(dry basis).
* * * * *
TOCrm = Organic carbon content of raw material i or organic carbon
content of combined raw kiln feed(dry basis), as determined in Sec.
98.84(c) or using a default factor of 0.2 percent of total raw
material weight.
M = Number of raw materials or 1 if calculating emissions based on
combined raw kiln feed.
* * * * *
    11. Section 98.84 is amended by revising paragraphs (b), (c), (d),
and (f) to read as follows:

Sec.  98.84  Monitoring and QA/QC requirements.

* * * * *
    (b) You must determine the weight fraction of total CaO and total
MgO in clinker from each kiln using ASTM C114-09 Standard Test Methods
for Chemical Analysis of Hydraulic Cement (incorporated by reference,
see Sec.  98.7). The monitoring must be conducted monthly for each kiln
from a monthly clinker sample drawn from bulk clinker storage if
storage is dedicated to the specific kiln, or from a monthly arithmetic
average of daily clinker samples drawn from the clinker conveying
systems exiting each kiln.
    (c) The total organic carbon content (dry basis) of raw materials
must be determined annually using ASTM C114-09 Standard Test Methods
for Chemical Analysis of Hydraulic Cement (incorporated by reference,
see Sec.  98.7) or a similar industry standard practice or method
approved for total organic carbon determination in raw mineral
materials. The analysis must be conducted either on sample material
drawn from bulk raw kiln feed storage or on sample material drawn from
bulk raw material storage for each category of raw material (i.e.,
limestone, sand, shale, iron oxide, and alumina). Facilities that opt
to use the default total organic carbon factor provided in Sec.
98.83(d)(3), are not required to monitor for TOC.
    (d) The quantity of clinker produced monthly by each kiln must be
determined by direct weight measurement of clinker using the same plant
techniques used for accounting purposes, such as reconciling weigh
hopper or belt weigh feeder measurements against inventory
measurements. As an alternative, facilities may also determine clinker
production by direct measurement of

raw kiln feed and application of a kiln-specific feed-to-clinker
factor. Facilities that opt to use a feed-to-clinker factor must verify
the accuracy of this factor on a monthly basis.
* * * * *
    (f) The annual quantity of raw kiln feed or annual quantity of each
category of raw materials consumed by the facility (e.g., limestone,
sand, shale, iron oxide, and alumina) must be determined monthly by
direct weight measurement using the same plant instruments used for
accounting purposes, such as weigh hoppers, truck weigh scales, or belt
weigh feeders.
* * * * *
    12. Section 98.86 is amended by revising paragraphs (b)(12) and
(b)(13); and by adding paragraph (b)(15) to read as follows:

Sec.  98.86  Data reporting requirements.

    (b) * * *
    (12) Annual organic carbon content of raw kiln feed or annual
organic carbon content of each raw material (wt-fraction, dry basis).
    (13) Annual consumption of raw kiln feed or annual consumption of
each raw material (dry basis).
* * * * *
    (15) Method used to determine the monthly clinker production from
each kiln reported under (b)(2) of this section, including monthly
kiln-specific clinker factors, if used.
    13. Section 98.87 is amended by:
    a. Revising paragraph (a) introductory text.
    b. Removing and reserving paragraphs (a)(1) and (a)(2).
    c. Adding paragraphs (b)(1), (b)(2), and (b)(3).

Sec.  98.87  Records that must be retained.

    (a) If a CEMS is used to measure CO2 emissions, then in
addition to the records required by Sec.  98.3(g), you must retain
under this subpart the records required for the Tier 4 Calculation
Methodology in Sec.  98.37.
* * * * *
    (b) * * *
    (1) Documentation of monthly calculated kiln-specific clinker
CO2 emission factor.
    (2) Documentation of quarterly calculated kiln-specific CKD
CO2 emission factor.
    (3) Measurements, records and calculations used to determine
reported parameters.

Subpart K--[Amended]

    14. Section 98.112 is amended by revising paragraph (a) to read as
follows:

Sec.  98.112  GHGs to report.

* * * * *
    (a) Process CO2 emissions from each electric arc furnace
(EAF) used for the production of any ferroalloy listed in Sec.  98.110,
and process CH4 emissions from each EAF that is used for the
production of any ferroalloy listed in Table K-1 of this section.
* * * * *
    15. Section 98.113 is amended by revising the introductory text to
read as follows:

Sec.  98.113  Calculating GHG emissions.

    You must calculate and report the annual process CO2
emissions from each EAF not subject to paragraph (c) of this section
using the procedures in either paragraph (a) or (b) of this section.
For each EAF also subject to annual process CH4 emissions
reporting, you must also calculate and report the annual process
CH4 emissions from the EAF using the procedures in paragraph
(d) of this section.
* * * * *
    16. Section 98.116 is amended by revising paragraphs (b), (c), (d)
introductory text, (d)(1), and (e)(1) to read as follows:

Sec.  98.116  Data reporting requirements.

* * * * *
    (b) Annual production for each ferroalloy product identified in
Sec.  98.110, from each EAF (tons).
    (c) Total number of EAFs at facility used for production of
ferroalloy products.
    (d) If a CEMS is used to measure CO2 emissions, then you
must report under this subpart the relevant information required by
Sec.  98.36 for the Tier 4 Calculation Methodology and the following
information specified in paragraphs (d)(1) through (d)(3) of this
section.
    (1) Annual process CO2 emissions (in metric tons) from
each EAF used for the production of any ferroalloy product identified
in Sec.  98.110.
* * * * *
    (e) * * *
    (1) Annual process CO2 emissions (in metric tons) from
each EAF used for the production of any ferroalloy identified in Sec.
98.110 (metric tons).
* * * * *

Subpart N--[Amended]

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

Sec.  98.144  Monitoring and QA/QC requirements.

* * * * *
    (b) You must measure carbonate-based mineral mass fractions at
least annually to verify the mass fraction data provided by the
supplier of the raw material; such measurements shall be based on
sampling and chemical analysis conducted by a certified laboratory
using ASTM D3682-01 (Reapproved 2006) Standard Test Method for Major
and Minor Elements in Combustion Residues from Coal Utilization
Processes (incorporated by reference, see Sec.  98.7) or ASTM D6349-09
Standard Test Method for Determination of Major and Minor Elements in
Coal, Coke, and Solid Residues from Combustion of Coal and Coke by
Inductively Coupled Plasma--Atomic Emission Spectrometry (incorporated
by reference, see Sec.  98.7).
* * * * *
    18. Section 98.146 is amended by revising paragraphs (a)
introductory text, (a)(2), (b)(7), and (b)(9) to read as follows:

Sec.  98.146  Data reporting requirements.

* * * * *
    (a) If a CEMS is used to measure CO2 emissions, then you
must report under this subpart the relevant information required under
Sec.  98.36 for the Tier 4 Calculation Methodology and the following
information specified in paragraphs (a)(1) and (a)(2) of this section:
* * * * *
    (2) Annual quantity of glass produced by each glass melting furnace
and by all furnaces combined (tons).
    (b) * * *
    (7) Method used to determine fraction of calcination.
* * * * *
    (9) The number of times in the reporting year that missing data
procedures were followed to measure monthly quantities of carbonate-
based raw materials or mass fraction of the carbonate-based minerals
for any continuous glass melting furnace (months).
    19. Table N-1 to subpart N is amended by adding entries for
``Barium carbonate'' and ``Potassium carbonate'' to read as follows:

  Table N-1--To Subpart N--CO2 Emission Factors for Carbonate-Based Raw
                                Materials
------------------------------------------------------------------------
                                                                  CO2
            Carbonate-Based raw material--mineral               emission
                                                               factor\a\
------------------------------------------------------------------------

                                * * * * *
Barium carbonate--BaCO3......................................      0.223

Potassium carbonate--K2CO3...................................     0.318
------------------------------------------------------------------------
\a\ Emission factors in units of metric tons of CO2 emitted per metric
  ton of carbonate-based raw material charged to the furnace.

Subpart O--[Amended]

    20. Section 98.154 is amended by revising the first and second
sentences of paragraph (k), revising the second sentence of paragraph
(l) introductory text, and revising paragraph (o) to read as follows:

Sec.  98.154  Monitoring and QA/QC requirements.

* * * * *
    (k) The mass of HFC-23 emitted from process vents shall be
estimated at least monthly by incorporating the results of the most
recent emissions test into Equation O-7 of this subpart. HCFC-22
production facilities that use a destruction device connected to the
HCFC-22 production equipment shall conduct emissions tests at process
vents at least once every five years or after significant changes to
the process. * * *
    (l) * * * HFC-23 destruction facilities shall conduct annual
measurements of HFC-23 concentrations at the outlet of the destruction
device in accordance with EPA Method 18 at 40 CFR part 60, appendix A-
6. * * *
* * * * *
    (o) In their estimates of the mass of HFC-23 destroyed, HFC-23
destruction facilities shall account for any temporary reductions in
the destruction efficiency that result from any startups, shutdowns, or
malfunctions of the destruction device, including departures from the
operating conditions defined in state or local permitting requirements
and/or destruction device manufacturer specifications.
* * * * *
    21. Section 98.156 is amended by revising paragraphs (b)(1),
(b)(3), (c), and (d); and revising paragraph (e) introductory text to
read as follows:

Sec.  98.156  Data reporting requirements.

* * * * *
    (b) * * *
    (1) Annual mass of HFC-23 fed into the destruction device.
* * * * *
    (3) Annual mass of HFC-23 emitted from the destruction device.
    (c) Each HFC-23 destruction facility shall report the concentration
(mass fraction) of HFC-23 measured at the outlet of the destruction
device during the facility's annual HFC-23 concentration measurements
at the outlet of the device.
    (d) If the HFC-23 concentration measured pursuant to Sec.
98.154(l) is greater than that measured during the performance test
that is the basis for the destruction efficiency (DE), the facility
shall report the revised destruction efficiency calculated under Sec.
98.154(l) and the values used to calculate it, specifying whether Sec.
98.154(l)(1) or Sec.  98.154(l)(2) has been used for the calculation.
Specifically, the facility shall report the following:
    (1) Flow rate of HFC-23 being fed into the destruction device in
kg/hr.
    (2) Concentration (mass fraction) of HFC-23 at the outlet of the
destruction device.
    (3) Flow rate at the outlet of the destruction device in kg/hr.
    (4) Emission rate (in kg/hr) calculated from paragraphs (d)(2) and
(d)(3) of this section.
    (5) Destruction efficiency (DE) calculated from paragraphs (d)(1)
and (d)(4) of this section.
    (e) By March 31, 2011 or within 60 days of commencing HFC-23
destruction, HFC-23 destruction facilities shall submit a one-time
report including the following information for each destruction
process:
* * * * *
    22. Section 98.157 is amended by revising paragraph (b)(1) to read
as follows:

Sec.  98.157  Records that must be retained.

* * * * *
    (b) * * *
    (1) Records documenting their one-time and annual reports in Sec.
98.156(b) through (e).
* * * * *

Subpart P--[Amended]

    23. Section 98.160 is amended by revising paragraph (c) to read as
follows:

Sec.  98.160  Definition of the source category.

* * * * *
    (c) This source category includes merchant hydrogen production
facilities located within another facility if they are not owned by, or
under the direct control of, the other facility's owner and operator.
    24. Section 98.162 is amended by revising paragraph (a); and by
removing and reserving paragraph (b) to read as follows:

Sec.  98.162  GHGs to report.

* * * * *
    (a) CO2 emissions from each hydrogen production process
unit.
* * * * *
    25. Section 98.163 is amended by:
    a. Revising the introductory text.
    b. Revising paragraph (a) and paragraph (b) introductory text.
    c. In paragraph (b)(1), revising the only sentence, and revising
the definition of ``CO2'' in Equation P-1.
    d. Revising the only sentence of paragraphs (b)(2) and (b)(3).

Sec.  98.163  Calculating GHG emissions.

    You must calculate and report the annual CO2 emissions
from each hydrogen production process unit using the procedures
specified in either paragraph (a) or (b) of this section.
    (a) Continuous Emissions Montoring Systems (CEMS). Calculate and
report under this subpart the 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) Fuel and feedstock material balance approach. Calculate and
report CO2 emissions as the sum of the annual emissions
associated with each fuel and feedstock used for hydrogen production by
following paragraphs (b)(1) through (b)(3) of this section.
    (1) Gaseous fuel and feedstock. You must calculate the annual
CO2 emissions from each gaseous fuel and feedstock according
to Equation P-1 of this section:
* * * * *

    CO2 = Annual CO2 emissions arising from
fuel and feedstock consumption (metric tons/yr).

* * * * *
    (2) Liquid fuel and feedstock. You must calculate the annual
CO2 emissions from each liquid fuel and feedstock according
to Equation P-2 of this section:
* * * * *
    (3) Solid fuel and feedstock. You must calculate the annual
CO2 emissions from each solid fuel and feedstock according
to Equation P-3 of this section:
* * * * *
    26. Section 98.166 is amended by revising the introductory text and
paragraphs (a)(1), (b)(1), and (c) to read as follows:

Sec.  98.166  Data reporting requirements.

    In addition to the information required by Sec.  98.3(c), each
annual report must contain the information specified

in paragraphs (a) or (b) of this section, as appropriate, and (c) and
(d):
    (a) * * *
    (1) Unit identification number and annual CO2 emissions.
* * * * *
    (b) * * *
    (1) Unit identification number and annual CO2 emissions.
* * * * *
    (c) Quantity of CO2 collected and transferred off site
in either gas, liquid, or solid forms, following the requirements of
subpart PP of this part.
* * * * *

Subpart Q--[Amended]

    27. Section 98.172 is amended by revising paragraphs (b) and (c) to
read as follows:

Sec.  98.172  GHGs to report.

* * * * *
    (b) You must report CO2 emissions from flares that burn
blast furnace gas or coke oven gas according to the procedures in Sec.
98.253(b)(1) of subpart Y (Petroleum Refineries) of this part. When
using the alternatives set forth in Sec.  98.253(b)(1)(ii)(B) and Sec.
98.253(b)(1)(iii)(C), you must use the default CO2 emission
factors for coke oven gas and blast furnace gas from Table C-1 of
subpart C in Equations Y-2 and Y-3 of subpart Y of this part. You must
report CH4 and N2O emissions from flares
according to the requirements in Sec.  98.33(c)(2) using the emission
factors for coke oven gas and blast furnace gas in Table C-2 of subpart
C of this part.
    (c) You must report process CO2 emissions from each
taconite indurating furnace; basic oxygen furnace; non-recovery coke
oven battery combustion stack; coke pushing process; sinter process;
EAF; decarburization vessel; and direct reduction furnace by following
the procedures in this subpart.
    28. Section 98.173 is amended by:
    a. Revising the first sentence of the introductory text.
    b. In paragraph (b)(1)(vi), revising the introductory text and the
definition of ``CO2'' in Equation Q-6.
    c. Revising the first sentence of paragraph (d).

Sec.  98.173  Calculating GHG emissions.

    You must calculate and report the annual process CO2
emissions from each taconite indurating furnace, basic oxygen furnace,
non-recovery coke oven battery, sinter process, EAF, decarburization
vessel, and direct reduction furnace using the procedures in either
paragraph (a) or (b) of this section. * * *
    (b) * * *
    (1) * * *
    (vi) For decarburization vessels, estimate CO2 emissions
using Equation Q-6 of this section.
* * * * *

    CO2 = Annual CO2 mass emissions from the
decarburization vessel (metric tons).

* * * * *
    (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
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.*
* *
    29. Section 98.174 is amended by revising first sentence of
paragraph (c)(2) and revising paragraph (c)(7) to read as follows:

Sec.  98.174  Monitoring and QA/QC requirements.

* * * * *
    (c) * * *
    (2) For the furnace 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. * * *
* * * * *
    (7) If your EAF and decarburization vessel exhaust to a common
emission control device and stack, 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 both
processes are operating and base the site-specific emission factor on
the steel production rate of the EAF.
* * * * *
    30. Section 98.175 is amended by revising the introductory text to
read as follows:

Sec.  98.175  Procedures for estimating missing data.

    A complete record of all measured parameters used in the GHG
emissions calculations in Sec.  98.173 is required. Therefore, whenever
a quality-assured value of a required parameter is unavailable, a
substitute data value for the missing parameter shall be used in the
calculations as specified in the paragraphs (a) and (b) of this
section. You must follow the missing data procedures in Sec.  98.255(b)
of subpart Y (Petroleum Refineries) of this part for flares burning
coke oven gas or blast furnace gas. You must document and keep records
of the procedures used for all such estimates.
* * * * *
    31. Section 98.176 is amended by revising the introductory text and
paragraphs (c) and (e)(3); and by adding paragraphs (g) and (h) to read
as follows:

Sec.  98.176  Data reporting requirements.

    In addition to the information required by Sec.  98.3(c), each
annual report must contain the information required in paragraphs (a)
through (h) of this section for each coke pushing operation; taconite
indurating furnace; basic oxygen furnace; non-recovery coke oven
battery; sinter process; EAF; decarburization vessel; direct reduction
furnace; and flare burning coke oven gas or blast furnace gas:
* * * * *
    (c) If a CEMS is used to measure CO2 emissions, then you
must report the relevant information required under Sec.  98.36 for the
Tier 4 Calculation Methodology.
* * * * *
    (e) * * *
    (3) The annual volume of each type of gaseous fuel (reported
separately for each type in standard cubic feet), the annual volume of
each type of liquid fuel (reported separately for each type in
gallons), and the annual mass (in metric tons) of each other process
inputs and outputs used to determine CO2 emissions.
* * * * *
    (g) The annual amount of coal charged to the coke ovens (in metric
tons).
    (h) For flares burning coke oven gas or blast furnace gas, the
information specified in Sec.  98.256(e) of subpart Y (Petroleum
Refineries) of this part.
    32. Section 98.177 is amended by revising paragraph (d) to read as
follows:

Sec.  98.177  Records that must be retained.

* * * * *
    (d) Annual operating hours for each taconite indurating furnace,
basic oxygen furnace, non-recovery coke oven battery, sinter process,
electric arc furnace, decarburization vessel, and direct reduction
furnace.
* * * * *

Subpart S--[Amended]

    33. 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 (e.g., calcium oxide, high-calcium quicklime, calcium
hydroxide, hydrated lime, dolomitic quicklime, dolomitic hydrate, or
other lime products) by calcination of limestone, dolomite, shells or
other calcareous substances as defined in 40 CFR 63.7081(a)(1).
* * * * *
    34. Section 98.193 is amended by:
    a. In paragraph (b)(2)(i), revising the second sentence and the
definition of ``2000/2205'' in Equation S-1.
    b. In paragraph (b)(2)(ii), revising the only sentence and the
definitions of ``EFLKD,i,n'', ``CaOLKD,i,n'',
``MgOLKD,i,n'', and ``2000/2205'' in Equation S-2.
    c. In paragraph (b)(2)(iii), revising the only sentence and the
definitions of ``Ewaste,i'', ``CaOwaste,i'',
``MgOwaste,i'', ``Mwaste,i'', and ``2000/2205''
in Equation S-3.
    d. In Paragraph (b)(2)(iv), revising the definitions of
``EFLIME,i,n'', ``MLIME,i,n'',
``EFLKD,i,n'', ``MLKD,i,n'',
``Ewaste,i'', ``t'', ``b'', and ``z'' in Equation S-4.

Sec.  98.193  Calculating GHG emissions.

* * * * *
    (b) * * *
    (2) * * *
    (i) * * * Calcium oxide and magnesium oxide content must be
analyzed monthly for each lime product type that is produced:
* * * * *

2000/2205 = Conversion factor for tons to metric tons.

    (ii) You must calculate a monthly emission factor for each type
of calcined byproduct/waste sold (including lime kiln dust) using
Equation S-2 of this section:
* * * * *

EFLKD,i,n = Emission factor for calcined lime byproduct/
waste type i sold, for month n (metric tons CO2/ton lime
byproduct).
* * * * *
CaOLKD,i,n = Calcium oxide content for calcined lime
byproduct/waste type i sold, for month n (metric tons CaO/metric ton
lime).
MgOLKD,i,n = Magnesium oxide content for calcined lime
byproduct/waste type i sold, for month n (metric tons MgO/metric ton
lime).
2000/2205 = Conversion factor for tons to metric tons.

    (iii) You must calculate the annual CO2 emissions
from each type of calcined byproduct/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/waste type i that is not sold (metric tons
CO2).
* * * * *
CaOwaste,i = Calcium oxide content for calcined lime
byproduct/waste type i that is not sold (metric tons CaO/metric ton
lime).
MgOwaste,i = Magnesium oxide content for calcined lime
byproduct/waste type i that is not sold (metric tons MgO/metric ton
lime).
Mwaste,i = Annual weight or mass of calcined byproducts/
wastes for lime type i that is not sold (tons).
2000/2205 = Conversion factor for tons to metric tons.

    (iv) * * *

EFLIME,i,n = Emission factor for lime type i produced, in
calendar month n (metric tons CO2/ton lime) from Equation
S-1 of this section.
MLIME,i,n = Weight or mass of lime type i produced in
calendar month n (tons).
EFLKD,i,n = Emission factor of calcined byproducts/wastes
sold for lime type i in calendar month n, (metric tons
CO2/ton byproduct/waste) from Equation S-2 of this
section.
MLKD,i,n = Monthly weight or mass of calcined byproducts/
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/waste type i that is not sold (metric tons
CO2) from Equation S-3 of this section.
t = Number of lime types produced
b = Number of calcined byproducts/wastes that are sold.
z = Number of calcined byproducts/wastes that are not sold.

* * * * *
    35. Section 98.194 is amended by:
    a. Revising the first sentence of paragraph (a).
    b. Revising paragraph (c) introductory text.
    c. Revising paragraph (d).

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/waste (such as
lime kiln dust) that is sold. * * *
* * * * *
    (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/waste sold according to paragraph
(c)(1) or (c)(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/waste sold on a monthly basis. You must determine
the chemical composition for each type of calcined byproduct/waste that
is not sold on an annual basis.
* * * * *
    (d) You must use the analysis of calcium oxide and magnesium oxide
content of each lime product that is produced and that is collected
during the same month as the production data in monthly calculations.
* * * * *
    36. Section 98.195 is amended by revising the first sentence of the
introductory text; and by revising paragraph (a) to read as follows:

Sec.  98.195  Procedures for estimating missing data.

    For the procedure in Sec.  98.193(b)(1), a complete record of all
measured parameters used in the GHG emissions calculations is required
(e.g., oxide content, quantity of lime products, etc.). * * *
    (a) For each missing value of the quantity of lime produced (by
lime type), and quantity of calcined byproduct/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.
* * * * *
    37. Section 98.196 is revised to read as follows:

Sec.  98.196  Data reporting requirements.

    In addition to the information required by Sec.  98.3(c), each
annual report must contain the information specified in paragraphs (a)
or (b) of this section, as applicable.
    (a) If a CEMS is used to measure CO2 emissions, then you
must report under this subpart the relevant information required by
Sec.  98.36 and the information listed in paragraphs (a)(1) through
(a)(8) of this section.
    (1) Method used to determine the quantity of lime that is produced
and sold.
    (2) Method used to determine the quantity of calcined lime
byproduct/waste sold.
    (3) Beginning and end of year inventories for each lime product
that is produced, by type.
    (4) Beginning and end of year inventories for calcined lime
byproducts/wastes sold, by type.
    (5) Annual amount of calcined lime byproduct/waste sold, by type
(tons).
    (6) Annual amount of lime product sold, by type (tons).
    (7) Annual amount of calcined lime byproduct/waste that is not
sold, by type (tons).
    (8) Annual amount of lime product not sold, by type (tons).

    (b) If a CEMS is not used to measure CO2 emissions, then
you must report the information listed in paragraphs (b)(1) through
(b)(17) of this section.
    (1) Annual CO2 process emissions from all kilns combined
(metric tons).
    (2) Monthly emission factors for each lime type produced.
    (3) Monthly emission factors for each calcined byproduct/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/waste type.
    (5) Monthly results of chemical composition analysis of each type
of lime product produced and calcined byproduct/waste sold.
    (6) Annual results of chemical composition analysis of each type of
lime byproduct/waste that is not sold.
    (7) Method used to determine the quantity of lime produced and/or
lime sold.
    (8) Monthly amount of lime product sold, by type (tons).
    (9) Method used to determine the quantity of calcined lime
byproduct/waste sold.
    (10) Monthly amount of calcined lime byproduct/waste sold, by type
(tons).
    (11) Annual amount of calcined lime byproduct/waste that is not
sold, by type (tons).
    (12) Monthly weight or mass of each lime type produced (tons).
    (13) Beginning and end of year inventories for each lime product
that is produced.
    (14) Beginning and end of year inventories for calcined lime
byproducts/wastes sold.
    (15) Annual lime production capacity (tons) per facility.
    (16) Number of times in the reporting year that missing data
procedures were followed to measure lime production (months) or the
chemical composition of lime products sold (months).
    (17) Indicate whether CO2 was used on-site (i.e. for use
in a purification process). If CO2 was used on-site, provide
the information in paragraphs (b)(17)(i) and (b)(17)(ii) of this
section.
    (i) The annual amount of CO2 captured for use in the on-
site process.
    (ii) The method used to determine the amount of CO2
captured.

Subpart V--[Amended]

    38. Section 98.223 is amended by:
    a. Revising paragraphs (a)(1), (a)(2)(ii), (b) introductory text,
(b)(1), (b)(2), (c), (d) introductory text, and (e).
    b. Removing and reserving paragraph (f).
    c. Revising paragraph (g).
    d. Adding paragraph (i).

Sec.  98.223  Calculating GHG emissions.

    (a) * * *
    (1) Use a site-specific emission factor and production data
according to paragraphs (b) through (i) of this section.
    (2) * * *
    (ii) If the Administrator does not approve your requested
alternative method within 150 days of the end of the reporting year,
you must determine the N2O emissions for the current
reporting period using the procedures specified in paragraph (a)(1) of
this section.
    (b) You must conduct an annual performance test for each nitric
acid train according to paragraphs (b)(1) through (b)(3) of this
section.
    (1) You must conduct the performance test at the absorber tail gas
vent, referred to as the test point, for each nitric acid train
according to Sec.  98.224(b) through (f).
    (2) You must conduct the performance test under normal process
operating conditions.
* * * * *
    (c) Using the results of the performance test in paragraph (b) of
this section, you must calculate an average site-specific emission
factor for each nitric acid train ``t'' according to Equation V-1 of
this section:

 [GRAPHIC] [TIFF OMITTED] TP15JN10.005

Where:

EFN2Ot = Average site-specific N2O emissions
factor for nitric acid train ``t'' (lb N2O generated/ton
nitric acid produced, 100 percent acid basis).
CN2O = N2O concentration for each test run
during the performance test (ppm N2O).
1.14 x 10-\7\= Conversion factor (lb/dscf-ppm
N2O).
Q = Volumetric flow rate of effluent gas for each test run during
the performance test (dscf/hr).
P = Production rate for each test run during the performance test
(tons nitric acid produced per hour, 100 percent acid basis).
n = Number of test runs.

    (d) If nitric acid train ``t'' exhausts to any N2O
abatement technology ``N'' after the test point, you must determine the
destruction efficiency for each N2O abatement technology
``N'' according to paragraphs (d)(1), (d)(2), or (d)(3) of this
section.
* * * * *
    (e) If nitric acid train ``t'' exhausts to any N2O
abatement technology ``N'' after the test point, you must determine the
annual amount of nitric acid produced on 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.

 [GRAPHIC] [TIFF OMITTED] TP15JN10.006

Where:

AFt,N = Abatement utilization factor of N2O
abatement technology ``N'' at nitric acid train ``t'' (fraction of
annual production that abatement technology is operating).
Pa t = Total annual nitric acid production from nitric
acid train ``t'' (ton acid produced, 100 percent acid basis).
Pa,t,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).

    (f) [Reserved]
    (g) You must calculate N2O emissions for each nitric
acid train ``t'' according to paragraph (g)(1) or (g)(2) of this
section.
    (1) If nitric acid train ``t'' exhausts to any N2O
abatement technology ``N'' after the 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-3a of this section:

[GRAPHIC] [TIFF OMITTED] TP15JN10.007

Where:

EN2Ot = N2O mass emissions per year for nitric
acid train ``t'' (metric tons).
EFN2Ot = Average site-specific N2O emissions
factor for nitric acid train ''t'' (lb N2O generated/ton
acid produced, 100 percent acid basis).
Pa t = Annual nitric acid production from the train ``t''
(ton acid produced, 100 percent acid basis).
DFt,N = Destruction efficiency of N2O
abatement technology N that is used on nitric acid train ``t''
(percent of N2O removed from air stream).
AFt,N = Abatement utilization factor of N2O
abatement technology ``N'' for nitric acid train ``t'' (fraction of
annual production that N2O abatement technology is
operating).
2204.63 = Conversion factor (lb/metric ton).
z = Number of N2O abatement technologies on nitric acid
train ``t''.

    (2) If nitric acid train ``t'' does not exhaust to any
N2O abatement technology after the test point, you must use
the emissions factor (determined in Equation V-1 of this section), and
the annual nitric acid production (determined in paragraph (i) of this
section) according to Equation V-3b of this section:

 [GRAPHIC] [TIFF OMITTED] TP15JN10.008

Where:

EN2Ot = N2O mass emissions per year for nitric
acid train ``t'' (metric tons).
EFN2Ot = Average site-specific N2O emissions
factor for nitric acid train ''t'' (lb N2O generated/ton
acid produced, 100 percent acid basis).
Pa, t = Annual nitric acid production from nitric acid
train ``t'' (ton acid produced, 100 percent acid basis).
2205 = Conversion factor (lb/metric ton).

* * * * *
    (i) You must determine the total annual amount of nitric acid
produced on nitric acid train ``t'' for each nitric acid train (tons
acid produced, 100 percent acid basis), according to Sec.  98.224(f).
    39. Section 98.224 is amended by:
    a. Revising paragraph (a).
    b. Revising the first sentence in paragraph (d) introductory text.
    c. Revising paragraphs (e) and (f).

Sec.  98.224  Monitoring and QA/QC requirements.

    (a) You must conduct a new performance test according to a test
plan as specified in paragraphs (a)(1) through (a)(3) of this section.
    (1) Conduct the performance test annually. The test should be
conducted at a point during the campaign which is representative of the
average emissions over the entire campaign. Facilities must document
the methods used to determine the representative point of the campaign
when the performance test is conducted.
    (2) Conduct the performance test when your nitric acid production
process is changed, specifically when abatement equipment is installed.
    (3) If you requested Administrator approval for an alternative
method of determining N2O emissions under Sec.
98.223(a)(2), you must conduct the performance test if your request has
not been approved by the Administrator within 150 days of the end of
the reporting year in which it was submitted.
* * * * *
    (d) You must determine the volumetric flow rate during the
performance test in conjunction with the applicable EPA methods in 40
CFR part 60, appendices A-1 through A-4. * * *
* * * * *
    (e) You must determine the total monthly amount of nitric acid
produced and the monthly amount of nitric acid produced while
N2O abatement technology (located after the test point) is
operating from each nitric acid train according to the methods in
paragraphs (c)(1) or (c)(2) of this section.
    (f) You must determine the annual amount of nitric acid produced
and the annual amount of nitric acid produced while N2O
abatement technology (located after the test point) is operating for
each train by summing the respective monthly nitric acid quantities
determined in paragraph (e) of this section.
    40. Section 98.226 is amended by revising the introductory text,
paragraph (g), and paragraphs (m) and (n) introductory text to read as
follows:

Sec.  98.226  Data reporting requirements.

    In addition to the information required by Sec.  98.3(c), each
annual report must contain the information specified in paragraphs (a)
through (o) of this section.
* * * * *
    (g) Number of different N2O abatement technologies per
nitric acid train ``t''.
* * * * *
    (m) If you conducted a performance test and calculated a site-
specific emissions factor according to Sec.  98.223(a)(1), each annual
report must also contain the information specified in paragraphs (m)(1)
through (m)(7) of this section.
* * * * *
    (n) If you requested Administrator approval for an alternative
method of determining N2O emissions under Sec.
98.223(a)(2), each annual report must also contain the information
specified in paragraphs (n)(1) through (n)(4) of this section for each
nitric acid production facility.
* * * * *

Subpart Z--[Amended]

    41. 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. Conduct the representative bulk sampling using the
appropriate industry consensus standard or applicable standard method
in the Association of Fertilizer and Phosphate Chemists Analytical
Methods Manual 10th Edition (incorporated by reference, see Sec.
98.7). 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 inorganic carbon content of each monthly
grab sample of phosphate rock (consumed in the production of phosphoric
acid) using the applicable standard method in the Association of
Fertilizer and Phosphate Chemists Analytical Methods Manual 10th
Edition (incorporated by reference, see Sec.  98.7).
* * * * *
    42. Section 98.265 is amended by revising the second sentence of
paragraph (a) to read as follows:

Sec.  98.265  Procedures for estimating missing data.

* * * * *
    (a) * * * Alternatively, you must determine substitute data value
by calculating the arithmetic average of the quality-assured values of
inorganic carbon contents of phosphate rock of origin i from samples
immediately

preceding and immediately following the missing data incident. * * *
* * * * *
    43. Section 98.266 is amended by revising the introductory text,
paragraph (c), and paragraph (f) introductory text; and by adding
paragraph (f)(9) to read as follows:

Sec.  98.266  Data reporting requirements.

    In addition to the information required by Sec.  98.3(c), each
annual report must contain the information specified in paragraphs (a)
through (f) of this section.
* * * * *
    (c) Annual arithmetic average percent inorganic carbon in phosphate
rock from monthly records (percent by weight, expressed as a decimal
fraction).
* * * * *
    (f) If you do not use a CEMS to measure emissions, then you must
report the information in paragraphs (f)(1) through (f)(9) of this
section.
* * * * *
    (9) Annual process CO2 emissions from phosphoric acid
production facility (metric tons).

Subpart CC--[Amended]

    44. Section 98.294 is amended by revising the third sentence of
paragraph (a)(1) to read as follows:

Sec.  98.294  Monitoring and QA/QC requirements.

* * * * *
    (a) * * *
    (1) * * * The modified method referred to above adjusts the regular
ASTM method to express the results in terms of trona.* * *
* * * * *
    45. Section 98.296 is amended by revising paragraphs (a)(1),
(b)(3), (b)(6), and (b)(10); and by removing paragraphs (11)(iv)
through (11)(vi) to read as follows:

Sec.  98.296  Data reporting requirements.

* * * * *
    (a) * * *
    (1) Annual consumption of trona or liquid alkaline feedstock for
each manufacturing line (tons).
* * * * *
    (b) * * *
    (3) Annual production of soda ash for each manufacturing line
(tons).
* * * * *
    (6) Monthly production of soda ash for each manufacturing line
(tons).
* * * * *
    (10) If you produce soda ash using the liquid alkaline feedstock
process and use the site-specific emission factor method (Sec.
98.293(b)(3)) to estimate emissions then you must report the following
relevant information for each manufacturing line or stack:
    (i) Stack gas volumetric flow rate during performance test (dscfm).
    (ii) Hourly CO2 concentration during performance test
(percent CO2).
    (iii) CO2 emission factor (metric tons CO2/
metric tons of process vent flow from mine water stripper/evaporator).
    (iv) CO2 mass emission rate during performance test
(metric tons/hour).
* * * * *

Subpart EE--[Amended]

    46. Section 98.314 is amended by revising paragraph (e) to read as
follows:

Sec.  98.314  Monitoring and QA/QC requirements.

* * * * *
    (e) You must determine the quantity of carbon-containing waste
generated from each titanium dioxide production line on a monthly basis
using plant instruments used for accounting purposes including direct
measurement weighing the carbon-containing waste not used during the
process (by belt scales or a similar device) or through the use of
sales records.
* * * * *
    47. Section 98.316 is amended by revising paragraphs (b)(9) and
(b)(11) to read as follows:

Sec.  98.316  Data reporting requirements.

* * * * *
    (b) * * *
    (9) Monthly carbon content factor of petroleum coke (percent by
weight expressed as a decimal fraction).
* * * * *
    (11) Carbon content for carbon-containing waste for each process
line (percent by weight expressed as a decimal fraction).
* * * * *

Subpart GG--[Amended]

    48. Section 98.333 is amended by revising the definitions of
``(Electrode)k'' and ``(CElectrode)
k'' in Equation GG-1 of paragraph (b)(1) to read as follows:

Sec.  98.333  Calculating GHG emissions.

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

(Electrode) k = Annual mass of carbon electrode consumed
in furnace ``k'' (tons).
(CElectrode)k = Carbon content of the carbon
electrode consumed in furnace ``k'', from the annual carbon analysis
(percent by weight, expressed as a decimal fraction).

* * * * *
    49. Section 98.336 is amended by revising paragraph (a)
introductory text; and by revising paragraphs (b)(1), (b)(7), and
(b)(10) to read as follows:

Sec.  98.336  Data reporting requirements.

* * * * *
    (a) If a CEMS is used to measure CO2 emissions, then you
must report under this subpart the relevant information required for
the Tier 4 Calculation Methodology in Sec.  98.36 and the information
listed in this paragraph (a):
* * * * *
    (b) * * *
    (1) Identification number and annual process CO2
emissions from each individual Waelz kiln or electrothermic furnace
(metric tons).
* * * * *
    (7) Carbon content of each carbon-containing input material charged
to each kiln or furnace (including zinc bearing material, flux
materials, and other carbonaceous materials) from the annual carbon
analysis or from information provided by the material supplier for each
kiln or furnace (percent by weight, expressed as a decimal fraction).
* * * * *
    (10) Carbon content of the carbon electrode used in each furnace
from the annual carbon analysis or from information provided by the
material supplier (percent by weight, expressed as a decimal fraction).
* * * * *

Subpart HH--[Amended]

    50. Section 98.340 is amended by revising paragraph (b) to read as
follows:

Sec.  98.340  Definition of the source category.

* * * * *
    (b) This source category does not include Resource Conservation and
Recovery Act (RCRA) Subtitle C or Toxic Substances Control Act (TSCA)
hazardous waste landfills, dedicated construction and demolition waste
landfills, or industrial waste landfills.
* * * * *
    51. Section 98.343 is amended by:
    a. In paragraph (a)(1), revising Equation HH-1 and the definitions
of ``x,'' ``S,'' ``WX,'' ``MCF,'' ``DOCF,''
``F,'' and ``k'' in Equation HH-1; and removing the definition of
``L0'' in Equation HH-1.
    b. Revising the last sentence of paragraph (a)(2).
    c. Redesignating paragraph (a)(3) as (a)(4) and revising new
paragraph (a)(4).
    d. Adding a new paragraph (a)(3).
    e. Revising paragraph (b)(1), and revising paragraph (b)(2)
introductory text.

    f. Revising paragraphs (b)(2)(ii), (b)(2)(iii)(A), and
(b)(2)(iii)(B); and revising paragraph (c) introductory text.

Sec.  98.343  Calculating GHG emissions.

    (a) * * *
    (1) * * *
    [GRAPHIC] [TIFF OMITTED] TP15JN10.009

* * * * *
x = Year in which waste was disposed.
    S = Start year of calculation. Use the year 1960 or the opening
year of the landfill, whichever is more recent.
* * * * *
WX = Quantity of waste disposed in the landfill in year x
from measurement data, tipping fee receipts, or other company
records (metric tons, as received (wet weight)).
MCF = Methane correction factor (fraction). Use the default value of
1
* * * * *
    DOCF = Fraction of DOC dissimilated (fraction). Use
the default value of 0.5.
F = Fraction by volume of CH4 in landfill gas from
measurement data on a dry basis, if available (fraction); default is
0.5.
k = Rate constant from Table HH-1 of this subpart
(yr-\1\). Select the most applicable k value for the
majority of the past 10 years (or operating life, whichever is
shorter).

    (2) * * * For years when waste composition data are not available,
use the bulk waste parameter values for k and DOC in Table HH-1 of this
subpart for the total quantity of waste disposed in those years.
    (3) Beginning in the first emissions monitoring year (2010 or
later) and for each year thereafter, if scales are in place, you must
determine the annual quantity of waste (in metric tons as received,
i.e., wet weight) disposed of in the landfill using paragraph (a)(3)(i)
of this section for all containers and for all vehicles, other than
passenger cars or light duty pickup trucks, used to haul waste to the
landfill. If scales are not in place, you must use paragraph (a)(3)(ii)
of this section to determine the annual quantity of waste disposed. For
waste hauled to the landfill in passenger cars or light duty pickup
trucks, you may use either paragraph (a)(3)(i) or paragraph (a)(3)(ii)
of this section to determine the annual quantity of waste disposed. The
approach used to determine the annual quantity of waste disposed of
must be documented in the monitoring plan.
    (i) Use direct mass measurements of each individual load received
at the landfill using either of the following methods:
    (A) Weigh using mass scales each vehicle or container used to haul
waste as it enters the landfill or disposal area; weigh using mass
scales each vehicle or container after it has off-loaded the waste;
determine the quantity of waste received from the individual load as
the difference in the two mass measurements; and determine the annual
quantity of waste received as the sum of all waste loads received
during the year. Alternatively, you may determine annual quantity of
waste by summing the weights of all vehicles and containers entering
the landfill and subtracting from it the sum of all the weights of
vehicles and containers after they have off-loaded the waste in the
landfill.
    (B) Weigh using mass scales each vehicle or container used to haul
waste as it enters the landfill or disposal area; determine a
representative tare weight by vehicle or container type by weighing no
less than 5 of each type of vehicle or container after it has off-
loaded the waste; determine the quantity of waste received from the
individual load as the difference between the measured weight in and
the tare weight determined for that container/vehicle type; and
determine the annual quantity of waste received as the sum of all waste
loads received during the year.
    (ii) Determine the working capacity in units of mass for each type
of container or vehicle used to haul waste to the landfill (e.g., using
volumetric capacity and waste density measurements; direct measurement
of a selected number of passenger vehicles and light duty pick-up
trucks; or similar methods); record the number of loads received at the
landfill by vehicle/container type; calculate the annual mass per
vehicle/container type as the mass product of the number of loads of
that vehicle/container multiplied by its working capacity; and
calculate the annual quantity of waste received as the sum of the
annual mass per vehicle/container type across all of the vehicle/
container types used to haul waste to the landfill.
    (4) For years prior to the first emissions monitoring year, use
methods in paragraph (a)(3) of this section when waste disposal
quantity data are readily available. When waste disposal quantity data
are not readily available, Wx shall be estimated using one
of the applicable methods in paragraphs (a)(4)(i) through (a)(4)(iii)
of this section. You must determine which method is most applicable to
the conditions and disposal history of your facility. Historical waste
disposal quantities should only be determined once, as part of the
first annual report, and the same values should be used for all
subsequent annual reports, supplemented by the next year's data on new
waste disposal.
    (i) Assume all prior years waste disposal quantities are the same
as the waste quantity in the first year for which waste quantities are
available.
    (ii) Use the estimated population served by the landfill in each
year, the values for national average per capita waste generation, and
fraction of generated waste disposed of in solid waste disposal sites
found in Table HH-2 of this subpart, and calculate the waste quantity
landfilled using Equation HH-2 of this section.
[GRAPHIC] [TIFF OMITTED] TP15JN10.010

Where:
Wx = Quantity of waste placed in the landfill in year x
(metric tons, wet basis).
POPx = Population served by the landfill in year x from
city population, census data, or other estimates (capita).
WDRx = Average per capita waste disposal rate for year x
from Table HH-2 of this subpart (metric tons per capita per year,
wet basis; tons/cap/yr).

    (iii) Use a constant average waste disposal quantity calculated
using Equation HH-3 of this section for each year the landfill was in
operation (i.e., from the first year accepting waste until the last
year for which waste disposal data is unavailable, inclusive).
[GRAPHIC] [TIFF OMITTED] TP15JN10.011

Where:

WX = Quantity of waste placed in the landfill in year x
(metric tons, wet basis).
LFC = Landfill capacity or, for operating landfills, capacity of the
landfill used (or the total quantity of waste-in-place) at the end
of the year prior to the year when waste disposal data are available
from design drawings or engineering estimates (metric tons).
YrData = Year in which the landfill last received waste or, for
operating landfills, the year prior to the first reporting year when
waste disposal data is first available from company records, or best
available data.
YrOpen = Year in which the landfill first received waste from
company records or best available data. If no data are available for
estimating YrOpen for a closed landfill, use 30 years as the default
operating life of the landfill.

    (b) * * *
    (1) If you continuously monitor the flow rate, CH4
concentration, temperature, pressure, and, if necessary, moisture
content of the landfill gas that is collected and routed to a
destruction device (before any treatment equipment) using a monitoring
meter specifically for CH4 gas, as specified in Sec.
98.344, you must use this monitoring system and calculate the quantity
of CH4 recovered for destruction using Equation HH-4 of this
section. A fully integrated system that directly reports CH4
content requires no other calculation than summing the results of all
monitoring periods for a given year.
[GRAPHIC] [TIFF OMITTED] TP15JN10.012

Where:
R = Annual quantity of recovered CH4 (metric tons
CH4).
N = Total number of measurement periods in a year. Use daily
averaging periods for continuous monitoring system and N = 365 (or N
= 366 for leap years). For weekly sampling, as provided in paragraph
(b)(2) of this section, use N = 52.
n = Index for measurement period.
(V)n = Cumulative volumetric flow for the measurement
period in actual cubic feet (acf). If the flow rate meter
automatically corrects for temperature and pressure, replace ``520
[deg] R/(T)n x (P)n/1 atm'' with ``1''.
(KMC)n = Moisture correction term for the
measurement period, volumetric basis, as follows:
(KMC)n = 1 when (V)n and
(C)n are both measured on a dry basis or if both are
measured on a wet basis; (KMC)n = [1 -
(fH2O)n] when (V)n is measured on a
wet basis and (C)n is measured on a dry basis; and
(KMC)n = 1/[1 - (fH2O)n]
when (V)n is measured on a dry basis and (C)n
is measured on a wet basis.
(fH2O)n = Average moisture content of landfill
gas during the measurement period, volumetric basis (cubic feet
water per cubic feet landfill gas).
(CCH4)n = Average CH4 concentration
of landfill gas for the measurement period (volume %).
0.0423 = Density of CH4 lb/cf at 520 [deg] R or 60[deg] F
and 1 atm.
(T)n = Temperature at which flow is measured for the
measu rement period ([deg] R).
(P)n = Pressure at which flow is measured for the
measurement period (atm).
0.454/1,000 = Conversion factor (metric ton/lb).

    (2) If you do not continuously monitor according to paragraph
(b)(1) of this section, you must determine the flow rate,
CH4 concentration, temperature, pressure, and moisture
content of the landfill gas that is collected and routed to a
destruction device (before any treatment equipment) according to the
requirements in paragraphs (b)(2)(i) through (b)(2)(iii) of this
section and calculate the quantity of CH4 recovered for
destruction using Equation HH-4 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 once each calendar week, with at least
three 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 once each calendar week, with at least three 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 once each calendar week, with at least
three days between measurements.
    (c) For all landfills, calculate CH4 generation
(adjusted for oxidation in cover materials) and actual CH4
emissions (taking into account any CH4 recovery, and
oxidation in cover materials) according to the applicable methods in
paragraphs (c)(1) through (c)(3) of this section.
* * * * *
    52. Section 98.344 is amended by:
    a. Revising paragraph (a).
    b. Revising the first sentence of paragraph (b).
    c. Revising paragraphs (b)(6)(ii), (b)(6)(ii)(A), and
(b)(6)(ii)(B).
    d. Revising the definition of ``CCH4'' in Equation HH-9
of paragraph (b)(6)(iii).
    e. Revising the second and third sentences of paragraph (c).
    f. Revising paragraph (d).
    g. Amending paragraph (e) by revising the first sentence.

Sec.  98.344  Monitoring and QA/QC requirements.

    (a) Mass measurement equipment used to determine the quantity of
waste landfilled on or after January 1, 2010 must meet the requirements
for weighing equipment as described in ``Specifications, Tolerances,
and Other Technical Requirements For Weighing and Measuring Devices''
NIST Handbook 44 (2009) (incorporated by reference, see Sec.  98.7).
    (b) For landfills with gas collection systems, operate, maintain,
and calibrate a gas composition monitor capable of measuring the
concentration of CH4 in the recovered landfill gas using one
of the methods specified in paragraphs (b)(1) through (b)(6) of this
section or as specified by the manufacturer. * * *
* * * * *
    (6) * * *
    (ii) Determine a non-methane organic carbon correction factor at
the routine sampling location no less frequently than once a reporting
year following the requirements in paragraphs (b)(6)(ii)(A) through
(b)(6)(ii)(C) of this section.
    (A) Take a minimum of three grab samples of the landfill gas with a
minimum of 20 minutes between samples and determine the methane
composition of the landfill gas using one of the methods specified in
paragraphs (b)(1) through (b)(5) of this section.
    (B) As soon as practical after each grab sample is collected and
prior to the

collection of a subsequent grab sample, determine the total gaseous
organic concentration of the landfilll gas using either Method 25A or
25B at 40 CFR part 60, appendix A-7 as specified in paragraph (b)(6)(i)
of this section.
* * * * *
    (iii) * * *

CCH4 = Methane concentration in the landfill gas (volume
%) for use in Equation HH-4.
* * * * *
    (c) * * * Each gas flow meter shall be recalibrated either
biennially (every 2 years) or at the minimum frequency specified by the
manufacturer. Except as provided in Sec.  98.343(b)(2)(i), each gas
flow meter must be capable of correcting for the temperature and
pressure and, if necessary, moisture content.
* * * * *
    (d) All temperature, pressure, and if necessary, moisture content
monitors must be calibrated using the procedures and frequencies
specified by the manufacturer.
    (e) 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. * * *
    53. Section 98.346 is amended by revising paragraphs (a), (b),
(d)(1), (f), (h), (i)(1), (i)(2), (i)(3), (i)(4), (i)(5), and (i)(7) to
read as follows:

Sec.  98.346  Data reporting requirements.

* * * * *
    (a) A classification of the landfill as ``open'' (actively received
waste in the reporting year) or ``closed'' (no longer receiving waste),
the year in which the landfill first started accepting waste for
disposal, the last year the landfill accepted waste (for open
landfills, enter the estimated year of landfill closure), the capacity
(in metric tons) of the landfill, an indication of whether leachate
recirculation is used during the reporting year and its typical
frequency of use over the past 10 years (e.g., used several times a
year for the past 10 years, used at least once a year for the past 10
years, used occasionally but not every year over the past 10 years, not
used), an indication as to whether scales are present at the landfill,
and the waste disposal quantity for each year of landfilling required
to be included when using Equation HH-1 of this subpart (in metric
tons, wet weight).
    (b) Method for estimating reporting year and historical waste
disposal quantities, reason for its selection, and the range of years
it is applied. For years when waste quantity data are determined using
the methods in Sec.  98.343(a)(3), report separately the quantity of
waste determined using the methods in Sec.  98.343(a)(3)(i) and the
quantity of waste determined using the methods in Sec.
98.343(a)(3)(ii). For historical waste disposal quantities that were
not determined using the methods in Sec.  98.343(a)(3), provide the
population served by the landfill for each year the Equation HH-2 of
this subpart is applied, if applicable, or, for open landfills using
Equation HH-3 of this subpart, provide the value of landfill capacity
(LFC) used in the calculation.
* * * * *
    (d) * * *
    (1) Degradable organic carbon (DOC), methane correction factor
(MCF), and fraction of DOC dissimilated (DOCF) values used
in the calculations.
* * * * *
    (f) The surface area of the landfill containing waste (in square
meters), identification of the type of cover material used (as either
organic cover, clay cover, sand cover, or other soil mixtures). If
multiple cover types are used, the surface area associated with each
cover type.
* * * * *
    (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, 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) * * *
    (1) Total volumetric flow of landfill gas collected for destruction
for the reporting year (cubic feet at 520 [deg]R or 60 [deg]F and 1
atm).
    (2) Annual average CH4 concentration of landfill gas
collected for destruction (percent by volume).
    (3) Monthly average temperature and pressure for each month at
which flow is measured for landfill gas collected for destruction, or
statement that temperature and/or pressure is incorporated into
internal calculations run by the monitoring equipment.
    (4) An indication as to whether flow was measured on a wet or dry
basis, an indication as to whether CH4 concentration was
measured on a wet or dry basis, and if required for Equation HH-4,
monthly average moisture content for each month at which flow is
measured for landfill gas collected for destruction.
    (5) An indication of whether destruction occurs at the landfill
facility or off-site. If destruction occurs at the landfill facility,
also report an indication of whether a back-up destruction device is
present at the landfill, the annual operating hours for the primary
destruction device, the annual operating hours for the back-up
destruction device (if present), and the destruction efficiency used
(percent).
* * * * *
    (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 of
this subpart, the estimated gas collection system efficiency for
landfills with this gas collection system, the annual operating hours
of the gas collection system, 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.
* * * * *
    54. Section 98.347 is amended by adding a second sentence to the
introductory text to read as follows:

Sec.  98.347  Records that must be retained.

    * * * You must retain records of all measurements made to determine
tare weights and working capacities by vehicle/container type if these
are used to determine the annual waste quantities.
    55. Section 98.348 is revised to read as follows:

Sec.  98.348  Definitions.

    Except as specified in this section, all terms used in this subpart
have the same meaning given in the Clean Air Act and subpart A of this
part.
    Dedicated construction and demolition landfill means a landfill
that only receives materials generated from the construction or
destruction of structures such as buildings, roads, and bridges.
    Destruction device means a flare, thermal oxidizer, boiler,
turbine, internal combustion engine, or any other combustion unit used
to destroy or oxidize methane contained in landfill gas.
    Industrial waste landfill means any landfill other than a municipal
solid waste landfill, a RCRA Subtitle C hazardous waste landfill, or a
TSCA hazardous waste landfill, in which industrial solid waste, such a
RCRA Subtitle D wastes (nonhazardous industrial solid waste, defined in
40 CFR 257.2), commercial solid wastes, or conditionally exempt small
quantity generator wastes, is placed. An

industrial waste landfill includes all disposal areas at the facility.
    Solid waste has the meaning established by the Administrator
pursuant to the Solid Waste Disposal Act [42 U.S.C.A. 6901 et seq.]
    Working capacity means the maximum volume or mass of waste that is
actually placed in the landfill from an individual or representative
type of container (such as a tank, truck, or roll-off bin) used to
convey wastes to the landfill, taking into account that the container
may not be able to be 100 percent filled and/or 100 percent emptied for
each load.
    56. Table HH-1 to subpart HH is amended by:
    a. Revising the entries for ``k (precipitation <20 inches/year and
no leachate recirculation),'' ``k (precipitation 20-40 inches/year and
no leachate recirculation),'' and ``k (precipitation >40 inches/year or
for landfill areas with leachate recirculation).''
    b. Adding an entry for ``DOC (bulk waste)'' to follow the revised
entry for ``k (precipitation plus recirculated leachate\a\ >40 inches/
year).''
    c. Removing the entry for ``L0 (Equivalent to DOC =
0.2028 when MCF = 1, DOCF = 0.5, and F = 0.5).''
    d. Adding an entry for ``DOC (inerts, e.g. glass, plastics, metal,
cement)'' to follow the entry for ``DOC (sewage sludge).''
    e. Revising the entries for ``k (food waste),'' ``k (garden),'' ``k
(paper),'' ``k (wood and straw),'' ``k (textiles),'' ``k (diapers),''
and ``k (sewage sludge).''
    f. Adding a new entry for ``k (inerts e.g. glass, plastics, metal,
cement).''
    g. Redesignating footnote ``a'' as footnote ``b,'' and revising new
footnote ``b.''
    h. Adding a new footnote ``a.''

                   Table HH-1 to Subpart HH--Emissions Factors, Oxidation Factors and Methods
----------------------------------------------------------------------------------------------------------------
                  Factor                                Default value                           Units
----------------------------------------------------------------------------------------------------------------
                                         Waste Model--Bulk Waste Option
----------------------------------------------------------------------------------------------------------------
k (precipitation plus recirculated         0.02...................................  yr-1.
 leachate \a\ <20 inches/year).
k (precipitation plus recirculated         0.038..................................  yr-1.
 leachate \a\ 20-40 inches/year).
k (precipitation plus recirculated         0.057..................................  yr-1.
 leachate \a\ >40 inches/year).
DOC (bulk waste).........................  0.20...................................  Weight fraction, wet basis.

                                                  * * * * * * *
DOC (inerts, e.g. glass, plastics, metal,  0.00...................................  Weight fraction, wet basis.
 cement).

                                                  * * * * * * *
k (food waste)...........................  \b\ 0.06 to 0.185......................  yr-1.
k (garden)...............................  \b\ 0.05 to 0.10.......................  yr-1.
k (paper)................................  \b\ 0.04 to 0.06.......................  yr-1.
k (wood and straw).......................  \b\ 0.02 to 0.03.......................  yr-1.
k (textiles).............................  \b\ 0.04 to 0.06.......................  yr-1.
k (diapers)..............................  \b\ 0.05 to 0.10.......................  yr-1.
k (sewage sludge)........................  \b\ 0.06 to 0.185......................  yr-1.
k (inerts e.g. glass, plastics, metal,     \b\ 0.00...............................  yr-1.
 cement).

                                                  * * * * * * *
----------------------------------------------------------------------------------------------------------------
\a\ Recirculated leachate (in inches/year) is the total volume of leachate recirculated divided by the area of
  the portion of the landfill containing waste with appropriate unit conversions.
\b\ Use the lesser value when the potential evapotranspiration rate exceeds the mean annual precipitation rate
  plus recirculated leachate. Use the greater value when the potential evapotranspiration rate does not exceed
  the mean annual precipitation rate plus recirculated leachate.

    57. Table HH-2 to subpart HH is amended by:
    a. Removing the entries for ``1950'' through ``1959.''
    b. Revising the entries for ``1989'' through ``2006.''
    c. Adding entries for ``2007'' through ``2009.''

     Table HH-2 to Subpart HH--U.S. Per Capita Waste Disposal Rates
------------------------------------------------------------------------
                Year                     Waste per capita ton/cap/yr
------------------------------------------------------------------------

                                * * * * *
                   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                                 0.95
------------------------------------------------------------------------

    58. Table HH-3 to subpart HH-3 is amended by revising the entries
for ``A2: Area without active gas collection, regardless of cover type
H2: Average depth of waste in area A2,'' ``A3: Area with daily soil
cover and active gas collection H3: Average depth of waste in area
A3,'' ``A4: Area with an intermediate soil cover and active gas
collection H4: Average depth of waste in area A4,'' and ``A5: Area with
a final soil and geomembrane cover system and active gas collection H5:
Average depth of waste in area A5'' to read as follows:

     Table HH-3 to Subpart HH--Landfill Gas Collection Efficiencies
------------------------------------------------------------------------
                                              Landfill gas collection
               Description                          efficiency
------------------------------------------------------------------------

                              * * * * * * *
A2: Area without active gas collection,   CE2: 0%.
 regardless of cover type.
A3: Area with daily soil cover and        CE3: 60%.
 active gas collection.
A4: Area with an intermediate soil        CE4: 75%.
 cover, or a final soil cover not
 meeting the criteria for A5 below, and
 active gas collection.
A5: Area with a final soil cover of 3     CE5: 95%.
 feet or thicker of clay and/or
 geomembrane cover system and active gas
 collection.

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

Subpart LL--[Amended]

    59. Section 98.386 is amended by adding a third sentence to
paragraphs (a)(5) and (a)(6) to read as follows:

Sec.  98.386  Data reporting requirements.

* * * * *
    (a) * * *
    (5) * * * Those products that enter the facility, but are not
reported in (a)(1), shall not be reported under this paragraph.
    (6) * * * Those products that enter the facility, but are not
reported in (a)(2), shall not be reported under this paragraph.
* * * * *

Subpart MM--[Amended]

    60. Section 98.393 is amended by:
    a. In paragraph (a)(1), revising the only sentence and the
definition of ``Producti'' in Equation MM-1.
    b. Revising the definition of ``Producti'' in Equation
MM-2 of paragraphs (a)(2).
    c. Revising the only sentence of paragraph (b)(1) and the first
sentence in paragraph (f)(1).
    d. Revising the definition of ``%Voli'' in Equation MM-8
in paragraph (h)(1).
    e. Revising Equation MM-9 and the definition of
``%Volj'' in paragraph (h)(2).
    f. Revising paragraphs (h)(3) and (h)(4).
    g. Adding paragraph (i).

Sec.  98.393  Calculating GHG emissions.

    (a) * * *
    (1) Except as provided in paragraphs (h) and (i) of this section,
any refiner, importer, or exporter shall calculate CO2
emissions from each individual petroleum product and natural gas liquid
using Equation MM-1 of this section.
* * * * *
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)(1). For natural gas liquids, volumes shall
reflect the individual components of the product as listed in Table
MM-1 of this subpart.
* * * * *
    (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)(1).
* * * * *
    (b) * * *
    (1) Except as provided in paragraphs (h) and (i) of this section,
any refiner shall calculate CO2 emissions from each non-
crude feedstock using Equation MM-2 of this section.
* * * * *
    (f) * * *
    (1) Calculation Method 1. To determine the emission factor (i.e.,
EFi in Equation MM-1) for solid products, multiply the
default carbon share factor (i.e., percent carbon by mass) in column B
of Table MM-1 of this subpart for the appropriate product by 44/12. * *
*
* * * * *
    (h) * * *
    (1) * * *

%Voli = Percent volume of product ``i'' that is
petroleum-based, not including any denaturant that may be present in
any ethanol product, expressed as a fraction (e.g., 75% would be
expressed as 0.75 in the above equation).

    (2) * * *
    [GRAPHIC] [TIFF OMITTED] TP15JN10.013

* * * * *
%Volj = Percent volume of feedstock ``j'' that is
petroleum-based, not including any denaturant that may be present in
any ethanol product, expressed as a fraction (e.g., 75% would be
expressed as 0.75 in the above equation).

    (3) Calculation Method 2 procedures for products.
    (i) A reporter using Calculation Methodology 2 of this subpart to
determine the emission factor of a petroleum product that does not
contain denatured ethanol must calculate the CO2 emissions
associated with that product using Equation MM-10 of this section in
place of Equation MM-1 of this section.
[GRAPHIC] [TIFF OMITTED] TP15JN10.014

Where:

    CO2i = Annual CO2 emissions that would
result from the complete combustion or oxidation of each product
``i'' (metric tons).
Producti = Annual volume of each petroleum product ``i''
produced, imported, or exported by the reporting party (barrels).
For refiners, this volume only includes products ex refinery gate.
EFi = Product-specific CO2 emission factor
(metric tons CO2 per barrel).
EFm = Default CO2 emission factor from Table
MM-2 of this subpart that most closely represents the component of
product ``i'' that is biomass-based.
%Volm = Percent volume of petroleum product ``i'' that is
biomass-based,

expressed as a fraction (e.g., 75% would be expressed as 0.75 in the
above equation).

    (ii) In the event that a petroleum product contains denatured
ethanol, importers and exporters must follow Calculation Method 1
procedures in paragraph (h)(1); and refineries must sample the
petroleum portion of the blended biomass-based fuel prior to blending
and calculate CO2 emissions using Equation MM-10a of this
section.
[GRAPHIC] [TIFF OMITTED] TP15JN10.015

Where:

CO2i = Annual CO2 emissions that would result
from the complete combustion or oxidation of each biomass-blended
fuel ``i'' (metric tons).
Productp = Annual volume of the petroleum-based portion
of each biomass blended fuel ``i'' produced by the refiner
(barrels).
EFi = Petroleum product-specific CO2 emission
factor (metric tons CO2 per barrel).

    (4) Calculation Method 2 procedures for non-crude feedstocks.
    (i) A refiner using Calculation Method 2 of this subpart to
determine the emission factor of a non-crude petroleum feedstock that
does not contain denatured ethanol must calculate the CO2
emissions associated with that feedstock using Equation MM-11 of this
section in place of Equation MM-2 of this section.
[GRAPHIC] [TIFF OMITTED] TP15JN10.016

Where:

    CO2j = (Feedstockj * EFj)-
(Feedstockj * EFm * %Volm) (Eq. MM-
11)
Where:

CO2j = Annual CO2 emissions that would result
from the complete combustion or oxidation of each non-crude
feedstock ``j'' (metric tons).
Feedstockj = Annual volume of each petroleum product
``j'' that enters the refinery to be further refined or otherwise
used on site (barrels).
EFj = Feedstock-specific CO2 emission factor
(metric tons CO2 per barrel).
EFm = Default CO2 emission factor from Table
MM-2 of this subpart that most closely represents the component of
petroleum product ``j'' that is biomass-based.
%Volm = Percent volume of non-crude feedstock ``j'' that
is biomass-based, expressed as a fraction (e.g., 75% would be
expressed as 0.75 in the above equation).

    (ii) In the event that a non-crude feedstock contains denatured
ethanol, refiners must follow Calculation Method 1 procedures in
paragraph (h) (2) of this section.
    (i) Optional procedures for blended products that do not contain
biomass.
    (1) In the event that a reporter produces, imports, or exports a
blended product that does not include biomass, the reporter may
calculate emissions for the blended product according to the method in
paragraph (i)(2) of this section. In the event that a refiner receives
a blended non-crude feedstock that does not include biomass, the
refiner may calculate emission for the blended non-crude feedstock
according to the method in paragraph (i)(3) of this section. The
procedures in this section may be used only if all of the following
criteria are met:
    (i) The reporter knows the relative proportion of each component of
the blend (i.e., the mass or volume percentage).
    (ii) Each component of blended product ``i '' or blended non-crude
feedstock ``j '' meets the strict definition of a product listed in
Table MM-1.
    (iii) The blended product or non-crude feedstock is not comprised
entirely of natural gas liquids.
    (iv) The reporter uses Calculation Method 1.
    (v) Solid components are blended only with other solid components.
    (2) The reporter must calculate emissions for the blended product
using Equation MM-12 of this section in place of Equation MM-1 of this
section.
[GRAPHIC] [TIFF OMITTED] TP15JN10.017

Where:

CO2i = Annual CO2 emissions that would result
from the complete combustion or oxidation of a blended product ''i''
(metric tons).
Blending Componenti[hellip]n = Annual volume or mass of
each blending component that is blended (barrels or metric tons).
EFi[hellip]n = CO2  emission factors specific
to each blending component (metric tons CO2 per barrel or
per metric ton of product).
n = Number of blending components blended into blended product
''i''.

    (3) For refineries, the reporter must calculate emissions for the
blended non-crude feedstock using Equation MM-13 of this section in
place of Equation MM-2 of this section.
[GRAPHIC] [TIFF OMITTED] TP15JN10.018

Where:

CO2j = Annual CO2 emissions that would result
from the complete combustion or oxidation of a blended non-crude
feedstock ''j'' (metric tons).
Blending Componenti * * * n = Annual volume or mass of
each blending component that is blended (barrels or metric tons).
EFi * * * n = CO 2 emission factors specific
to each blending component (metric tons CO2 per barrel or
per metric ton of product).
n = Number of blending components blended into blended non-crude
feedstock ``j''.

    (4) For refineries, if a blending component ``k'' used in paragraph
(i)(2) of this section enters the refinery before blending as non-crude
feedstock:
    (i) The emissions that would result from the complete combustion or
oxidation of non-crude feedstock ``k'' must still be calculated
separately using Equation MM-2 of this section and applied in Equation
MM-4 of this section.
    (ii) The quantity of blending component `` k'' applied in Equation
MM-12 of this section and the quantity of non-crude feedstock ``k''
applied in Equation MM-2 of this section must be determined using the
same method or practice.
    61. Section 98.394 is amended by revising paragraphs (d)(1),
(d)(3), and (d)(4) to read as follows:

Sec.  98.394   Monitoring and QA/QC requirements.

    (d) * * *
    (1) A representative sample or multiple representative samples of
each batch of crude oil shall be taken according to an appropriate
standard method published by a consensus-based standards organization.
* * * * *
    (3) API gravity shall be measured using an appropriate standard
method published by a consensus-based standards organization. The
weighted average API gravity for each batch shall be calculated by
multiplying the volume associated with each representative sample by
the API gravity, adding these values for all the samples, and then
dividing that total value by the volume of the batch.
    (4) Sulfur content shall be measured using an appropriate standard
method published by a consensus-based standards organization. The
weighted average sulfur content for each batch shall be calculated by
multiplying the volume associated with each representative sample by
the sulfur content, adding these values for all the samples, and then
dividing that total value by the volume of the batch.
* * * * *
    62. Section 98.396 is amended by:
    a. Revising paragraph (a)(3).
    b. Amending paragraphs (a)(5) and (a)(6) by adding a third
sentence.
    c. Revising paragraphs (a)(7), (a)(20)(ii), (a)(20)(iii), (b)(3),
and (c)(3).
    d. Adding a new paragraph (d).

Sec.  98.396  Data reporting requirements.

* * * * *
    (a) * * *
    (3) For each feedstock reported in paragraph (a)(2) of this section
that was produced by blending a petroleum-based product with a biomass-
based product, report the percent of the volume reported in paragraph
(a)(2) of this section that is petroleum-based (excluding any
denaturant that may be present in any ethanol product).
* * * * *
    (5) * * * Petroleum products and natural gas liquids that enter the
refinery, but are not reported in (a)(1), shall not be reported under
this paragraph.
    (6) * * * Petroleum products and natural gas liquids that enter the
refinery, but are not reported in (a)(2), shall not be reported under
this paragraph.
    (7) For each product reported in paragraph (a)(6) of this section
that was produced by blending a petroleum-based product with a biomass-
based product, report the percent of the volume reported in paragraph
(a)(6) of this section that is petroleum-based (excluding any
denaturant that may be present in any ethanol product).
* * * * *
    (20) * * *
    (ii) Weighted average API gravity of the batch at the point of
entry at the refinery.
    (iii) Weighted average sulfur content of the batch at the point of
entry at the refinery.
* * * * *
    (b) * * *
    (3) For each product reported in paragraph (b)(2) of this section
that was produced by blending a petroleum-based product with a biomass-
based product, report the percent of the volume reported in paragraph
(b)(2) of this section that is petroleum-based (excluding any
denaturant that may be present in any ethanol product).
* * * * *
    (c) * * *
    (3) For each product reported in paragraph (c)(2) of this section
that was produced by blending a petroleum-based product with a biomass-
based product, report the percent of the volume reported in paragraph
(c)(2) of this section that is petroleum based (excluding any
denaturant that may be present in any ethanol product).
* * * * *
    (d) Blended non-crude feedstock and products.
    (1) Refineries, exporters, and importers must report the following
information for each blended product and non-crude feedstock where
emissions were calculated according to Sec.  98.393(i):
    (i) Volume or mass of each blending component.
    (ii) The CO2 emissions in metric tons that would result
from the complete combustion or oxidation of each blended non-crude
feedstock or product, using Equation MM-12 or Equation MM-13 of this
section.
    (2) For a product that enters the refinery to be further refined or
otherwise used on site that is a blended non-crude feedstock, refiners
must meet the reporting requirements of paragraphs (a)(1) and (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)(5), (a)(6), (b)(1), (b)(2),
(c)(1), and (c)(2) of this section, as applicable, by reflecting the
individual components of the blended product.

Sec.  98.397  [Amended]

    63. Section 98.397 is amended by removing paragaph (e); and by
redesignating paragraphs (f) and (g) as (e) and (f), respectively.
    64. Section 98.398 is revised to read as follows:

Sec.  98.398  Definitions.

    Except as specified in this section, all terms used in this subpart
have the same meaning given in the Clean Air Act and subpart A of this
part.
    Batch means up to a calendar month of crude oil volume from a
single country of origin or up to a calendar month of crude oil volume
for which the country of origin is unknown.

Subpart NN--[Amended]

    65. Section 98.403 is amended by:
    a. Revising the definitions of ``Fuel'' and ``HHV'' in Equation NN-
1 of paragraph (a)(1).
    b. Revising the definition of ``Fuel'' in Equation NN-2 of
paragraph (a)(2).
    c. Revising the definition of ``Fuel1'' in Equation NN-5
of paragraph (b)(3).
    d. Revising the definition of ``EF'' in Equation NN-7 of paragraph
(c)(1).
    e. In paragraph (c)(2), revising Equation NN-8 and the definition
of ``CO2i'' in Equation NN-8.

Sec.  98.403  Calculating GHG emissions.

    (a) * * *
    (1) * * *

Fuelh = Total annual volume of product ``h'' supplied
(volume per year, in thousand standard cubic feet (Mscf) for natural
gas and bbl for NGLs).
HHVh = Higher heating value of product ``h'' supplied
(MMBtu/Mscf or MMBtu/bbl).

* * * * *
    (2) * * *

    Fuelh = Total annual volume of product ``h'' supplied
(bbl or Mscf per year).

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

Fuel1 = Total annual volume of natural gas received by
the LDC at the city gate and stored on-system or liquefied and
stored in the reporting year (Mscf per year).

* * * * *
    (c) * * *
    (1) * * *

EFg = Fuel-specific CO2 emission factor of NGL
product ``g'' (MT CO2/bbl).

    (2) * * *
    [GRAPHIC] [TIFF OMITTED] TP15JN10.019

* * * * *

CO2i = Annual CO2 mass emissions that would
result from the combustion or oxidation of fractionated NGLs
delivered to all customers or on behalf of customers as calculated
in paragraph (a)(1) or (a)(2) of this section (metric tons).

* * * * *
    66. Section 98.406 is amended by revising paragraphs (a)(6) and
(a)(9) introductory text to read as follows:

Sec.  98.406  Data reporting requirements.

    (a) * * *
    (6) Annual CO2 emissions (metric tons) that would result
from the complete combustion or oxidation of the quantities in
paragraphs (a)(1) and (a)(2) of this section, calculated in accordance
with Sec.  98.403(a) and (c)(1).
* * * * *
    (9) If the NGL fractionator developed reporter-specific EFs or
HHVs, report the following for each product type:
* * * * *
    67. Section 98.407 is amended by revising paragraphs (a) and (d) to
read as follows:

Sec.  98.407  Records that must be retained.

* * * * *
    (a) Records of all meter readings and documentation to support
volumes of natural gas and NGLs that are reported under this part.
* * * * *
    (d) Records related to the large end-users identified in Sec.
98.406(b)(7).
* * * * *
    68. Tables NN-1 and NN-2 to Subpart NN are amended to read as
follows:

 Table NN-1 to Subpart NN--Default Factors for Calculation Methodology 1
                             of This Subpart
------------------------------------------------------------------------
                                 Default high
             Fuel                heating value     Default CO2 emission
                                    factor        factor (kg CO2/MMBtu)
------------------------------------------------------------------------
Natural Gas..................  1.028 MMBtu/Mscf                    53.02
Propane......................  3.822 MMBtu/bbl.                    61.46
Normal butane................  4.242 MMBtu/bbl.                    65.15
Ethane.......................  4.032 MMBtu/bbl.                    62.64
Isobutane....................  4.074 MMBtu/bbl.                    64.91
Pentanes plus................  4.620 MMBtu/bbl.                    70.02
------------------------------------------------------------------------

     Table NN-2 of Subpart NN--Lookup Default Values for Calculation
                      Methodology 2 of This Subpart
------------------------------------------------------------------------
                                                   Default CO2 emission
             Fuel                    Unit          value (MT CO2/unit)
------------------------------------------------------------------------
Natural Gas..................  Mscf............                    0.055
Propane......................  Barrel..........                    0.235
Normal butane................  Barrel..........                    0.276
Ethane.......................  Barrel..........                    0.253
Isobutane....................  Barrel..........                    0.266
Pentanes plus................  Barrel..........                    0.324
------------------------------------------------------------------------

[FR Doc. 2010-13361 Filed 6-14-10; 8:45 am]
BILLING CODE 6560-50-P


[Federal Register Volume 82, Number 188 (Friday, September 29, 2017)]
[Proposed Rules]
[Page 45550]
[FR Doc No: 2017-20825]

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ENVIRONMENTAL PROTECTION AGENCY

40 CFR Part 52

[EPA-R07-OAR-2017-0517; FRL-9968-65-Region 7]

Approval of Iowa Air Quality Implementation Plans; Elements of
the Infrastructure SIP Requirements for the 2012 Annual Fine
Particulate Matter (PM2.5) National Ambient Air Quality Standard
(NAAQS)

AGENCY: Environmental Protection Agency (EPA).

ACTION: Proposed rule.

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

SUMMARY: The Environmental Protection Agency (EPA) is proposing to
approve elements of a State Implementation Plan (SIP) submission from
the State of Iowa for the 2012 Annual Fine Particulate Matter
(PM2.5) National Ambient Air Quality Standard (NAAQS).
Infrastructure SIPs address the applicable requirements of Clean Air
Act (CAA) section 110, which requires that each state adopt and submit
a SIP for the implementation, maintenance, and enforcement of each new
or revised NAAQS promulgated by the EPA. These SIPs are commonly
referred to as ``infrastructure'' SIPs. The infrastructure requirements
are designed to ensure that the structural components of each state's
air quality management program are adequate to meet the state's
responsibilities under the CAA.
    In the ``Rules and Regulations'' section of this issue of the
Federal Register, we are approving the state's SIP revisions as a
direct final rule without a prior proposed rule. If we receive no
adverse comment, we will not take further action on this proposed rule.

DATES: Comments must be received on or before October 30, 2017.

ADDRESSES: Submit your comments, identified by Docket ID No. EPA-R07-
OAR-2017-0517, to https://www.regulations.gov. Follow the online
instructions for submitting comments. Once submitted, comments cannot
be edited or removed from Regulations.gov. EPA may publish any comment
received to its public docket. Do not submit electronically any
information you consider to be Confidential Business Information (CBI)
or other information whose disclosure is restricted by statute.
Multimedia submissions (audio, video, etc.) must be accompanied by a
written comment. The written comment is considered the official comment
and should include discussion of all points you wish to make. The EPA
will generally not consider comments or comment contents located
outside of the primary submission (i.e., on the Web, cloud, or other
file sharing system). For additional submission methods, the full EPA
public comment policy, information about CBI or multimedia submissions,
and general guidance on making effective comments, please visit https://www2.epa.gov/dockets/commenting-epa-dockets.

FOR FURTHER INFORMATION CONTACT: Heather Hamilton, Air Planning and
Development Branch, U.S. Environmental Protection Agency, Region 7,
11201 Renner Boulevard, Lenexa, KS 66219 at<PHONE_NUMBER>, or by email
at<EMAIL_ADDRESS>
SUPPLEMENTARY INFORMATION: This document proposes to take direct final
action on Iowa's infrastructure SIP submissions for the 2010
NO2 NAAQS. We have published a direct final rule approving
the State's SIP revisions in the ``Rules and Regulations'' section of
this issue of the Federal Register, because we view this as a
noncontroversial action and anticipate no relevant adverse comment. We
have explained our reasons for this action in the preamble to the
direct final rule. A detailed technical support document (TSD) is
included in this rulemaking docket to address the following: A
description of Clean Air Act section 110(a)(1) and (2) infrastructure
SIPs; the applicable elements under sections 110(a)(1) and (2); EPA's
approach to the review of infrastructure SIP submissions, and EPA's
evaluation of how Iowa addressed the relevant elements of sections
110(a)(1) and (2). If we receive no adverse comment, we will not take
further action on this proposed rule. If we receive adverse comment, we
will withdraw the direct final rule and it will not take effect. We
would address all public comments in any subsequent final rule based on
this proposed rule. We do not intend to institute a second comment
period on this action. Any parties interested in commenting must do so
at this time. For further information, please see the information
provided in the ADDRESSES section of this document.

List of Subjects in 40 CFR Part 52

    Environmental protection, Air pollution control, Incorporation by
reference, Intergovernmental relations, Particulate Matter, and
Reporting and recordkeeping requirements.

    Dated: September 20, 2017.
Cathy Stepp,
Acting Regional Administrator, Region 7.
[FR Doc. 2017-20825 Filed 9-28-17; 8:45 am]
BILLING CODE 6560-50-P


[Federal Register Volume 82, Number 169 (Friday, September 1, 2017)]
[Notices]
[Page 41621]
[FR Doc No: 2017-18604]

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

ENVIRONMENTAL PROTECTION AGENCY

[ER-FRL-9034-9]

Environmental Impact Statements; Notice of Availability

    Responsible Agency: Office of Federal Activities, General
Information<PHONE_NUMBER> or http://www.epa.gov/nepa.

Weekly receipt of Environmental Impact Statements (EISs)
Filed 08/21/2017 Through 08/25/2017
Pursuant to 40 CFR 1506.9.

Notice

    Section 309(a) of the Clean Air Act requires that EPA make public
its comments on EISs issued by other Federal agencies. EPA's comment
letters on EISs are available at: http://www.epa.gov/compliance/nepa/eisdata.html.

EIS No. 20170165, Final, USFS, CA, Power Fire Reforestation, Review
Period Ends: 10/02/2017, Contact: Marc Young<PHONE_NUMBER>
EIS No. 20170166, Draft, BLM, NV, Greater Phoenix Project, Comment
Period Ends: 10/16/2017, Contact: Christine Gabriel<PHONE_NUMBER>
EIS No. 20170167, Final, DOC, CO, Nationwide Public Safety Broadband
Network for the Central United States, Review Period Ends: 10/02/2017,
Contact: Amanda Pereira<PHONE_NUMBER>
EIS No. 20170168, Draft, Caltrans, CA, North County Corridor New State
Route 108 Project and Route Adoption, Comment Period Ends: 10/16/2017,
Contact: Juan Torres<PHONE_NUMBER>
EIS No. 20170169, Draft, USACE, AK, Nanushuk Project, Comment Period
Ends: 10/16/2017, Contact: Ellen Lyons<PHONE_NUMBER>
EIS No. 20170170, Draft, USACE, TX, Houston Ship Channel Expansion
Channel Improvement Project, Comment Period Ends: 10/16/2017, Contact:
Kelly Burks-Copes<PHONE_NUMBER>
EIS No. 20170171, Draft, FTA, CA, East San Fernando Valley Transit
Corridor, Comment Period Ends: 10/16/2017, Contact: Candice Hughes 213-
629-8613

    Dated: August 28, 2017.
Dawn Roberts,
Management Analyst, NEPA Compliance Division, Office of Federal
Activities.
[FR Doc. 2017-18604 Filed 8-31-17; 8:45 am]
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