Equation Y-4 and
``EmFN2O'' to Equation Y-5.
0
b. Revising paragraphs (f)(2), (f)(3), and (f)(4) introductory text.
0
c. Revising parameters ``FSG'' and ``MFc'' to
Equation Y-12.
0
d. Revising paragraphs (j) introductory text, (k) introductory text,
and (m) introductory text.

Sec.  98.253  Calculating GHG emissions.

* * * * *
    (b) * * *
    (2) * * *
* * * * *

EmFCH4 = Default CH4 emission factor for
``Fuel Gas'' from Table C-2 of subpart C

of this part (General Stationary Fuel Combustion Sources) (kg
CH4/MMBtu).

* * * * *
    (3) * * *
* * * * *

EmFN2O = Default N2O emission factor for
``Fuel Gas'' from Table C-2 of subpart C of this part (General
Stationary Fuel Combustion Sources) (kg N2O/MMBtu).

* * * * *
    (f) * * *
    (2) Flow measurement. If you have a continuous flow monitor on the
sour gas feed to the sulfur recovery plant or the sour gas feed sent
for off-site sulfur recovery, you must use the measured flow rates when
the monitor is operational to calculate the sour gas flow rate. If you
do not have a continuous flow monitor on the sour gas feed to the
sulfur recovery plant or the sour gas feed sent for off-site sulfur
recovery, you must use engineering calculations, company records, or
similar estimates of volumetric sour gas flow.
    (3) Carbon content. If you have a continuous gas composition
monitor capable of measuring carbon content on the sour gas feed to the
sulfur recovery plant or the sour gas feed sent for off-site for sulfur
recovery, or if you monitor gas composition for carbon content on a
routine basis, you must use the measured carbon content value.
Alternatively, you may develop a site-specific carbon content factor
using limited measurement data or engineering estimates or use the
default factor of 0.20.
    (4) Calculate the CO2 emissions from each on-site sulfur
recovery plant and for sour gas sent off-site for sulfur recovery using
Equation Y-12 of this section.
* * * * *

FSG = Volumetric flow rate of sour gas (including sour
water stripper gas) fed to the sulfur recovery plant or the sour gas
feed sent for off-site for sulfur recovery (scf/year).

* * * * *

MFC = Mole fraction of carbon in the sour gas fed to the
sulfur recovery plant or the four gas feed sent for off-site for
sulfur recovery (kg-mole C/kg-mole gas); default = 0.20.

* * * * *
    (j) For each process vent not covered in paragraphs (a) through (i)
of this section that can reasonably be expected to contain greater than
2 percent by volume CO2 or greater than 0.5 percent by
volume of CH4 or greater than 0.01 percent by volume (100
parts per million) of N2O, calculate GHG emissions using the
Equation Y-19 of this section. You must also use Equation Y-19 of this
section to calculate CH4 emissions for catalytic reforming
unit depressurization and purge vents when methane is used as the purge
gas, CH4 emissions if you elected to use the method in
paragraph (i)(1) of this section, and CO2 and/or
CH4 emissions, as applicable, if you elected this method as
an alternative to the methods in paragraphs (f), (h), or (k) of this
section.
* * * * *
    (k) For uncontrolled blowdown systems, you must calculate
CH4 emissions either using the methods for process vents in
paragraph (j) of this section regardless of the CH4
concentration or using Equation Y-20 of this section. Blowdown systems
where the uncondensed gas stream is routed to a flare or similar
control device is considered to be controlled and is not required to
estimate emissions under this paragraph (k).
* * * * *
    (m) For storage tanks, except as provided in paragraph (m)(3) of
this section, calculate CH4 emissions using the applicable
methods in paragraphs (m)(1) and (m)(2) of this section.
* * * * *
0
52. Section 98.256 is amended by:
0
a. Revising paragraphs (f)(6), (h) introductory text, (h)(2), (h)(3),
(h)(4), (h)(5), and (h)(6).
0
b. Adding paragraph (j)(10).
0
c. Revising paragraph (k)(4).
0
d. Adding paragraph (k)(6).
0
e. Revising paragraph (o)(4)(vi).
0
f. Removing and reserving paragraphs (o)(5) through (7).

Sec.  98.256  Data reporting requirements.

* * * * *
    (f) * * *
    (6) If you use a CEMS, the relevant information required under
Sec.  98.36 for the Tier 4 Calculation Methodology, the CO2
annual emissions as measured by the CEMS (unadjusted to remove
CO2 combustion emissions associated with additional units,
if present) and the process CO2 emissions as calculated
according to Sec.  98.253(c)(1)(ii). Report the CO2 annual
emissions associated with sources other than those from the coke burn-
off in accordance with the applicable subpart (e.g., subpart C of this
part in the case of a CO boiler).
* * * * *
    (h) For on-site sulfur recovery plants and for emissions from sour
gas sent off-site for sulfur recovery, the owner and operator shall
report:
* * * * *
    (2) For each on-site sulfur recovery plant, the maximum rated
throughput (metric tons sulfur produced/stream day), a description of
the type of sulfur recovery plant, and an indication of the method used
to calculate CO2 annual emissions for the sulfur recovery
plant (e.g., CO2 CEMS, Equation Y-12, or process vent method
in Sec.  98.253(j)).
    (3) The calculated CO2 annual emissions for each on-site
sulfur recovery plant, expressed in metric tons. The calculated annual
CO2 emissions from sour gas sent off-site for sulfur
recovery, expressed in metric tons.
    (4) If you use Equation Y-12 of this subpart, the annual volumetric
flow to the on-site and off-site sulfur recovery plant (in scf/year),
the molar volume conversion factor (in scf/kg-mole), and the annual
average mole fraction of carbon in the sour gas (in kg-mole C/kg-mole
gas).
    (5) If you recycle tail gas to the front of an on-site sulfur
recovery plant, indicate whether the recycled flow rate and carbon
content are included in the measured data under Sec.  98.253(f)(2) and
(3). Indicate whether a correction for CO2 emissions in the
tail gas was used in Equation Y-12. If so, then report the value of the
correction, the annual volume of recycled tail gas (in scf/year) and
the annual average mole fraction of carbon in the tail gas (in kg-mole
C/kg-mole gas). Indicate whether you used the default (95%) or a unit
specific correction, and if a unit specific correction is used, report
the approach used.
    (6) If you use a CEMS, the relevant information required under
Sec.  98.36 for the Tier 4 Calculation Methodology, the CO2
annual emissions as measured by the CEMS and the annual process
CO2 emissions calculated according to Sec.  98.253(f)(1).
Report the CO2 annual emissions associated with fuel
combustion in accordance with subpart C of this part (General
Stationary Fuel Combustion Sources).
* * * * *
    (j) * * *
    (10) If you use Equation Y-19 of this subpart, the relevant
information required under paragraph (l)(5) of this section.
    (k) * * *
    (4) For each set of coking drums that are the same dimensions: The
number of coking drums in the set, the height and diameter of the coke
drums (in feet), the cumulative number of vessel openings for all
delayed coking drums in the set, the typical venting pressure (in
psig), void fraction (in cf gas/cf of vessel), and the mole fraction of
methane in coking gas (in kg-mole CH4/kg-mole gas, wet
basis).
* * * * *

    (6) If you use Equation Y-19 of this subpart, the relevant
information required under paragraph (l)(5) of this section for each
set of coke drums or vessels of the same size.
* * * * *
    (o) * * *
    (4) * * *
    (vi) If you did not use Equation Y-23, the tank-specific methane
composition data and the annual gas generation volume (scf/yr) used to
estimate the cumulative CH4 emissions for storage tanks used
to process unstabilized crude oil.
    (5) [Reserved]
    (6) [Reserved]
    (7) [Reserved]
* * * * *

Subpart Z--[AMENDED]

0
53. Section 98.263 is amended by revising paragraph (b)(1)(ii)
introductory text and the parameter ``CO2n,i'' of Equation
Z-1b to read as follows:

Sec.  98.263  Calculating GHG emissions.

* * * * *
    (b) * * *
    (1) * * *
    (ii) If your process measurement provides the CO2
content directly as an output, calculate and report the process
CO2 emissions from each wet-process phosphoric acid process
line using Equation Z-1b of this section:
* * * * *

CO2n,i = Carbon dioxide content of a grab sample batch of
phosphate rock by origin i obtained during month n (percent by
weight, expressed as a decimal fraction).

* * * * *
0
54. Section 98.264 is amended by revising paragraphs (a) and (b) to
read as follows:

Sec.  98.264  Monitoring and QA/QC requirements.

    (a) You must obtain a monthly grab sample of phosphate rock
directly from the rock being fed to the process line before it enters
the mill using one of the following methods. You may conduct the
representative bulk sampling using a method published by a consensus
standards organization, or you may use industry consensus standard
practice methods, including but not limited to the Phosphate Mining
States Methods Used and Adopted by the Association of Fertilizer and
Phosphate Chemists (AFPC). If phosphate rock is obtained from more than
one origin in a month, you must obtain a sample from each origin of
rock or obtain a composite representative sample.
    (b) You must determine the carbon dioxide or inorganic carbon
content of each monthly grab sample of phosphate rock (consumed in the
production of phosphoric acid). You may use a method published by a
consensus standards organization, or you may use industry consensus
standard practice methods, including but not limited to the Phosphate
Mining States Methods Used and Adopted by AFPC.
* * * * *
0
55. Section 98.265 is amended by adding introductory text and revising
paragraph (a) to read as follows:

Sec.  98.265  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 the inorganic carbon content or
CO2 content of phosphate rock (by origin), you must use the
appropriate default factor provided in Table Z-1 of this subpart.
Alternatively, you must determine a substitute data value by
calculating the arithmetic average of the quality-assured values of
inorganic carbon contents or CO2 contents of phosphate rock
of origin i (see Equation Z-1a or Z-1b of this subpart) from samples
immediately preceding and immediately following the missing data
incident. If no quality-assured data on inorganic carbon contents or
CO2 contents of phosphate rock of origin i are available
prior to the missing data incident, the substitute data value shall be
the first quality-assured value for inorganic carbon contents or
CO2 contents for phosphate rock of origin i obtained after
the missing data period.
* * * * *
0
56. Section 98.266 is amended by revising paragraphs (a), (b), (d),
(f)(5), (f)(6), and (f)(8) to read as follows:

Sec.  98.266  Data reporting requirements.

* * * * *
    (a) Annual phosphoric acid production, by origin of the phosphate
rock (tons).
    (b) Annual phosphoric acid production capacity (tons).
* * * * *
    (d) Annual phosphate rock consumption from monthly measurement
records by origin (tons).
* * * * *
    (f) * * *
    (5) Monthly inorganic carbon content of phosphate rock for each
wet-process phosphoric acid process line for which Equation Z-1a is
used (percent by weight, expressed as a decimal fraction), or
CO2 content (percent by weight, expressed as a decimal
fraction) for which Equation Z-1b is used.
    (6) Monthly mass of phosphate rock consumed, by origin, in
production for each wet-process phosphoric acid process line (tons).
* * * * *
    (8) Number of times missing data procedures were used to estimate
phosphate rock consumption (months), inorganic carbon contents of the
phosphate rock (months), and CO2 contents of the phosphate
rock (months).
* * * * *
0
57. Section 98.267 is amended by revising paragraphs (a) and (c) to
read as follows:

Sec.  98.267  Records that must be retained.

* * * * *
    (a) Monthly mass of phosphate rock consumed by origin (tons).
* * * * *
    (c) Documentation of the procedures used to ensure the accuracy of
monthly phosphate rock consumption by origin.

Subpart AA--[AMENDED]

0
58. Section 98.273 is amended by revising paragraph (a)(3) introductory
text and the parameter ``(EF)'' of Equation AA-1 to read as follows:

Sec.  98.273  Calculating GHG emissions.

    (a) * * *
    (3) Calculate biogenic CO2 emissions and emissions of
CH4 and N2O from biomass using measured
quantities of spent liquor solids fired, site-specific HHV, and default
emissions factors, according to Equation AA-1 of this section:
* * * * *
(EF) = Default emission factor for CO2, CH4,
or N2O, from Table AA-1 of this subpart (kg
CO2, CH4, or N2O per mmBtu).
* * * * *
0
59. Section 98.276 is amended by revising paragraphs (e) and (k) to
read as follows:

Sec.  98.276  Data reporting requirements.

* * * * *
    (e) The default emission factor for CO2, CH4,
or N2O, used in Equation AA-1 of this subpart (kg
CO2, CH4, or N2O per mmBtu).
* * * * *
    (k) Annual production of pulp and/or paper products produced
(metric tons) as follows:
    (1) Report the total annual production of unbleached virgin pulp
produced

onsite during the reporting year in air-dried metric tons per year.
This total annual production value is the sum of all kraft,
semichemical, soda, and sulfite pulp produced onsite, prior to
bleaching, through all virgin pulping lines.
    (i) Do not include secondary fiber repulped for paper production in
the virgin pulp production total.
    (ii) You must report a positive (non-zero) value for pulp
production unless your pulp mill did not operate during the reporting
year.
    (2) Report the total annual production of paper products exiting
the paper machine(s), prior to application of any off-machine coatings,
in air-dried metric tons per year. If you operate multiple paper
machines, report the sum (total) of the air-dried metric tons of paper
produced during the reporting year for all paper machines at the mill.
0
60. Tables AA-1 and AA-2 are revised to read as follows:

 Table AA-1 to Subpart AA of Part 98--Kraft Pulping Liquor Emissions Factors for Biomass-Based CO2, CH4, and N2O
----------------------------------------------------------------------------------------------------------------
                                                                  Biomass-based emissions factors (kg/mmBtu HHV)
                          Wood furnish                           -----------------------------------------------
                                                                       CO2a             CH4             N2O
----------------------------------------------------------------------------------------------------------------
North American Softwood.........................................            94.4          0.0019         0.00042
North American Hardwood.........................................            93.7          0.0019         0.00042
Bagasse.........................................................            95.5          0.0019         0.00042
Bamboo..........................................................            93.7          0.0019         0.00042
Straw...........................................................            95.1          0.0019         0.00042
----------------------------------------------------------------------------------------------------------------
a Includes emissions from both the recovery furnace and pulp mill lime kiln.

       Table AA-2 to Subpart AA of Part 98--Kraft Lime Kiln and Calciner Emissions Factors for CH4 and N2O
----------------------------------------------------------------------------------------------------------------
                                                 Fossil fuel-based emissions factors (kg/mmBtu HHV)
                                  ------------------------------------------------------------------------------
               Fuel                          Kraft lime kilns                        Kraft calciners
                                  ------------------------------------------------------------------------------
                                           CH4                N2O               CH4                  N2O
----------------------------------------------------------------------------------------------------------------
Residual Oil (any type)..........  0.0027.............               0  0.0027.............  0.0003.
Distillate Oil (any type)........  0.0027.............               0  0.0027.............  0.0004.
Natural Gas......................  0.0027.............               0  0.0027.............  0.0001.
Biogas...........................  0.0027.............               0  0.0027.............  0.0001.
Petroleum coke...................  0.0027.............               0  NA a...............  NA a.
Other Fuels......................  See Table C-2......               0  See Table C-2......  See Table C-2.
----------------------------------------------------------------------------------------------------------------
a Emission factors for kraft calciners are not available.

Subpart BB--[AMENDED]

0
61. Section 98.282 is amended by revising paragraph (a) to read as
follows:

Sec.  98.282  GHGs to report.

* * * * *
    (a) CO2 process emissions from all silicon carbide
process units or furnaces combined.
* * * * *
0
62. Section 98.283 is amended by:
0
a. Revising the introductory text.
0
b. Revising paragraphs (a), (b) introductory text, and (b)(2)
introductory text.
0
c. Revising the parameter ``Tn'' in Equation BB-2.
0
d. Removing paragraph (d).

Sec.  98.283  Calculating GHG emissions.

    You must calculate and report the combined annual process
CO2 emissions from all silicon carbide process units and
production furnaces using the procedures in either paragraph (a) or (b)
of this section.
    (a) Calculate and report under this subpart the combined annual
process CO2 emissions by operating and maintaining CEMS
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) Calculate and report under this subpart the combined annual
process CO2 emissions using the procedures in paragraphs
(b)(1) and (b)(2) of this section.
* * * * *
    (2) Calculate annual CO2 process emissions from the
silicon carbide production facility according to Equation BB-2 of this
section:
* * * * *
Tn = Petroleum coke consumption in calendar month n
(tons).
* * * * *
0
63. Section 98.286 is amended by revising paragraph (b) introductory
text to read as follows:

Sec.  98.286  Data reporting requirements.

* * * * *
    (b) If a CEMS is not used to measure process CO2
emissions, you must report the information in paragraph (b)(1) through
(b)(8) of this section for all silicon carbide process units or
production furnaces combined:
* * * * *

Subpart DD--[AMENDED]

0
64. Section 98.304 is amended by revising paragraphs (c)(1) and (c)(2)
to read as follows:

Sec.  98.304  Monitoring and QA/QC requirements.

* * * * *
    (c) * * *
    (1) Ensure that cylinders returned to the gas supplier are
consistently weighed on a scale that is certified to be accurate and
precise to within 2 pounds of true weight and is periodically
recalibrated per the manufacturer's specifications. Either measure
residual gas (the amount of gas remaining in returned cylinders) or
have the gas supplier measure it. If the gas supplier weighs the
residual gas, obtain from the gas supplier a detailed monthly
accounting, within  2 pounds, of

residual gas amounts in the cylinders returned to the gas supplier.
    (2) Ensure that cylinders weighed for the beginning and end of year
inventory measurements are weighed on a scale that is certified to be
accurate and precise to within 2 pounds of true weight and is
periodically recalibrated per the manufacturer's specifications. All
scales used to measure quantities that are to be reported under Sec.
98.306 must be calibrated using calibration procedures specified by the
scale manufacturer. Calibration must be performed prior to the first
reporting year. After the initial calibration, recalibration must be
performed at the minimum frequency specified by the manufacturer.
* * * * *

Subpart FF--[AMENDED]

0
65. Section 98.320 is amended by revising paragraphs (b)(1) and (b)(2)
to read as follows:

Sec.  98.320  Definition of the source category.

* * * * *
    (b) * * *
    (1) Each ventilation system shaft or vent hole, including both
those points where mine ventilation air is emitted and those where it
is sold, used onsite, or otherwise destroyed (including by ventilation
air methane (VAM) oxidizers).
    (2) Each degasification system well or gob gas vent hole, including
degasification systems deployed before, during, or after mining
operations are conducted in a mine area. This includes both those wells
and vent holes where coal bed gas is emitted, and those where the gas
is sold, used onsite, or otherwise destroyed (including by flaring).
* * * * *
0
66. Section 98.322 is amended by revising paragraphs (b) and (d) to
read as follows:

Sec.  98.322  GHGs to report.

* * * * *
    (b) You must report CH4 destruction from systems where
gas is sold, used onsite, or otherwise destroyed (including by VAM
oxidation and by flaring).
* * * * *
    (d) You must report under this subpart the CO2 emissions
from coal mine gas CH4 destruction occurring at the
facility, where the gas is not a fuel input for energy generation or
use (e.g., flaring and VAM oxidation).
* * * * *
0
67. Section 98.323 is amended by:
0
a. Revising parameters ``V'', ``MCF'', ``(fH2O)'', and ``P''
of Equation FF-2.
0
b. Revising paragraphs (a)(2) and (b)(1).
0
c. Revising Equation FF-3 and parameters ``Vi'',
``MCFi'', ``Pi'', and ``(fH2O)'' of
Equation FF-3.
0
d. Removing parameter ``(CH4D)'' of Equation FF-4 and adding
parameter ``(CH4D)i,j'' in its place.
0
e. Revising paragraph (c) introductory text and Equation FF-6.

Sec.  98.323  Calculating GHG emissions.

    (a) * * *
* * * * *
V = Volumetric flow rate for the quarter (acfm) based on sampling or
a flow rate meter. If a flow rate meter is used and the meter
automatically corrects to standard temperature and pressure, then
use scfm and replace ``520[deg]R/T x P/1 atm'' with ``1''.
MCF = Moisture correction factor for the measurement period,
volumetric basis.
= 1 when V and C are measured on a dry basis or if both are measured
on a wet basis. = 1-(fH2O) when V is measured on a wet
basis and C is measured on a dry basis. = 1/[1-(fH2O)]
when V is measured on a dry basis and C is measured on a wet basis.
(fH2O) = Moisture content of the methane emitted during
the measurement period, volumetric basis (cubic feet water per cubic
feet emitted gas).
* * * * *
P = Absolute pressure at which flow is measured (atm) for the
quarter. The annual average barometric pressure from the nearest
NOAA weather service station may be used as a default.
* * * * *
    (2) Values of V, C, T, P, and (fH2O), if applicable,
must be based on measurements taken at least once each quarter with no
fewer than 6 weeks between measurements. If measurements are taken more
frequently than once per quarter, then use the average value for all
measurements taken. If continuous measurements are taken, then use the
average value over the time period of continuous monitoring.
* * * * *
    (b) * * *
    [GRAPHIC] [TIFF OMITTED] TP02AP13.003

* * * * *
Vi = Measured volumetric flow rate for the days in the
week when the degasification system is in operation at that
monitoring point, based on sampling or a flow rate meter (acfm). If
a flow rate meter is used and the meter automatically corrects to
standard temperature and pressure, then use scfm and replace
``520[deg]R/Tix Pi/1 atm'' with ``1''.
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.
(fH2O) = Moisture content of the CH4 emitted
during the measurement period, volumetric basis (cubic feet water
per cubic feet emitted gas).
* * * * *
Pi = Absolute pressure at which flow is measured (atm).
* * * * *
    (1) Values for V, C, T, P, and (fH2O), if applicable,
must be based on measurements taken at least once each calendar week
with at least 3 days between measurements. If measurements are taken
more frequently than once per week, then use the average value for all
measurements taken that week. If continuous measurements are taken,
then use the average values over the time period of continuous
monitoring when the continuous monitoring equipment is properly
functioning.
    (2) * * *
* * * * *
(CH4D)i,j = Weekly CH4 liberated
from a degasification monitoring point (metric tons CH4).
* * * * *
    (c) If gas from a degasification system or ventilation system is
sold, used onsite, or otherwise destroyed (including by flaring or VAM
oxidation), you must calculate the quarterly CH4 destroyed
for each destruction device and each point of offsite transport to a
destruction device, using Equation FF-5 of this section. You must
measure CH4 content and flow rate according to the
provisions in Sec.  98.324, and calculate the methane routed to the
destruction device (CH4) using either Equation FF-

1 or Equation FF-4 of this section, as applicable.
* * * * *
    (1) * * *
    [GRAPHIC] [TIFF OMITTED] TP02AP13.004

* * * * *
0
68. Section 98.324 is amended by revising paragraphs (b) introductory
text, (c)(2), and parameter ``CCH4'' of Equation FF-9 to
read as follows:

Sec.  98.324  Monitoring and QA/QC requirements.

* * * * *
    (b) For CH4 liberated from ventilation systems,
determine whether CH4 will be monitored from each
ventilation shaft and vent hole, from a centralized monitoring point,
or from a combination of the two options. Operators are allowed
flexibility for aggregating emissions from more than one ventilation
point, as long as emissions from all are addressed, and the methodology
for calculating total emissions documented. Monitor by one of the
following options:
* * * * *
    (c) * * *
    (2) Collect weekly (once each calendar week, with at least three
days between measurements) or more frequent samples, for all
degasification wells and gob gas vent holes. Determine weekly or more
frequent flow rates, methane concentration, temperature, and pressure
from these degasification wells and gob gas vent holes. Methane
composition should be determined either by submitting samples to a lab
for analysis, or from the use of methanometers at the degasification
monitoring site. Follow the sampling protocols for sampling of methane
emissions from ventilation shafts, as described in Sec.  98.324(b)(1).
You must record the date of sampling, flow, temperature, pressure, and
moisture measurements, the methane concentration (percent), the bottle
number of samples collected, and the location of the measurement or
collection.
* * * * *
    (d) * * *
    (2) * * *
    (iii) * * *
* * * * *
CCH4 = Methane (CH4) concentration in the gas
(volume %) for use in Equations FF-1 and FF-3 of this subpart.
* * * * *
0
69. Section 98.326 is amended by revising paragraphs (a), (f), (h),
(i), (j), (o), and (r), and adding paragraphs (r)(1), (r)(2), (r)(3),
(t), and (u) to read as follows:

Sec.  98.326  Data reporting requirements.

* * * * *
    (a) Quarterly CH4 liberated from each ventilation
monitoring point, (metric tons CH4).
* * * * *
    (f) Quarterly volumetric flow rate for each ventilation monitoring
point and units of measure (scfm or acfm), date and location of each
measurement, and method of measurement (quarterly sampling or
continuous monitoring), used in Equation FF-1 of this subpart.
* * * * *
    (h) Weekly volumetric flow rate used to calculate CH4
liberated from degasification systems and units of measure (acfm or
scfm), and method of measurement (sampling or continuous monitoring),
used in Equation FF-3 of this subpart.
    (i) Quarterly CH4 concentration (%) used to calculate
CH4 liberated from degasification systems and if the data is
based on CEMS or weekly sampling.
    (j) Weekly volumetric flow rate used to calculate CH4
destruction for each destruction device and each point of offsite
transport, and units of measure (acfm or scfm).
* * * * *
    (o) Temperatures ([deg]R), pressure (atm), moisture content, and
the moisture correction factor (if applicable) used in Equation FF-1
and FF-3 of this subpart; and the gaseous organic concentration
correction factor, if Equation FF-9 was required.
* * * * *
    (r) Identification information and description for each well and
shaft, including paragraphs (r)(1) through (r)(3) of this section:
    (1) Indication of whether the well or shaft is monitored
individually, or as part of a centralized monitoring point. Note which
method (sampling or continuous monitoring) was used.
    (2) Start date and close date of each well or shaft.
    (3) Number of days the well or shaft was in operation during the
reporting year.
* * * * *
    (t) Quarterly CH4 routed to each destruction device or
offsite transfer point used in Equation FF-5 of this subpart (metric
tons).
    (u) Mine Safety and Health Administration (MSHA) identification for
this coal mine.

Subpart HH--[AMENDED]

0
70. Section 98.343 is amended by:
0
a. Revising the parameters ``DOC'' and ``F'' of Equation HH-1.
0
b. Revising Equation HH-4 and the parameters ``N'' and ``0.0423'' of
Equation HH-4.
0
c. Revising paragraphs (b)(2)(i), (b)(2)(ii), (b)(2)(iii)(A), and
(b)(2)(iii)(B).
0
d. Revising parameter ``OX'' of Equation HH-5 at paragraph (c)(1).
0
e. Revising paragraphs (c)(3)(i) and (c)(3)(ii).

Sec.  98.343  Calculating GHG emissions.

    (a) * * *
    (1) * * *
* * * * *
DOC = Degradable organic carbon from Table HH-1 of this subpart
[fraction (metric tons C/metric ton waste)].
* * * * *
F = Fraction by volume of CH4 in landfill gas from
measurement data for the current reporting year, if available
(fraction, dry basis, corrected to 0 percent oxygen); otherwise, use
the default of 0.5.
* * * * *
    (b) * * *
    (1) * * *
    [GRAPHIC] [TIFF OMITTED] TP02AP13.005

* * * * *
N = Total number of measurement periods in a year. Use daily
averaging periods for a continuous monitoring system and N = 365 (or
N = 366 for leap years). For monthly sampling, as provided in
paragraph (b)(2) of this section, use N=12.
* * * * *
0.0423 = Density of CH4 lb/cf at 520[deg]R or 60 degrees
Fahrenheit and 1 atm.
* * * * *
    (2) * * *
    (i) Continuously monitor gas flow rate and determine the cumulative
volume of landfill gas each month and the cumulative volume of landfill
gas each year that is collected and routed to a destruction device
(before any treatment equipment). Under this option, the gas flow meter
is not required to automatically correct for temperature, pressure, or,
if necessary, moisture content. If the gas flow meter is not equipped
with automatic correction for temperature, pressure, or, if necessary,
moisture content, you must determine these parameters as specified in
paragraph (b)(2)(iii) of this section.
    (ii) Determine the CH4 concentration in the landfill gas
that is collected and routed to a destruction device (before any
treatment equipment) in a location near or representative of the
location of the gas flow meter at least once each calendar month; if
only one measurement is made each calendar month, there must be at
least fourteen days between measurements.
    (iii) * * *
    (A) Determine the temperature and pressure in the landfill gas that
is collected and routed to a destruction device (before any treatment
equipment) in a location near or representative of the location of the
gas flow meter at least once each calendar month; if only one
measurement is made each calendar month, there must be at least
fourteen days between measurements.
    (B) If the CH4 concentration is determined on a dry
basis and flow is determined on a wet basis or CH4
concentration is determined on a wet basis and flow is determined on a
dry basis, and the flow meter does not automatically correct for
moisture content, determine the moisture content in the landfill gas
that is collected and routed to a destruction device (before any
treatment equipment) in a location near or representative of the
location of the gas flow meter at least once each calendar month; if
only one measurement is made each calendar month, there must be at
least fourteen days between measurements.
    (c) * * *
    (1) * * *
* * * * *
OX = Oxidation fraction. Use the appropriate oxidation fraction
default value from Table HH-4 of this subpart.
* * * * *
    (3) * * *
    (i) Calculate CH4 emissions from the modeled
CH4 generation and measured CH4 recovery using
Equation HH-6 of this section.
[GRAPHIC] [TIFF OMITTED] TP02AP13.006

Where:

Emissions = Methane emissions from the landfill in the reporting
year (metric tons CH4).
GCH4 = Modeled methane generation rate in reporting year
from Equation HH-1 of this section or the quantity of recovered
CH4 from Equation HH-4 of this section, whichever is
greater (metric tons CH4).
N = Number of landfill gas measurement locations (associated with a
destruction device or gas sent off-site). If a single monitoring
location is used to monitor volumetric flow and CH4
concentration of the recovered gas sent to one or multiple
destruction devices, then N=1.
Rn = Quantity of recovered CH4 from Equation
HH-4 of this section for the nth measurement location
(metric tons).
OX = Oxidation fraction. Use the appropriate oxidation fraction
default value from Table HH-4 of this subpart.
DEn = Destruction efficiency (lesser of manufacturer's
specified destruction efficiency and 0.99) for the nth
measurement location. If the gas is transported off-site for
destruction, use DE = 1. If the volumetric flow and CH4
concentration of the recovered gas is measured at a single location
providing landfill gas to multiple destruction devices (including
some gas destroyed on-site and some gas sent off-site for
destruction), calculate DEn as the arithmetic average of
the DE values determined for each destruction device associated with
that measurement location.
fDest, n = Fraction of hours the destruction device
associated with the nth measurement location was operating during
active gas flow calculated as the annual operating hours for the
destruction device divided by the annual hours flow was sent to the
destruction device as measured at the nth measurement
location. If the gas is destroyed in a back-up flare (or similar
device) or if the gas is transported off-site for destruction, use
fDest= 1. If the volumetric flow and CH4
concentration of the recovered gas is measured at a single location
providing landfill gas to multiple destruction devices (including
some gas destroyed on-site and some gas sent off-site for
destruction), calculate fDest, n as the arithmetic
average of the fDest values determined for each
destruction device associated with that measurement location.
    (ii) Calculate CH4 generation and CH4
emissions using measured CH4 recovery and estimated gas
collection efficiency and Equations HH-7 and HH-8 of this section.
[GRAPHIC] [TIFF OMITTED] TP02AP13.007

Where:

MG = Methane generation, adjusted for oxidation, from the landfill
in the reporting year (metric tons CH4).
Emissions = Methane emissions from the landfill in the reporting
year (metric tons CH4).
N = Number of landfill gas measurement locations (associated with a
destruction device or gas sent off-site). If a single monitoring
location is used to monitor volumetric flow and CH4
concentration of the recovered gas sent to one or multiple
destruction devices, then N=1.
Rn = Quantity of recovered CH4 from Equation
HH-4 of this section for the nth measurement location
(metric tons CH4).
CE = Collection efficiency estimated at landfill, taking into
account system coverage, operation, and cover system materials from
Table HH-3 of this subpart. If area by soil cover type information
is not available, use default value of 0.75 (CE4 in table HH-3 of
this subpart) for all areas under active influence of the collection
system.
fRec, n = Fraction of hours the recovery system
associated with the nth measurement location was operating (annual
operating hours/8760 hours per year or annual operating hours/8784
per year for a leap year).
OX = Oxidation fraction. Use appropriate oxidation fraction default
value from Table HH-4 of this subpart.
     DEn = Destruction efficiency, (lesser of
manufacturer's specified destruction efficiency and 0.99) for the
nth measurement location. If the gas is transported off-
site for destruction, use DE = 1. If the volumetric flow and
CH4 concentration of the recovered gas is measured at a
single location providing landfill gas to multiple destruction
devices (including some gas destroyed on-site and some gas sent off-
site for destruction), calculate DEn as the arithmetic
average of the DE values determined for each destruction device
associated with that measurement location.
     fDest,n = Fraction of hours the destruction device
associated with the nth measurement location was
operating during active gas flow calculated as the annual operating
hours for the destruction device divided by the annual hours flow
was sent to the destruction device as measured at the nth
measurement location. If the gas is destroyed in a back-up flare (or
similar device) or if the gas is transported off-site for
destruction, use fDest = 1. If the volumetric flow and
CH4 concentration of the recovered gas is measured at a
single location providing landfill gas to multiple destruction
devices (including some gas destroyed on-site and some gas sent off-
site for destruction), calculate fDest,n as the
arithmetic average of the fDest values determined for
each destruction device associated with that measurement location.
0
71. Section 98.344 is amended by revising paragraph (e) and adding
paragraph (f) to read as follows:

Sec.  98.344  Monitoring and QA/QC requirements.

* * * * *
    (e) For landfills electing to measure the fraction by volume of
CH4 in landfill gas (F), follow the requirements in
paragraphs (e)(1) and (e)(2) of this section.
    (1) Use a gas composition monitor capable of measuring the
concentration of CH4 on a dry basis that is properly
operated, calibrated, and maintained according to the requirements
specified in paragraph (b) of this section. You must either use a gas
composition monitor that is also capable of measuring the O2
concentration correcting for excess (infiltration) air or you must
operate, maintain, and calibrate a second monitor capable of measuring
the O2 concentration on a dry basis according to the
manufacturer's specifications.
    (2) Use Equation HH-10 of this section to correct the measured
CH4 concentration to 0% oxygen. If multiple CH4
concentration measurements are made during the reporting year,
determine F separately for each measurement made during the reporting
year, and use the results to determine the arithmetic average value of
F for use in Equation HH-1 of this part.
[GRAPHIC] [TIFF OMITTED] TP02AP13.008

     Where:

F = Fraction by volume of CH4 in landfill gas (fraction,
dry basis, corrected to 0% oxygen).
CCH4 = Measured CH4 concentration in landfill
gas (volume %, dry basis).
20.9c = Defined O2 correction basis, (volume
%, dry basis).
20.9 = O2 concentration in air (volume %, dry basis).
%O2 = Measured O2 concentration in landfill
gas (volume %, dry basis).

    (f) The owner or operator shall document the procedures used to
ensure the accuracy of the estimates of disposal quantities and, if
applicable, gas flow rate, gas composition, temperature, pressure, and
moisture content measurements. These procedures include, but are not
limited to, calibration of weighing equipment, fuel flow meters, and
other measurement devices. The estimated accuracy of measurements made
with these devices shall also be recorded, and the technical basis for
these estimates shall be provided.
0
72. Section 98.345 is amended by revising paragraph (c) to read as
follows:

Sec.  98.345  Procedures for estimating missing data.

* * * * *
    (c) For missing daily waste disposal quantity data for disposal in
the reporting year, the substitute value shall be the average daily
waste disposal quantity for that day of the week as measured on the
week before and week after the missing daily data.
0
73. Section 98.346 is amended by revising paragraphs (d)(1), (e), (h),
(i)(5), (i)(8), (i)(10), (i)(11), and (i)(12) to read as follows:

Sec.  98.346  Data reporting requirements.

* * * * *
    (d) * * *
    (1) Degradable organic carbon (DOC) and fraction of DOC
dissimilated (DOCF) values used in the calculations.
* * * * *
    (e) Fraction of CH4 in landfill gas (F), an indication
of whether the fraction of CH4 was determined based on
measured values or the default value, and the methane correction factor
used in the calculations. If an MCF other than the default of 1 is
used, provide an indication of whether active aeration of the waste in
the landfill was conducted during the reporting year, a description of
the aeration system, including aeration blower capacity, the fraction
of the landfill containing waste affected by aeration, the total number
of hours during the year the aeration blower was operated, and other
factors used as a basis for the selected MCF value.
* * * * *
    (h) For landfills without gas collection systems, the annual
methane emissions (i.e., the methane generation, adjusted for
oxidation, calculated using Equation HH-5 of this subpart), reported in
metric tons CH4, the oxidation fraction used in the
calculation, and an indication of whether passive vents and/or passive
flares (vents or flares that are not considered part of the gas
collection system as defined in Sec.  98.6) are present at this
landfill.

    (i) * * *
    (5) An indication of whether destruction occurs at the landfill
facility, off-site, or both. If destruction occurs at the landfill
facility, also report for each measurement location an indication of
whether a back-up destruction device is present at the landfill, the
annual operating hours for the primary destruction device, the annual
operating hours for the back-up destruction device (if present), and
the destruction efficiency used (percent).
* * * * *
    (8) Methane generation corrected for oxidation calculated using
Equation HH-5 of this subpart, reported in metric tons CH4,
and the oxidation fraction used in the calculation.
* * * * *
    (10) Methane generation corrected for oxidation calculated using
Equation HH-7 of this subpart, reported in metric tons CH4,
and the oxidation fraction used in the calculation.
    (11) Methane emissions calculated using Equation HH-6 of this
subpart, reported in metric tons CH4, and the oxidation
fraction used in the calculation.
    (12) Methane emissions calculated using Equation HH-8 of this
subpart, reported in metric tons CH4, and the oxidation
fraction used in the calculation.
0
74. Section 98.348 is amended by adding definitions for ``Landfill
capacity'' and ``Leachate recirculation'' in alphabetical order to read
as follows:

Sec.  98.348  Definitions.

* * * * *
    Landfill capacity means the maximum amount of solid waste a
landfill can accept. For the purposes of this subpart, for landfills
that have a permit, the landfill capacity can be determined in terms of
volume or mass in the most recent permit issued by the state, local, or
Tribal agency responsible for regulating the landfill, plus any in-
place waste not accounted for in the most recent permit. If the owner
or operator chooses to convert from volume to mass to determine its
capacity, the calculation must include a site-specific density.
    Leachate recirculation means the practice of taking the leachate
collected from the landfill and reapplying it to the landfill by any of
one of a variety of methods, including pre-wetting of the waste, direct
discharge into the working face, spraying, infiltration ponds, vertical
injection wells, horizontal gravity distribution systems, and pressure
distribution systems.
* * * * *
0
75. Table HH-1 to Subpart HH is amended by revising the entry for
``OX'' as follows:

    Table HH-1 to Subpart HH of Part 98--Emissions Factors, Oxidation
                           Factors and Methods
------------------------------------------------------------------------
               Factor                      Default value         Units
------------------------------------------------------------------------

                                * * * * *
                   Other parameters--All MSW landfills

------------------------------------------------------------------------
                                * * * * *
OX..................................  See Table HH-4 of this   .........
                                       subpart.

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

0
76. Table HH-2 to Subpart HH is revised to read as follows:

   Table HH-2 to Subpart HH of Part 98--U.S. Per Capita Waste Disposal
                                  Rates
------------------------------------------------------------------------
                                                             Waste per
                          Year                            capita ton/cap/
                                                                yr
------------------------------------------------------------------------
1950....................................................            0.63
1951....................................................            0.63
1952....................................................            0.63
1953....................................................            0.63
1954....................................................            0.63
1955....................................................            0.63
1956....................................................            0.63
1957....................................................            0.63
1958....................................................            0.63
1959....................................................            0.63
1960....................................................            0.63
1961....................................................            0.64
1962....................................................            0.64
1963....................................................            0.65
1964....................................................            0.65
1965....................................................            0.66
1966....................................................            0.66
1967....................................................            0.67
1968....................................................            0.68
1969....................................................            0.68
1970....................................................            0.69
1971....................................................            0.69
1972....................................................            0.70
1973....................................................            0.71
1974....................................................            0.71
1975....................................................            0.72
1976....................................................            0.73
1977....................................................            0.73
1978....................................................            0.74
1979....................................................            0.75
1980....................................................            0.75
1981....................................................            0.76
1982....................................................            0.77
1983....................................................            0.77
1984....................................................            0.78
1985....................................................            0.79
1986....................................................            0.79
1987....................................................            0.80
1988....................................................            0.80
1989....................................................            0.83
1990....................................................            0.82
1991....................................................            0.76
1992....................................................            0.74
1993....................................................            0.76
1994....................................................            0.75
1995....................................................            0.70
1996....................................................            0.68
1997....................................................            0.69
1998....................................................            0.75
1999....................................................            0.75
2000....................................................            0.80
2001....................................................            0.91
2002....................................................            1.02
2003....................................................            1.02
2004....................................................            1.01
2005....................................................            0.98
2006....................................................            0.95
2007....................................................            0.95
2008....................................................            0.95
2009 and all later years................................            0.95
------------------------------------------------------------------------

0
77. Table HH-4 to Subpart HH is added to read as follows:

     Table HH-4 to Subpart HH of Part 98--Landfill Methane Oxidation
                                Fractions
------------------------------------------------------------------------
                                                             Use this
                                                             landfill
 If your methane flux rate\a\ for the reporting year is:      methane
                                                             oxidation
                                                             fraction:
------------------------------------------------------------------------
Less than 10 grams per square meter per day (g/m\2\/d)..            0.35
10 to 70 g/m\2\/d.......................................            0.25
Greater than 70 g/m\2\/d................................            0.10
------------------------------------------------------------------------
\a\Methane flux rate (in grams per square meter per day; g/m\2\/d) is
  the mass flow rate of methane per unit area at the bottom of the
  surface soil prior to any oxidation and is calculated as follows.

[GRAPHIC] [TIFF OMITTED] TP02AP13.009

Where:

MF = Methane flux rate from the landfill in the reporting year
(grams per square meter per day, g/m\2\/d).
K = unit conversion factor = 10\6\/365 (g/metric ton per days/year)
or 10\6\/366 for a leap year.
SArea = The surface area of the landfill containing waste at the
beginning of the reporting year (square meters, m\2\).
GCH4 = Modeled methane generation rate in reporting year
from Equation HH-1 of this subpart, or, for application with
Equation HH-6 only, the greater of the modeled methane generation
rate in reporting year from Equation HH-1 of this subpart and the
quantity of recovered CH4 from Equation HH-4 of this
subpart (metric tons CH4).
CE = Collection efficiency estimated at landfill, taking into
account system coverage, operation, and cover system materials from
Table HH-3 of this subpart. If area by soil cover type information
is not available, use default value of 0.75 (CE4 in table HH-3 of
this subpart) for all areas under active influence of the collection
system.
N = Number of landfill gas measurement locations (associated with a
destruction device or gas sent off-site). If a single monitoring
location is used to monitor volumetric flow and CH4
concentration of the recovered gas sent to one or multiple
destruction devices, then N=1.
Rn = Quantity of recovered CH4 from Equation
HH-4 of this subpart for the nth measurement location (metric tons).
fRec,n = Fraction of hours the recovery system associated
with the nth measurement location was operating (annual operating
hours/8760 hours per year or annual operating hours/8784 hours per
year for a leap year).

Subpart II--[AMENDED]

0
78. Section 98.353 is amended by revising the parameters
``fDest--1'' and ``fDest--2'' of Equation II-6 to
read as follows:

Sec.  98.353  Calculating GHG emissions.

* * * * *
    (d) * * *
    (2) * * *
* * * * *
fDest1 = Fraction of hours the primary destruction device
was operating calculated as the annual hours when the destruction
device was operating divided by the annual operating hours of the
biogas recovery system. If the biogas is transported off-site for
destruction, use fDest = 1.
* * * * *
fDest2 = Fraction of hours the back-up destruction device
was operating calculated as the annual hours when the destruction
device was operating divided by the annual operating hours of the
biogas recovery system.
* * * * *

Subpart LL--[AMENDED]

0
79. Section 98.386 is amended by:
0
a. Removing and reserving paragraphs (a)(1) and (a)(5).
0
b. Revising paragraph (a)(4), (a)(8), (a)(9)(v), and (a)(11)(v).
0
c. Removing and reserving paragraph (a)(13).
0
d. Revising paragraphs (a)(14), (a)(15) and (a)(18).
0
e. Removing and reserving paragraph (b)(1).
0
f. Revising paragraphs (b)(4), (b)(5)(v), and (b)(6)(i).
0
g. Removing and reserving paragraph (c)(1).
0
h. Revising paragraphs (c)(4), (c)(5)(v), (d)(2), and (d)(3) to read as
follows:

Sec.  98.386  Data reporting requirements.

* * * * *
    (a) * * *
    (4) Each standard method or other industry standard practice used
to measure each quantity reported in paragraph (a)(2) of this section.
* * * * *
    (8) Each standard method or other industry standard practice used
to measure each quantity reported in paragraph (a)(6) of this section.
    (9) * * *
    (v) The calculated CO2 emissions factor in metric tons
CO2 per barrel or per metric ton of product.
* * * * *
    (11) * * *
    (v) The calculated CO2 emissions factor in metric tons
CO2 per barrel or metric ton of product.
* * * * *
    (14) For each specific type of biomass that enters the coal-to-
liquid facility to be co-processed with fossil fuel-based feedstock to
produce a product reported in paragraph (a)(6) of this section, report
the annual quantity in metric tons or barrels.
    (15) Each standard method or other industry standard practice used
to measure each quantity reported in paragraph (a)(14) of this section.
* * * * *
    (18) Annual CO2 emissions in metric tons that would
result from the complete combustion or oxidation of

each type of biomass feedstock co-processed with fossil fuel-based
feedstocks reported in paragraph (a)(14) of this section, calculated
according to Sec.  98.393(c).
* * * * *
    (b) * * *
    (4) Each standard method or other industry standard practice used
to measure each quantity reported in paragraph (b)(2) of this section.
    (5) * * *
    (v) The calculated CO2 emissions factor in metric tons
per barrel or per metric ton of product.
    (6) * * *
    (i) The density test results in metric tons per barrel.
* * * * *
    (c) * * *
    (4) Each standard method or other industry standard practice used
to measure each quantity reported in paragraph (c)(2) of this section.
    (5) * * *
    (v) The calculated CO2 emissions factor in metric tons
per barrel or per metric ton of product.
* * * * *
    (d) * * *
    (2) For a product that enters the facility to be further refined or
otherwise used on site that is a blended feedstock, producers must meet
the reporting requirements of paragraph (a)(2) of this section by
reflecting the individual components of the blended feedstock.
    (3) For a product that is produced, imported, or exported that is a
blended product, producers, importers, and exporters must meet the
reporting requirements of paragraphs (a)(6), (b)(2), and (c)(2) of this
section, as applicable, by reflecting the individual components of the
blended product.

Subpart MM--[AMENDED]

0
80. Section 98.393 is amended by:
0
a. Revising the parameter ``Producti'' to Equation MM-1 in
paragraph (a)(1).
0
b. Revising the parameter ``Producti'' to Equation MM-1 in
paragraph (a)(2).
0
c. Revising paragraphs (h)(1) introductory text and (h)(2) introductory
text.

Sec.  98.393  Calculating GHG emissions.

    (a) * * *
    (1) * * *
* * * * *
Producti = Annual volume of product ``i'' produced,
imported, or exported by the reporting party (barrels). For
refiners, this volume only includes products ex refinery gate, and
excludes products that entered the refinery but are not reported
under Sec.  98.396(a)(2). For natural gas liquids, volumes shall
reflect the individual components of the product as listed in Table
MM-1 to subpart MM.
* * * * *
    (2) * * *
* * * * *
Producti = Annual mass of product ``i'' produced,
imported, or exported by the reporting party (metric tons). For
refiners, this mass only includes products ex refinery gate, and
excludes products that entered the refinery but are not reported
under Sec.  98.396(a)(2).
* * * * *
    (h) * * *
    (1) A reporter using Calculation Method 1 to determine the emission
factor of a petroleum product shall calculate the CO2
emissions associated with that product using Equation MM-8 of this
section in place of Equation MM-1 of this section.
* * * * *
    (2) A refinery using Calculation Method 1 of this subpart to
determine the emission factor of a non-crude petroleum feedstock shall
calculate the CO2 emissions associated with that feedstock
using Equation MM-9 of this section in place of Equation MM-2 of this
section.
* * * * *
0
81. Section 98.394 is amended by:
0
a. Revising paragraphs (a)(1) introductory text and (a)(3).
0
b. Adding paragraph (b)(3).
0
c. Revising paragraph (c) introductory text.
0
d. Removing and reserving paragraph (d).

Sec.  98.394  Monitoring and QA/QC requirements.

    (a) * * *
    (1) The quantity of petroleum products, natural gas liquids, and
biomass, shall be determined as follows:
* * * * *
    (3) The annual quantity of crude oil received shall be determined
according to one of the following methods. You may use an appropriate
standard method published by a consensus-based standards organization
or you may use an industry standard practice.
    (b) * * *
    (3) For units and processes that operate continuously with
infrequent outages, it may not be possible to complete the calibration
of a flow meter or other measurement device without disrupting normal
process operation. In such cases, the owner or operator may postpone
the calibration until the next scheduled maintenance outage. The best
available information from company records may be used in the interim.
Such postponements shall be documented in the monitoring plan that is
required under Sec.  98.3(g)(5).
    (c) Procedures for Calculation Method 2 of this subpart.
* * * * *
0
82. Section 98.395 is amended by:
0
a. Revising paragraph (a) introductory text.
0
b. Revising paragraph (b).
0
c. Removing paragraph (c).

Sec.  98.395  Procedures for estimating missing data.

    (a) Determination of quantity. Whenever the quality assurance
procedures in Sec.  98.394(a) cannot be followed to measure the
quantity of one or more petroleum products, natural gas liquids, types
of biomass, feedstocks, or crude oil during any period (e.g., if a
meter malfunctions), the following missing data procedures shall be
used:
* * * * *
    (b) Determination of emission factor. Whenever any of the
procedures in Sec.  98.394(c) cannot be followed to develop an emission
factor for any reason, Calculation Method 1 of this subpart must be
used in place of Calculation Method 2 of this subpart for the entire
reporting year.
0
83. Section 98.396 is amended by:
0
a. Removing and reserving paragraph (a)(1).
0
b. Revising paragraph (a)(4).
0
c. Removing and reserving paragraph (a)(5).
0
d. Revising paragraphs (a)(8), (a)(9) introductory text, (a)(9)(iii),
(a)(9)(v), (a)(10) introductory text, (a)(11) introductory text, and
(a)(11)(iii).
0
e. Removing and reserving paragraph (a)(13).
0
f. Revising paragraphs (a)(15) and (a)(18).
0
g. Revising paragraphs (a)(20), (a)(21) and (a)(22).
0
h. Removing paragraph (a)(23).
0
i. Removing and reserving paragraph (b)(1).
0
j. Revising paragraphs (b)(2), (b)(4), (b)(5) introductory text, and
(b)(6) introductory text.
0
k. Removing and reserving paragraph (c)(1).
0
l. Revising paragraph (c)(4), (c)(5) introductory text, (c)(6)
introductory text, (d)(2), and (d)(3).

Sec.  98.396  Data reporting requirements.

* * * * *
    (a) * * *
    (1) [Reserved]
* * * * *
    (4) Each standard method or other industry standard practice used
to measure each quantity reported in paragraph (a)(2) of this section.
    (5) [Reserved]
* * * * *

    (8) Each standard method or other industry standard practice used
to measure each quantity reported in paragraph (a)(6) of this section.
    (9) For every feedstock reported in paragraph (a)(2) of this
section for which Calculation Method 2 of this subpart was used to
determine an emissions factor, report:
* * * * *
    (iii) The carbon share test results in percent mass.
* * * * *
    (v) The calculated CO2 emissions factor in metric tons
CO2 per barrel or per metric ton of product.
    (10) For every non-solid feedstock reported in paragraph (a)(2) of
this section for which Calculation Method 2 of this subpart was used to
determine an emissions factor, report:
* * * * *
    (11) For every petroleum product and natural gas liquid reported in
paragraph (a)(6) of this section for which Calculation Method 2 of this
subpart was used to determine an emissions factor, report:
* * * * *
    (iii) The carbon share test results in percent mass.
* * * * *
    (13) [Reserved]
* * * * *
    (15) Each standard method or other industry standard practice used
to measure each quantity reported in paragraph (a)(14) of this section.
* * * * *
    (18) The CO2 emissions in metric tons that would result
from the complete combustion or oxidation of each type of biomass
feedstock co-processed with petroleum feedstocks reported in paragraph
(a)(14) of this section, calculated according to Sec.  98.393(c).
* * * * *
    (20) For all crude oil that enters the refinery, report the annual
quantity in barrels.
    (21) The quantity of bulk NGLs in metric tons or barrels received
for processing during the reporting year. Report only quantities of
bulk NGLs not reported in (a)(2) of this section.
    (22) Volume of crude oil in barrels that you injected into a crude
oil supply or reservoir.
    (b) In addition to the information required by Sec.  98.3(c), each
importer shall report all of the following information at the corporate
level:
    (1) [Reserved]
    (2) For each petroleum product and natural gas liquid listed in
Table MM-1 of this subpart, report the annual quantity in metric tons
or barrels. For natural gas liquids, quantity shall reflect the
individual components of the product.
* * * * *
    (4) Each standard method or other industry standard practice used
to measure each quantity reported in paragraph (b)(2) of this section.
    (5) For each product reported in paragraph (b)(2) of this section
for which Calculation Method 2 of this subpart used was used to
determine an emissions factor, report:
* * * * *
    (6) For each non-solid product reported in paragraph (b)(2) of this
section for which Calculation Method 2 of this subpart was used to
determine an emissions factor, report:
* * * * *
    (c) * * *
    (1) [Reserved]
* * * * *
    (4) Each standard method or other industry standard practice used
to measure each quantity reported in paragraph (c)(2) of this section.
    (5) For each product reported in paragraph (c)(2) of this section
for which Calculation Method 2 of this subpart was used to determine an
emissions factor, report:
* * * * *
    (6) For each non-solid product reported in paragraph (c)(2) of this
section for which Calculation Method 2 of this subpart used was used to
determine an emissions factor, report:
* * * * *
    (d) * * *
    (2) For a product that enters the refinery to be further refined or
otherwise used on site that is a blended non-crude feedstock, refiners
must meet the reporting requirements of paragraphs (a)(2) of this
section by reflecting the individual components of the blended non-
crude feedstock.
    (3) For a product that is produced, imported, or exported that is a
blended product, refiners, importers, and exporters must meet the
reporting requirements of paragraphs (a)(6), (b)(2), and (c)(2) of this
section, as applicable, by reflecting the individual components of the
blended product.
0
84. Section 98.397 is amended by revising paragraphs (b) and (d) to
read as follows:

Sec.  98.397  Records that must be retained.

* * * * *
    (b) Reporters shall maintain records to support quantities that are
reported under this subpart, including records documenting any
estimations of missing data and the number of calendar days in the
reporting year for which substitute data procedures were followed. For
all reported quantities of petroleum products, natural gas liquids, and
biomass, reporters shall maintain metering, gauging, and other records
normally maintained in the course of business to document product and
feedstock flows including the date of initial calibration and the
frequency of recalibration for the measurement equipment used.
* * * * *
    (d) Reporters shall maintain laboratory reports, calculations and
worksheets used in the measurement of density and carbon share for any
petroleum product or natural gas liquid for which CO2
emissions were calculated using Calculation Method 2.
* * * * *
0
85. Section 98.398 is amended by:
0
a. Adding the definitions for ``Bulk NGLs'' and ``Natural Gas Liquids
(NGLs)'' in alphabetical order.
0
b. Removing the definition of ``Batch''.

Sec.  98.398  Definitions.

* * * * *
    Bulk NGLs for purposes of reporting under this subpart means
mixtures of NGLs that are sold or delivered as undifferentiated
product.
    Natural Gas Liquids (NGLs) for the purposes of reporting under this
subpart means hydrocarbons that are separated from natural gas as
liquids through the process of absorption, condensation, adsorption, or
other methods, and are sold or delivered as differentiated product.
Generally, such liquids consist of ethane, propane, butanes, or
pentanes plus.
0
86. Table MM-1 to Subpart MM is amended by:
0
a. Revising the entries for Ethane, Ethylene, Propane, Propylene,
Butane, Butylene, Isobutane, and Isobutylene.
0
b. Adding footnotes 3 and 4.

   Table MM-1 to Subpart MM of Part 98--Default Factors for Petroleum
                  Products and Natural Gas Liquids\1 2\
------------------------------------------------------------------------
                                                              Column C: