Fdstkn = Volume or mass of the liquid fuel or feedstock
used in month n (gallons or kg of fuel or feedstock).
CCn = Average carbon content of the liquid fuel or
feedstock, for month n (kg carbon per gallon or kg 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
30. 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).
    The revisions read as follows:

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
31. Section 98.166 is amended by revising paragraphs (a)(2), (a)(3),
(b)(2), and (b)(5) 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.
    (b) * * *
    (2) Monthly consumption of each fuel and feedstock used for
hydrogen production and its type (scf or kg of gaseous fuels and
feedstocks, gallons or

kg of liquid fuels and feedstocks, kg of solid fuels and feedstocks).
* * * * *
    (5) Monthly analyses of carbon content for each fuel and feedstock
used in hydrogen production (kg carbon/kg of gaseous and solid fuels
and feedstocks, kg carbon per gallon or kg of liquid fuels and
feedstocks).
* * * * *

0
32. 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 in
Sec.  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
33. 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 collocated 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 collocated with
an integrated iron and steel manufacturing process. * * *

0
34. 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 Equation Q-5 and the definitions in Equation Q-5 in
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).
    The revisions read as follows:

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] TR29NO13.015

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] TR29NO13.016

* * * * *
(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
35. Section 98.174 is amended by adding a sentence to the end of
paragraph (b)(1) and revising paragraph (c)(2) to read as follows:

Sec.  98.174  Monitoring and QA/QC requirements.

* * * * *
    (b) * * *
    (1) * * * 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
36. 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
37. 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
38. 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
39. 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
40. 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
in paragraph (b)(2)(ii).
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 in paragraph (b)(2)(iii).
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 in paragraph
(b)(2)(iv).
    The revisions 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 (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 (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
41. Section 98.194 is amended by revising paragraphs (a), (b), and (c)
introductory text to read as follows:

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
42. Section 98.195 is amended by revising paragraph (a) to read as
follows:

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
43. Section 98.196 is amended by revising paragraphs (a)(1), (a)(2),
(a)(4), (a)(5), (a)(7), (b)(1) through (6), (b)(9) through (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
44. 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
45. Section 98.223 is amended by:
0
a. Revising paragraphs (b) introductory text, (b)(1), (b)(3), (d)
introductory text, and (e) introductory text.
0
b. Removing the parameter ``Pa,N'' of Equation V-2 in
paragraph (e) and adding in its place the parameter
``Pt,N''.
0
c. Revising parameters ``EN2Ot'', ``Pt'', ``DF'',
and ``AF'' of Equation V-3a in paragraph (g)(1).
0
d. Revising paragraph (g)(2) introductory text.
0
e. Revising parameters ``EN2Ot'', ``EFN2O,t'',
``Pt'', ``DF1'', ``AF1'',
``DF2'', ``AF2'', ``DFN'', and
``AFN'' of Equation V-3b in paragraph (g)(2).
0
f. Revising paragraph (g)(3) introductory text.
0
g. Revising parameters ``EN2Ot'', ``EFN2O,t'',
``Pt'', ``DFN'', ``AFN'', and
``FCN'' of Equation V-3c in paragraph (g)(3).
0
h. Revising parameter ``EN2Ot'' of Equation V-3d in
paragraph (g)(4).
0
i. Revising paragraph (i).
    The revisions read as follows:

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 (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), (2), or (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.
* * * * *

Pt,N = Annual nitric acid production from nitric acid
train ``t'' during which N2O abatement technology ``N''
was operational (ton acid produced, 100 percent acid basis).

* * * * *
    (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
46. 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 (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
47. Section 98.226 is amended by:
0
a. Revising paragraph (a).
0
b. Adding reserved paragraph (o).
0
c. Revising paragraph (p).
    The revisions and addition read as follows:

Sec.  98.226  Data reporting requirements.

* * * * *
    (a) Nitric Acid train identification number.
* * * * *
    (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 W--[Amended]

0
48. Section 98.233 is amended by:
0
a. Revising parameter ``Convi'' of Equation W-1 in paragraph
(a).
0
b. Revising parameter ``Convi'' of Equation W-2 in paragraph
(c).
0
c. Revising parameter ``GWP'' of Equation W-36 in paragraph (v).
    The revisions read as follows:

Sec.  98.233  Calculating GHG emissions.

* * * * *
    (a) * * *

Convi = Conversion from standard cubic feet to metric
tons CO2e; 0.000479 for CH4, and 0.00005262
for CO2.

* * * * *
    (c) * * *

Convi = Conversion from standard cubic feet to metric
tons CO2e; 0.000479 for CH4, and 0.00005262
for CO2.

* * * * *
    (v) * * *

GWP = Global warming potential, 1 for CO2, 25 for
CH4, and 298 for N2O.

* * * * *

Subpart X--[AMENDED]

0
49. 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, including units that are not part of the petrochemical process
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
50. Section 98.243 is amended by:
0
a. Revising paragraph (b).
0
b. Revising paragraphs (c)(3) and (4).
0
c. Revising the equation terms ``Cg'',
``(Fgf)i,n'', and
``(Pgp)i,n'' of Equation X-1 in paragraph
(c)(5)(i).
0
d. Removing the equation term ``(MWf)I'' of
Equation X-1 and adding in its place the parameter
``(MWf)i,n'' and defining the new parameter in
the equation terms.
0
e. Removing the equation term ``(MWp)I'' of
Equation X-1 and adding in its place the parameter
``(MWp)i,n'' and defining the new parameter in
the equation terms.
0
f. Revising paragraph (d)(3)(i).
    The revisions read as follows:

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 (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) * * *
    [GRAPHIC] [TIFF OMITTED] TR29NO13.017

* * * * *

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,n/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,n/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
51. Section 98.244 is amended by:
0
a. Revising paragraph (b)(4) introductory text, and paragraphs
(b)(4)(xiii), (b)(4)(xiv), and (b)(4)(xv)(A).
0
b. Adding paragraph (c).
    The revisions and addition read as follows:

Sec.  98.244  Monitoring and QA/QC requirements.

* * * * *
    (b) * * *
    (4) Beginning January 1, 2010, use any applicable methods specified
in paragraphs (b)(4)(i) through (xv) of this section to determine the
carbon content or composition of feedstocks and products and the
average molecular weight of gaseous feedstocks and products. Calibrate
instruments in accordance with paragraphs (b)(4)(i) through (xv) of
this section, as applicable. For coal used as a feedstock, the samples
for carbon content determinations shall be taken at a location that is
representative of the coal feedstock used during the corresponding
monthly period. For carbon black products, samples shall be taken of
each grade or type of product produced during the monthly period.
Samples of coal feedstock or carbon black product for carbon content
determinations may be either grab samples collected and analyzed
monthly or a composite of samples collected more frequently and
analyzed monthly. Analyses conducted in accordance with methods
specified in paragraphs (b)(4)(i) through (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(b) through (e) for
each flare gas flow meter, gas composition meter, and/or heating value
monitor that you use to comply with Sec.  98.253(b)(1) through (b)(3).
You must implement all applicable QA/QC requirements specified in this
paragraph (c) beginning no later than January 1, 2015.

0
52. 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
53. Section 98.246 is amended by:
0
a. Revising paragraphs (a)(6), (a)(8), (a)(9), (a)(11) introductory
text, (a)(11)(iii), and (b)(2) through (5).
0
b. Removing and reserving paragraph (b)(6).
0
c. Revising paragraph (c)(4).
    The revisions read as follows:

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 Sec.  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 with Sec.
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
Sec.  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) The number of days during which off-specification product was
produced if the alternative to sampling and analysis specified in Sec.
98.243(c)(4) is used for a product, and, if applicable, the date of any
process change that reduced the monthly average composition to less
than 99.5 percent for each product or feedstock for which you comply
with the alternative to sampling and analysis specified in Sec.
98.243(c)(4).
* * * * *
    (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.
* * * * *
    (iii) An explanation of why an alternative to the methods listed in
Sec. Sec.  98.244(b)(4)(i) through (xiv) is needed.
    (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 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 (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 results from CO2 directly emitted by the
petrochemical process unit plus CO2 generated by the
combustion of off-gas from 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.
* * * * *
    (c) * * *
    (4) Name and annual quantity of each feedstock (metric tons).
* * * * *

0
54. Section 98.247 is amended by revising paragraphs (b) introductory
text, (b)(2), and (b)(3) 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 (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.
    (3) As part of the monitoring plan required under Sec.  98.3(g)(5),
record the estimated accuracy of measurement devices and the technical
basis for these estimates.
* * * * *

0
55. 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
56. 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
57. Section 98.253 is amended by:
0
a. Revising the parameter ``EmFCH4'' to Equation Y-4 in
paragraph (b)(2) and ``EmFN2O'' to Equation Y-5 in paragraph
(b)(3).
0
b. Revising paragraphs (f)(2) and (3).
0
c. Revising paragraph (f)(4) introductory text and the parameters
``FSG'' and ``MFc'' to Equation Y-12.
0
d. Revising paragraphs (j) introductory text, (k) introductory text,
and (m) introductory text.
    The revisions read as follows:

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 off-site for sulfur recovery (scf/year).

* * * * *

MFC = Mole fraction of carbon in the sour gas fed to the
sulfur recovery plant or the sour gas feed sent 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
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 are considered to be controlled and are 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 (2) of this section.
* * * * *
0
58. Section 98.256 is amended by:
0
a. Revising paragraphs (f)(6), (h) introductory text, and (h)(2)
through (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).
    The revisions and additions read as follows:

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.
* * * * *

Subpart Z--[AMENDED]

0
59. 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
60. 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
61. Section 98.265 is revised 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.
    (b) For each missing value of monthly mass consumption of phosphate
rock (by origin), you must use the best available estimate based on all
available process data or data used for accounting purposes.

0
62. Section 98.266 is amended by revising paragraphs (a), (b), (d), and
(f)(5), (6), and (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
63. 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
64. 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
65. 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) Total annual production of unbleached virgin chemical 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. Do not include mechanical
pulp or secondary fiber repulped for paper production in the virgin
pulp production total.

0
66. Table AA-1 is 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                            ---------------------------------------------
                                                                      \a\ CO2        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.

0
67. Table AA-2 is revised to read as follows:

       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  \a\NA...............  \a\NA
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
68. 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
69. 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 in
paragraph (b)(2).
0
d. Removing paragraph (d).
    The revisions read as follows:

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
70. 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
(8) of this section for all silicon carbide process units or production
furnaces combined:
* * * * *

Subpart DD--[AMENDED]

0
71. Section 98.304 is amended by revising paragraphs (c)(1) and (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
72. Section 98.320 is amended by revising paragraphs (b)(1) and (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
73. 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
74. Section 98.323 is amended by:
0
a. Revising parameters ``V'', ``MCF'', ``(fH2O)'' and ``P''
of Equation FF-1 in paragraph (a).
0
b. Revising paragraph (a)(2).
0
c. Revising Equation FF-3 and revising parameters ``Vi'',
``MCFi'', ``(fH2O)'', and ``Pi'' of
Equation FF-3 in paragraph (b).
0
d. Revising paragraph (b)(1).
0
e. Removing parameter ``CH4D'' of Equation FF-4 of paragraph
(b)(2) and adding parameter ``(CH4D)i,j'' in its
place.
0
f. Revising paragraph (c) introductory text and Equation FF-6 in
paragraph (c)(1).
    The revisions read as follows:

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 CH4 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] TR29NO13.018

* * * * *

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] TR29NO13.019

* * * * *

0
75. Section 98.324 is amended by revising paragraphs (b) introductory
text and (c)(2) 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.
* * * * *

0
76. Section 98.326 is amended by revising paragraphs (a), (f), (h),
(i), (j), (o), and (r), and adding paragraph (t) 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,
shaft, and vent hole, including paragraphs (r)(1) through (r)(3) of
this section:
    (1) Indication of whether the well, shaft, or vent hole 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, shaft, and vent hole.
    (3) Number of days the well, shaft, or vent hole was in operation
during the reporting year.
* * * * *
    (t) Mine Safety and Health Administration (MSHA) identification for
this coal mine.

Subpart HH--[AMENDED]

0
77. Section 98.340 is amended by revising paragraph (a) to read as
follows:

Sec.  98.340  Definition of the source category.

    (a) This source category applies to municipal solid waste (MSW)
landfills that accepted waste on or after January 1, 1980, unless all
three of the following conditions apply.
    (1) The MSW landfill did not receive waste on or after January 1,
2013.
    (2) The MSW landfill had CH4 generation as determined
using Equation HH-5 and, if applicable, Equation HH-7 of this subpart
of less than 1,190 metric tons of CH4 in the 2013 reporting
year.
    (3) The owner or operator of the MSW landfill was not required to
submit an annual report under any requirement of this part in any
reporting year prior to 2013.
* * * * *

0
78. Section 98.343 is amended by:
0
a. Revising the parameters ``DOC'' and ``F'' of Equation HH-1 in
paragraph (a)(1).
0
b. Revising Equation HH-4 and the parameters ``N'' and ``0.0423'' of
Equation HH-4 in paragraph (b)(1).
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 in paragraph (c)(1).
0
e. Revising paragraphs (c)(3)(i) and (ii).
    The revisions read as follows:

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% oxygen); otherwise, use the
default of 0.5.

* * * * *
    (b) * * *
    (1) * * *
    [GRAPHIC] [TIFF OMITTED] TR29NO13.020

* * * * *

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] TR29NO13.021

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 transported off-site for
destruction, use fDest,n= 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] TR29NO13.022

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
hours 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 transported off-site for
destruction, use fDest,n= 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
79. 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 (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] TR29NO13.023

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, and the technical basis for these estimates shall
be recorded.

0
80. 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
81. Section 98.346 is amended by revising paragraphs (d)(1), (e), (h),
(i)(5) through (8), and (i)(10) through (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
(MCF) 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 the number of
destruction devices associated with that measurement location and the
annual operating hours and the destruction efficiency (percent) for
each destruction device associated with that measurement location.
    (6) Annual quantity of recovered CH4 (metric tons
CH4) calculated using Equation HH-4 of this subpart for each
measurement location.
    (7) A description of the gas collection system (manufacturer,
capacity, and number of wells), the surface area (square meters) and
estimated waste depth (meters) for each area specified in Table HH-3 to
this subpart, the estimated gas collection system efficiency for
landfills with this gas collection system, the annual operating hours
of the gas collection system for each measurement location, 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 the landfill.
    (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
82. 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
83. Table HH-1 to Subpart HH is amended by revising the entry for
``OX'' to read 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
84. 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 capita ton/
                       Year                                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
85. 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
                 Under these conditions:                      methane
                                                             oxidation
                                                             fraction:
------------------------------------------------------------------------
       I. For all reporting years prior to the 2013 reporting year
------------------------------------------------------------------------
C1: For all landfills regardless of cover type or                   0.10
 methane flux...........................................
------------------------------------------------------------------------
        II. For the 2013 reporting year and all subsequent years
------------------------------------------------------------------------
C2: For landfills that have a geomembrane (synthetic)                0.0
 cover with less than 12 inches of cover soil for the
 majority of the landfill area containing waste.........
C3: For landfills that do not meet the conditions in C2             0.10
 above, and for which you elect not to determine methane
 flux...................................................
C4: For landfills that do not meet the conditions in C2             0.10
 above and that do not have a soil cover of at least 24
 inches for a majority of the landfill area containing
 waste..................................................
C5: For landfills that have a soil cover of at least 24             0.35
 inches for a majority of the landfill area containing
 waste and for which the methane flux rate is less than
 10 grams per square meter per day (g/m\2\/d)...........
C6: For landfills that have a soil cover of at least 24             0.25
 inches for a majority of the landfill area containing
 waste and for which the methane flux rate is 10 to 70 g/
 m\2\/d.................................................
C7: For landfills that have a soil cover of at least 24             0.10
 inches for a majority of the landfill area containing
 waste and for which the methane flux rate is greater
 than 70 g/m\2\/d.......................................
------------------------------------------------------------------------
\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] TR29NO13.024

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 Equation TT-1 of subpart TT of
this part, as applicable, except for application with Equation HH-6
of this subpart (metric tons CH4). For application with
Equation HH-6 of this subpart, the greater of the modeled methane
generation rate in reporting year from Equation HH-1 of this subpart
or Equation TT-1 of this part, as applicable, 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
86. Section 98.353 is amended by revising the parameters
``fDest--1'' and ``fDest--2'' of Equation II-6 in
paragraph (d)(2) to read as follows:

Sec.  98.353  Calculating GHG emissions.

* * * * *
    (d) * * *
    (2) * * *
* * * * *
fDest--1 = 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.
* * * * *
fDest--2 = 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
87. Section 98.386 is amended by:
0
a. Removing and reserving paragraphs (a)(1) and (5).
0
b. Revising paragraph (a)(4), (a)(8), (a)(9)(v), (a)(11)(v), and
(a)(12) introductory text.
0
c. Removing and reserving paragraph (a)(13).
0
d. Revising paragraphs (a)(14), (15) and (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), and (d)(2) and (3).
    The revisions 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.
* * * * *
    (12) For every non-solid product reported in paragraph (a)(6) of
this section for which Calculation Method 2 of subpart MM of this part
was used to determine an emissions factor, report:
* * * * *
    (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
CO2 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
88. Section 98.393 is amended by:
0
a. Revising the parameter ``Producti'' of Equation MM-1 in
paragraph (a)(1).
0
b. Revising the parameter ``Producti'' of Equation MM-1 in
paragraph (a)(2).
0
c. Revising paragraphs (h)(1) introductory text and (h)(2) introductory
text.
    The revisions read as follows:

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
89. 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 paragraph (d).
    The revisions and addition read as follows:

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
90. Section 98.395 is amended by revising paragraphs (a) introductory
text and (b) and removing paragraph (c).
    The revisions read as follows:

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
91. Section 98.396 is amended by:
0
a. Removing and reserving paragraph (a)(1).
0
b. Removing and reserving paragraphs (a)(4), (5), and (8).
0
c. Revising paragraphs (a)(9) introductory text, (a)(9)(iii),
(a)(9)(v),

(a)(10) introductory text, (a)(11) introductory text, and (a)(11)(iii).
0
d. Removing and reserving paragraphs (a)(13) and (15).
0
e. Revising paragraph (a)(18).
0
f. Revising paragraphs (a)(20) through (22).
0
g. Removing paragraph (a)(23).
0
h. Removing and reserving paragraph (b)(1).
0
i. Revising paragraph (b)(2).
0
j. Removing and reserving paragraph (b)(4).
0
k. Revising paragraphs (b)(5) introductory text and (b)(6) introductory
text.
0
l. Removing and reserving paragraphs (c)(1) and (4).
0
m. Revising paragraphs (c)(5) introductory text, (c)(6) introductory
text, and (d)(2) and (3).
0
The revisions read as follows:

Sec.  98.396  Data reporting requirements.

* * * * *
    (a) * * *
    (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.
* * * * *
    (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) * * *
* * * * *
    (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.
* * * * *
    (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) * * *
    (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 paragraph (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
92. 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
93. 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''.
    The revisions read as follows:

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
94. 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 A:                       Column C:
                                                                      density        Column B:       emission
                            Products                               (metric tons/   carbon share   factor (metric
                                                                       bbl)         (% of mass)    tons CO2/bbl)
----------------------------------------------------------------------------------------------------------------

                                                  * * * * * * *
----------------------------------------------------------------------------------------------------------------
                                Other Petroleum Products and Natural Gas Liquids
----------------------------------------------------------------------------------------------------------------

                                                  * * * * * * *
----------------------------------------------------------------------------------------------------------------
Ethane \3\......................................................          0.0579           79.89           0.170
Ethylene \4\....................................................          0.0492           85.63           0.154
Propane \3\.....................................................          0.0806           81.71           0.241
Propylene \3\...................................................          0.0827           85.63           0.260
Butane \3\......................................................          0.0928           82.66           0.281
Butylene \3\....................................................          0.0972           85.63           0.305
Isobutane \3\...................................................          0.0892           82.66           0.270
Isobutylene \3\.................................................          0.0949           85.63           0.298
----------------------------------------------------------------------------------------------------------------

                                                  * * * * * * *
----------------------------------------------------------------------------------------------------------------
\3\ The density and emission factors for components of LPG determined at 60 degrees Fahrenheit and saturation
  pressure (LPGs other than ethylene).
\4\ The density and emission factor for ethylene determined at 41 degrees Fahrenheit and saturation pressure.

Subpart NN--[AMENDED]

0
95. Section 98.400 is amended by revising paragraphs (a) and (b) to
read as follows:

Sec.  98.400  Definition of the source category.

* * * * *
    (a) Natural gas liquids fractionators are installations that
fractionate natural gas liquids (NGLs) into their constituent liquid
products or mixtures of products (ethane, propane, normal butane,
isobutane or pentanes plus) for supply to downstream facilities.
    (b) Local Distribution Companies (LDCs) are companies that own or
operate distribution pipelines, not interstate pipelines or intrastate
pipelines, that physically deliver natural gas to end users and that
are within a single state that are regulated as separate operating
companies by State public utility commissions or that operate as
independent municipally-owned distribution systems. LDCs do not include
pipelines (both interstate and intrastate) delivering natural gas
directly to major industrial users and farm taps upstream of the local
distribution company inlet.
* * * * *

0
96. Section 98.403 is amended by:
0
a. Revising the parameter ``Fuelh'' to Equation NN-2 in
paragraph (a)(2).
0
b. Revising paragraphs (b)(1) introductory text and (b)(2)(i).
0
c. Revising parameters ``CO2k'' and ``Fuel'' to Equation NN-
4 in paragraph (b)(2)(ii).
0
d. Revising paragraph (b)(3).
0
e. Revising paragraph (b)(4).
0
f. Revising paragraph (c)(2) introductory text.
0
g. Revising parameter ``CO2'' of Equation NN-8 of paragraph
(c)(2).
    The revisions read as follows:

Sec.  98.403  Calculating GHG emissions.

    (a) * * *
    (2) * * *
* * * * *
Fuelh = Total annual volume of product ``h'' supplied
(volume per year, in Mscf for natural gas and bbl for NGLs).
* * * * *
    (b) * * *
    (1) For natural gas that is received for redelivery to downstream
gas transmission pipelines and other local distribution companies, use
Equation NN-3 of this section and the default values for the
CO2 emission factors found in Table NN-2 of this subpart.
Alternatively, reporter-specific CO2 emission factors may be
used, provided they are developed using methods outlined in Sec.
98.404.
* * * * *
    (2)(i) For natural gas delivered to large end-users, use Equation
NN-4 of this section and the default values for the CO2
emission factors found in Table NN-2 of this subpart. A large end-user
means any end-user facility receiving greater than or equal to 460,000
Mscf of natural gas per year. If the LDC does not know the total
quantity of gas delivered to the end-user facility based on readily
available information in the LDCs possession, then large end-user means
any single meter at an end-user facility to which the LDC delivers
equal to or greater than 460,000 Mscf per year.
    (ii) * * *
* * * * *
CO2k = Annual CO2 mass emissions that would
result from the combustion or oxidation of natural gas delivered to
each large end-user k, as defined in paragraph (b)(2)(i) of this
section (metric tons).
Fuel = Total annual volume of natural gas supplied to each large
end-user k, as defined in paragraph (b)(2)(i) of this section (Mscf
per year).
* * * * *
    (3) For the net change in natural gas stored on system by the LDC
during the reporting year, use Equation NN-5a of this section. For
natural gas that is received by means other than through the city gate,
and is not otherwise accounted for by Equation NN-1 or NN-2 of this
section, use Equation NN-5b of this section.
    (i) For natural gas received by the LDC that is injected into on-
system storage, and/or liquefied and stored, and for gas removed from
storage and used for deliveries, use Equation NN-5a of this section and
the default value for the CO2 emission factors found in
Table NN-2 of this subpart. Alternatively, a reporter-specific
CO2 emission factor may be

used, provided it is developed using methods outlined in Sec.  98.404.
[GRAPHIC] [TIFF OMITTED] TR29NO13.028

Where:

CO2l = Annual CO2 mass emissions that would
result from the combustion or oxidation of the net change in natural
gas stored on system by the LDC within the reporting year (metric
tons).
Fuel1 = Total annual volume of natural gas added to
storage on-system or liquefied and stored in the reporting year
(Mscf per year).
Fuel2 = Total annual volume of natural gas that is
removed from storage or vaporized and removed from storage and used
for deliveries to customers or other LDCs by the LDC within the
reporting year (Mscf per year).
EF = Annual average CO2 emission factor for natural gas
placed into/removed from storage (MT CO2/Mscf).

    (ii) For natural gas received by the LDC that bypassed the city
gate, use Equation NN-5b of this section. This includes natural gas
received directly by LDC systems from producers or natural gas
processing plants from local production, received as a liquid and
vaporized for delivery, or received from any other source that bypassed
the city gate. Use the default value for the CO2 emission
factors found in Table NN-2 of this subpart. Alternatively, a reporter-
specific CO2 emission factor may be used, provided it is
developed using methods outlined in Sec.  98.404.
[GRAPHIC] [TIFF OMITTED] TR29NO13.029

Where:

CO2n = Annual CO2 mass emissions that would
result from the combustion or oxidation of natural gas received that
bypassed the city gate and is not otherwise accounted for by
Equation NN-1 or NN-2 of this section (metric tons).
Fuelz = Total annual volume of natural gas received that
was not otherwise accounted for by Equation NN-1 or NN-2 of this
section (natural gas from producers and natural gas processing
plants from local production, or natural gas that was received as a
liquid, vaporized and delivered, and any other source that bypassed
the city gate). (Mscf per year)
EFz = Fuel-specific CO2 emission factor (MT
CO2/Mscf)

    (4) Calculate the total CO2 emissions that would result
from the complete combustion or oxidation of the annual supply of
natural gas to end-users that receive a supply less than 460,000 Mscf
per year using Equation NN-6 of this section.
[GRAPHIC] [TIFF OMITTED] TR29NO13.030

Where:

CO2 = Annual CO2 mass emissions that would
result from the combustion or oxidation of natural gas delivered to
LDC end-users not covered in paragraph (b)(2) of this section
(metric tons).