uncontrolled asphalt blowing from facility-specific test data
(metric tons CO2/MMbbl asphalt blown); default = 1,100.
CEFAB = Carbon emission factor from asphalt blowing from
facility-specific test data (metric tons C/MMbbl asphalt blown);
default = 2,750.
44 = Molecular weight of CO2 (kg/kg-mole).
12 = Atomic weight of C (kg/kg-mole).
[GRAPHIC] [TIFF OMITTED] TR17DE10.011

Where:

CH4 = Annual methane emissions from controlled asphalt
blowing (metric tons CH4/year).
0.02 = Fraction of methane uncombusted in thermal oxidizer or flare
based on assumed 98% combustion efficiency.
QAB = Quantity of asphalt blown (million barrels per
year, MMbbl/year).
EFAB,CH4 = Emission factor for CH4 from
uncontrolled asphalt blowing from facility-specific test data
(metric tons CH4/MMbbl asphalt blown); default = 580.

    (i) * * *
    (1) Use the process vent method in paragraph (j) of this section to
calculate the CH4 emissions from the depressurization of the
coke drum or vessel regardless of the CH4 concentration and
also calculate the CH4 emissions from the subsequent opening
of the vessel for coke cutting operations using Equation Y-18 of this
section. If you have coke drums or vessels of different dimensions, use
the process vent method in paragraph (j) of this section and Equation
Y-18 for each set of coke drums or vessels of the same size and sum the
resultant emissions across each set of coke drums or vessels to
calculate the CH4 emissions for all delayed coking units.
* * * * *
MVC = Molar volume conversion factor (849.5 scf/kg-mole at 68 [deg]F
and 14.7 psia or 836.6 scf/kg-mole at 60 [deg]F and 14.7 psia).
* * * * *
    (j) For each process vent not covered in paragraphs (a) through (i)
of this section that can reasonably be expected to contain greater than
2 percent by volume CO2 or greater than 0.5 percent by
volume of CH4 or greater than 0.01 percent by volume (100
parts per million) of N2O, calculate GHG emissions using the
Equation Y-19 of this section. You must use Equation Y-19 of this
section to calculate CH4 emissions for catalytic reforming
unit depressurization and purge vents when methane is used as the purge
gas or if you elected this method as an alternative to the methods in
paragraphs (f), (h), or (k) of this section.
* * * * *
(VR)p = Average volumetric flow rate of process gas
during the event (scf per hour) from measurement data, process
knowledge, or engineering estimates.
(MFx)p = Mole fraction of GHG x in process
vent during the event (kg-mol of GHG x/kg-mol vent gas) from
measurement data, process knowledge, or engineering estimates.
* * * * *
MVC = Molar volume conversion factor (849.5 scf/kg-mole at 68 [deg]F
and 14.7 psia or 836.6 scf/kg-mole at 60 [deg]F and 14.7 psia).
* * * * *
    (k) For uncontrolled blowdown systems, you must calculate CH4
emissions either using the methods for process vents in paragraph (j)
of this section regardless of the CH4 concentration or using
Equation Y20 of this section. * * *
* * * * *
MVC = Molar volume conversion factor (849.5 scf/kg-mole at 68 [deg]F
and 14.7 psia or 836.6 scf/kg-mole at 60 [deg]F and 14.7 psia).
* * * * *
    (m) For storage tanks, except as provided in paragraph (m)(4) of
this section, calculate CH4 emissions using the applicable
methods in paragraphs (m)(1) through (m)(3) of this section.
    (1) For storage tanks other than those processing unstabilized
crude oil, you must either calculate CH4 emissions from
storage tanks that have a vapor-phase methane concentration of 0.5
volume percent or more using tank-specific methane composition data
(from measurement data or product knowledge) and the emission
estimation methods provided in AP 42, Section 7.1 (incorporated by
reference, see Sec.  98.7) or estimate CH4 emissions from
storage tanks using Equation Y-22 of this section.
* * * * *
    (2) * * *
MFCH4 = Average mole fraction of CH4 in vent
gas from the unstabilized crude oil storage tanks from facility
measurements (kg-mole CH4/kg-mole gas); use 0.27 as a
default if measurement data are not available.
* * * * *
MVC = Molar volume conversion factor (849.5 scf/kg-mole at 68 [deg]F
and 14.7 psia or 836.6 scf/kg-mole at 60 [deg]F and 14.7 psia).
* * * * *
    (n) For crude oil, intermediate, or product loading operations for
which the vapor-phase concentration of methane is 0.5 volume percent or
more, calculate CH4 emissions from loading operations using
vapor-phase methane composition data (from measurement data or process
knowledge) and the emission estimation procedures provided in AP 42,
Section 5.2 (incorporated by reference, see Sec.  98.7). For loading
operations in which the vapor-phase concentration of methane is less
than 0.5 volume percent, you may assume zero methane emissions.

0
42. Section 98.254 is amended by:
0
a. Revising paragraph (a).
0
b. Revising paragraph (b).
0
c. Revising paragraph (c).
0
d. Revising paragraph (d) introductory text.
0
e. Adding paragraph (d)(6).
0
f. Revising paragraph (e) introductory text.
0
g. Revising paragraph (f) introductory text and (f)(1).
0
h. Removing and reserving paragraph (f)(2).
0
i. Removing paragraph (f)(4).
0
j. Revising paragraph (g).
0
k. Revising the second sentence of paragraph (h).
0
l. Removing paragraph (l).

Sec.  98.254  Monitoring and QA/QC requirements.

    (a) Fuel flow meters, gas composition monitors, and heating value
monitors that are associated with sources that use a CEMS to measure
CO2 emissions

according to subpart C of this part or that are associated with
stationary combustion sources must meet the applicable monitoring and
QA/QC requirements in Sec.  98.34.
    (b) All gas flow meters, gas composition monitors, and heating
value monitors that are used to provide data for the GHG emissions
calculations in this subpart for sources other than those subject to
the requirements in paragraph (a) of this section shall be calibrated
according to the procedures specified by the manufacturer, or according
to the procedures in the applicable methods specified in paragraphs (c)
through (g) of this section. In the case of gas flow meters, all gas
flow meters must meet the calibration accuracy requirements in Sec.
98.3(i). All gas flow meters, gas composition monitors, and heating
value monitors must be recalibrated at the applicable frequency
specified in paragraph (b)(1) or (b)(2) of this section.
    (1) You must recalibrate each gas flow meter according to one of
the following frequencies. You may recalibrate at the minimum frequency
specified by the manufacturer, biennially (every two years), or at the
interval specified by the industry consensus standard practice used.
    (2) You must recalibrate each gas composition monitor and heating
value monitor according to one of the following frequencies. You may
recalibrate at the minimum frequency specified by the manufacturer,
annually, or at the interval specified by the industry standard
practice used.
    (c) For flare or sour gas flow meters and gas flow meters used to
comply with the requirements in Sec.  98.253(j), operate, calibrate,
and maintain the flow meter according to one of the following. You may
use the procedures specified by the flow meter manufacturer, or a
method published by a consensus-based standards organization.
Consensus-based standards organizations include, but are not limited
to, the following: ASTM International (100 Barr Harbor Drive, P.O. Box
CB700, West Conshohocken, Pennsylvania 19428-B2959,<PHONE_NUMBER>,
http://www.astm.org), the American National Standards Institute (ANSI,
1819 L Street, NW., 6th floor, Washington, DC 20036,<PHONE_NUMBER>,
http://www.ansi.org), the American Gas Association (AGA, 400 North
Capitol Street, NW., 4th Floor, Washington, DC 20001,<PHONE_NUMBER>,
http://www.aga.org), the American Society of Mechanical Engineers
(ASME, Three Park Avenue, New York, NY 10016-5990,<PHONE_NUMBER>,
http://www.asme.org), the American Petroleum Institute (API, 1220 L
Street, NW., Washington, DC 20005-4070,<PHONE_NUMBER>, http://www.api.org), and the North American Energy Standards Board (NAESB, 801
Travis Street, Suite 1675, Houston, TX 77002,<PHONE_NUMBER>, http://www.api.org).
    (d) Except as provided in paragraph (g) of this section, determine
gas composition and, if required, average molecular weight of the gas
using any of the following methods. Alternatively, the results of
chromatographic analysis of the fuel may be used, provided that the gas
chromatograph is operated, maintained, and calibrated according to the
manufacturer's instructions; and the methods used for operation,
maintenance, and calibration of the gas chromatograph are documented in
the written Monitoring Plan for the unit under Sec.  98.3(g)(5).
* * * * *
    (6) ASTM D2503-92 (Reapproved 2007) Standard Test Method for
Relative Molecular Mass (Molecular Weight) of Hydrocarbons by
Thermoelectric Measurement of Vapor Pressure (incorporated by
reference, see Sec.  98.7).
    (e) Determine flare gas higher heating value using any of the
following methods. Alternatively, the results of chromatographic
analysis of the fuel may be used, provided that the gas chromatograph
is operated, maintained, and calibrated according to the manufacturer's
instructions; and the methods used for operation, maintenance, and
calibration of the gas chromatograph are documented in the written
Monitoring Plan for the unit under Sec.  98.3(g)(5).
* * * * *
    (f) For gas flow meters used to comply with the requirements in
Sec.  98.253(c)(2)(ii), install, operate, calibrate, and maintain each
gas flow meter according to the requirements in 40 CFR 63.1572(c) and
the following requirements.
    (1) Locate the flow monitor at a site that provides representative
flow rates. Avoid locations where there is swirling flow or abnormal
velocity distributions due to upstream and downstream disturbances.
* * * * *
    (g) For exhaust gas CO2/CO/O2 composition
monitors used to comply with the requirements in Sec.  98.253(c)(2),
install, operate, calibrate, and maintain exhaust gas composition
monitors according to the requirements in 40 CFR 60.105a(b)(2) or 40
CFR 63.1572(c) or according to the manufacturer's specifications and
requirements.
    (h) * * * Calibrate the measurement device according to the
procedures specified by NIST handbook 44 (incorporated by reference,
see Sec.  98.7) or the procedures specified by the manufacturer. * * *
* * * * *

0
43. Section 98.256 is amended by:
0
a. Revising paragraph (e)(6).
0
b. Redesignating paragraphs (e)(7) through (e)(9) as (e)(8) through
(e)(10), respectively.
0
c. Adding paragraph (e)(7).
0
d. Revising newly designated paragraphs (e)(8) and (e)(9).
0
e. Revising paragraphs (f)(6) through (f)(8).
0
f. Redesignating paragraphs (f)(9) through (f)(12) as (f)(10) through
(f)(13), respectively.
0
g. Adding paragraph (f)(9).
0
h. Revising newly designated paragraphs (f)(11) through (f)(13).
0
i. Revising paragraphs (g)(5), (h)(2), and (h)(4), and the first
sentence of paragraph (h)(6).
0
j. Adding paragraph (h)(7).
0
k. Revising paragraphs (i)(5), (i)(6), (i)(8), and (j)(2).
0
l. Redesignating paragraph (j)(8) as (j)(9).
0
m. Adding paragraph (j)(8).
0
n. Revising paragraphs (k)(1), (k)(3), (l) introductory text, (l)(5),
and (m).
0
o. Revising paragraphs (o)(1) through (o)(4).

Sec.  98.256  Data reporting requirements.

* * * * *
    (e) * * *
    (6) If you use Equation Y-1a of this subpart, an indication of
whether daily or weekly measurement periods are used, the annual volume
of flare gas combusted (in scf/year) and the annual average molecular
weight (in kg/kg-mole), the molar volume conversion factor (in scf/kg-
mole), and annual average carbon content of the flare gas (in kg carbon
per kg flare gas).
    (7) If you use Equation Y-1b of this subpart, an indication of
whether daily or weekly measurement periods are used, the annual volume
of flare gas combusted (in scf/year), the molar volume conversion
factor (in scf/kg-mole), the annual average CO2
concentration (volume or mole percent), the number of carbon containing
compounds other than CO2 in the flare gas stream, and for
each of the carbon containing compounds other than CO2 in
the flare gas stream:
    (i) The annual average concentration of the compound (volume or
mole percent).
    (ii) The carbon mole number of the compound (moles carbon per mole
compound).
    (8) If you use Equation Y-2 of this subpart, an indication of
whether daily

or weekly measurement periods are used, the annual volume of flare gas
combusted (in million (MM) scf/year), the annual average higher heating
value of the flare gas (in mmBtu/mmscf), and an indication of whether
the annual volume of flare gas combusted and the annual average higher
heating value of the flare gas were determined using standard
conditions of 68 [deg]F and 14.7 psia or 60 [deg]F and 14.7 psia.
    (9) If you use Equation Y-3 of this subpart, the annual volume of
flare gas combusted (in MMscf/year) during normal operations, the
annual average higher heating value of the flare gas (in mmBtu/mmscf),
the number of SSM events exceeding 500,000 scf/day, the volume of gas
flared (in scf/event), the average molecular weight (in kg/kg-mole),
the molar volume conversion factor (in scf/kg-mole), and carbon content
of the flare gas (in kg carbon per kg flare) for each SSM event over
500,000 scf/day.
* * * * *
    (f) * * *
    (6) If you use a CEMS, the relevant information required under
Sec.  98.36 for the Tier 4 Calculation Methodology, the CO2
annual emissions as measured by the CEMS (unadjusted to remove
CO2 combustion emissions associated with additional units,
if present) and the process CO2 emissions as calculated
according to Sec.  98.253(c)(1)(ii). Report the CO2 annual
emissions associated with sources other than those from the coke burn-
off in the applicable subpart (e.g., subpart C of this part in the case
of a CO boiler).
    (7) If you use Equation Y-6 of this subpart, the annual average
exhaust gas flow rate, %CO2, %CO, and the molar volume
conversion factor (in scf/kg-mole).
    (8) If you use Equation Y-7a of this subpart, the annual average
flow rate of inlet air and oxygen-enriched air, %O2,
%Ooxy, %CO2, and %CO.
    (9) If you use Equation Y-7b of this subpart, the annual average
flow rate of inlet air and oxygen-enriched air, %N2,oxy, and
%N2,exhaust.
* * * * *
    (11) Indicate whether you use a measured value, a unit-specific
emission factor, or a default emission factor for CH4
emissions. If you use a unit-specific emission factor for
CH4, report the unit-specific emission factor for
CH4, the units of measure for the unit-specific factor, the
activity data for calculating emissions (e.g., if the emission factor
is based on coke burn-off rate, the annual quantity of coke burned),
and the basis for the factor.
    (12) Indicate whether you use a measured value, a unit-specific
emission factor, or a default emission factor for N2O
emissions. If you use a unit-specific emission factor for
N2O, report the unit-specific emission factor for
N2O, the units of measure for the unit-specific factor, the
activity data for calculating emissions (e.g., if the emission factor
is based on coke burn-off rate, the annual quantity of coke burned),
and the basis for the factor.
    (13) If you use Equation Y-11 of this subpart, the number of
regeneration cycles or measurement periods during the reporting year,
the average coke burn-off quantity per cycle or measurement period, and
the average carbon content of the coke.
    (g) * * *
    (5) If the GHG emissions for the low heat value gas are calculated
at the flexicoking unit, also report the calculated annual
CO2, CH4, and N2O emissions for each
unit, expressed in metric tons of each pollutant emitted, and the
applicable equation input parameters specified in paragraphs (f)(7)
through (f)(13) of this section.
    (h) * * *
    (2) Maximum rated throughput of each independent sulfur recovery
plant, in metric tons sulfur produced/stream day, a description of the
type of sulfur recovery plant, and an indication of the method used to
calculate CO2 annual emissions for the sulfur recovery plant
(e.g., CO2 CEMS, Equation Y-12, or process vent method in
Sec.  98.253(j)).
* * * * *
    (4) If you use Equation Y-12 of this subpart, the annual volumetric
flow to the sulfur recovery plant (in scf/year), the molar volume
conversion factor (in scf/kg-mole), and the annual average mole
fraction of carbon in the sour gas (in kg-mole C/kg-mole gas).
* * * * *
    (6) If you use a CEMS, the relevant information required under
Sec.  98.36 for the Tier 4 Calculation Methodology, the CO2
annual emissions as measured by the CEMS and the annual process
CO2 emissions calculated according to Sec.  98.253(f)(1). *
* *
    (7) If you use the process vent method in Sec.  98.253(j) for a
non-Claus sulfur recovery plant, the relevant information required
under paragraph (l)(5) of this section.
    (i) * * *
    (5) If you use Equation Y-13 of this subpart, annual mass and
carbon content of green coke fed to the unit, the annual mass and
carbon content of marketable coke produced, the annual mass of coke
dust removed from the process through dust collection systems, and an
indication of whether coke dust is recycled to the unit (e.g., all dust
is recycled, a portion of the dust is recycled, or none of the dust is
recycled).
    (6) If you use a CEMS, the relevant information required under
Sec.  98.36 for the Tier 4 Calculation Methodology, the CO2
annual emissions as measured by the CEMS and the annual process
CO2 emissions calculated according to Sec.  98.253(g)(1). *
* *
* * * * *
    (8) Indicate whether you use a measured value, a unit-specific
emission factor, or a default emission factor for N2O
emissions. If you use a unit-specific emission factor for
N2O, report the unit-specific emission factor for
N2O, the units of measure for the unit-specific factor, the
activity data for calculating emissions (e.g., if the emission factor
is based on coke burn-off rate, the annual quantity of coke burned),
and the basis for the factor.
    (j) * * *
    (2) The quantity of asphalt blown (in million bbl) at the unit in
the reporting year.
* * * * *
    (8) If you use Equation Y-16b of this subpart, the CO2
emission factor used and the basis for its value and the carbon
emission factor used and the basis for its value.
* * * * *
    (k) * * *
    (1) The cumulative annual CH4 emissions (in metric tons
of CH4) for all delayed coking units at the facility.
* * * * *
    (3) The total number of delayed coking units at the facility, the
total number of delayed coking drums at the facility, and for each coke
drum or vessel: The dimensions, the typical gauge pressure of the
coking drum when first vented to the atmosphere, typical void fraction,
the typical drum outage (i.e. the unfilled distance from the top of the
drum, in feet), the molar volume conversion factor (in scf/kg-mole),
and annual number of coke-cutting cycles.
* * * * *
    (l) For each process vent subject to Sec.  98.253(j), the owner or
operator shall report:
* * * * *
    (5) The annual volumetric flow discharged to the atmosphere (in
scf), and an indication of the measurement or estimation method, annual
average mole fraction of each GHG above the concentration threshold or
otherwise required to be reported and an indication of the measurement
or estimation method, the molar volume conversion factor (in scf/kg-
mole), and for intermittent vents, the number of

venting events and the cumulative venting time.
    (m) For uncontrolled blowdown systems, the owner or operator shall
report:
    (1) An indication of whether the uncontrolled blowdown emission are
reported under Sec.  98.253(k) or Sec.  98.253(j) or a statement that
the facility does not have any uncontrolled blowdown systems.
    (2) The cumulative annual CH4 emissions (in metric tons
of CH4) for uncontrolled blowdown systems.
    (3) For uncontrolled blowdown systems reporting under Sec.
98.253(k), the total quantity (in million bbl) of crude oil plus the
quantity of intermediate products received from off site that are
processed at the facility in the reporting year, the methane emission
factor used for uncontrolled blowdown systems, the basis for the value,
and the molar volume conversion factor (in scf/kg-mole).
    (4) For uncontrolled blowdown systems reporting under Sec.
98.253(j), the relevant information required under paragraph (l)(5) of
this section.
* * * * *
    (o) * * *
    (1) The cumulative annual CH4 emissions (in metric tons
of CH4) for all storage tanks, except for those used to
process unstabilized crude oil.
    (2) For storage tanks other than those processing unstabilized
crude oil:
    (i) The method used to calculate the reported storage tank
emissions for storage tanks other than those processing unstabilized
crude (i.e., either AP 42, Section 7.1 (incorporated by reference, see
Sec.  98.7), or Equation Y-22 of this section).
    (ii) The total quantity (in MMbbl) of crude oil plus the quantity
of intermediate products received from off site that are processed at
the facility in the reporting year.
    (3) The cumulative CH4 emissions (in metric tons of
CH4) for storage tanks used to process unstabilized crude
oil or a statement that the facility did not receive any unstabilized
crude oil during the reporting year.
    (4) For storage tanks that process unstabilized crude oil:
    (i) The method used to calculate the reported unstabilized crude
oil storage tank emissions.
    (ii) The quantity of unstabilized crude oil received during the
calendar year (in MMbbl).
    (iii) The average pressure differential (in psi).
    (iv) The molar volume conversion factor (in scf/kg-mole).
    (v) The average mole fraction of CH4 in vent gas from
unstabilized crude oil storage tanks and the basis for the mole
fraction.
    (vi) If you did not use Equation Y-23, the tank-specific methane
composition data and the gas generation rate data used to estimate the
cumulative CH4 emissions for storage tanks used to process
unstabilized crude oil.
* * * * *

0
44. Section 98.257 is revised to read as follows:

Sec.  98.257  Records that must be retained.

    In addition to the records required by Sec.  98.3(g), you must
retain the records of all parameters monitored under Sec.  98.255. If
you comply with the combustion methodology in Sec.  98.252(a), then you
must retain under this subpart the records required for the Tier 3 and/
or Tier 4 Calculation Methodologies in Sec.  98.37 and you must keep
records of the annual average flow calculations.

Subpart AA--[Amended]

0
45. Section 98.273 is amended by:
0
a. Revising paragraphs (a)(1) and (a)(2).
0
b. Revising the definition of ``EF'' in Equation AA-1 of paragraph
(a)(3).
0
c. Revising paragraphs (b)(1) and (b)(2).
0
d. Revising paragraphs (c)(1) and (c)(2).

Sec.  98.273  Calculating GHG emissions.

    (a) * * *
    (1) Calculate fossil fuel-based CO2 emissions from
direct measurement of fossil fuels consumed and default emissions
factors according to the Tier 1 methodology for stationary combustion
sources in Sec.  98.33(a)(1). A higher tier from Sec.  98.33(a) may be
used to calculate fossil fuel-based CO2 emissions if the
respective monitoring and QA/QC requirements described in Sec.  98.34
are met.
    (2) Calculate fossil fuel-based CH4 and N2O
emissions from direct measurement of fossil fuels consumed, default or
site-specific HHV, and default emissions factors and convert to metric
tons of CO2 equivalent according to the methodology for
stationary combustion sources in Sec.  98.33(c).
    (3) * * *

(EF) = Default or site-specific emission factor for CO2,
CH4, or N2O, from Table AA-1 of this subpart
(kg CO2, CH4, or N2O per mmBtu).
* * * * *
    (b) * * *
    (1) Calculate fossil CO2 emissions from fossil fuels
from direct measurement of fossil fuels consumed and default emissions
factors according to the Tier 1 Calculation Methodology for stationary
combustion sources in Sec.  98.33(a)(1). A higher tier from Sec.
98.33(a) may be used to calculate fossil fuel-based CO2
emissions if the respective monitoring and QA/QC requirements described
in Sec.  98.34 are met.
    (2) Calculate CH4 and N2O emissions from
fossil fuels from direct measurement of fossil fuels consumed, default
or site-specific HHV, and default emissions factors and convert to
metric tons of CO2 equivalent according to the methodology
for stationary combustion sources in Sec.  98.33(c).
* * * * *
    (c) * * *
    (1) Calculate CO2 emissions from fossil fuel from direct
measurement of fossil fuels consumed and default HHV and default
emissions factors, according to the Tier 1 Calculation Methodology for
stationary combustion sources in Sec.  98.33(a)(1). A higher tier from
Sec.  98.33(a) may be used to calculate fossil fuel-based
CO2 emissions if the respective monitoring and QA/QC
requirements described in Sec.  98.34 are met.
    (2) Calculate CH4 and N2O emissions from
fossil fuel from direct measurement of fossil fuels consumed, default
or site-specific HHV, and default emissions factors and convert to
metric tons of CO2 equivalent according to the methodology
for stationary combustion sources in Sec.  98.33(c); use the default
HHV listed in Table C-1 of subpart C and the default CH4 and
N2O emissions factors listed in Table AA-2 of this subpart.
* * * * *

0
46. Section 98.276 is amended by revising the introductory text and
revising paragraph (e) to read as follows:

Sec.  98.276  Data reporting requirements.

    In addition to the information required by Sec.  98.3(c) and the
applicable information required by Sec.  98.36, each annual report must
contain the information in paragraphs (a) through (k) of this section
as applicable:
* * * * *
    (e) The default or site-specific emission factor for
CO2, CH4, or N2O, used in Equation AA-
1 of this subpart (kg CO2, CH4, or N2O
per mmBtu).
* * * * *

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

  Table AA-2 to Subpart AA--Kraft Lime Kiln and Calciner Emissions Factors for Fossil Fuel-Based CH[ihel4] and
                                                    N[ihel2]O
----------------------------------------------------------------------------------------------------------------
                                                    Fossil fuel-based emissions factors (kg/mmBtu HHV)
                                         -----------------------------------------------------------------------
                  Fuel                             Kraft lime kilns                     Kraft calciners
                                         -----------------------------------------------------------------------
                                              CH[ihel4]         N[ihel2]O         CH[ihel4]         N[ihel2]O
----------------------------------------------------------------------------------------------------------------
Residual Oil............................  ................  ................  ................            0.0003
Distillate Oil..........................  ................  ................            0.0027            0.0004
Natural Gas.............................            0.0027                    ................            0.0001
Biogas..................................  ................  ................  ................            0.0001
Petroleum coke..........................  ................  ................                NA            \a\ NA
----------------------------------------------------------------------------------------------------------------
\a\ Emission factors for kraft calciners are not available.

Subpart OO--[Amended]

0
48. Section 98.410 is amended by revising paragraph (b) to read as
follows:

Sec.  98.410  Definition of the source category.

* * * * *
    (b) To produce a fluorinated GHG means to manufacture a fluorinated
GHG from any raw material or feedstock chemical. Producing a
fluorinated GHG includes the manufacture of a fluorinated GHG as an
isolated intermediate for use in a process that will result in its
transformation either at or outside of the production facility.
Producing a fluorinated GHG also includes the creation of a fluorinated
GHG (with the exception of HFC-23) that is captured and shipped off
site for any reason, including destruction. Producing a fluorinated GHG
does not include the reuse or recycling of a fluorinated GHG, the
creation of HFC-23 during the production of HCFC-22, the creation of
intermediates that are created and transformed in a single process with
no storage of the intermediates, or the creation of fluorinated GHGs
that are released or destroyed at the production facility before the
production measurement at Sec.  98.414(a).
* * * * *

0
49. Section 98.414 is amended by:
0
a. Adding second and third sentences to paragraph (a).
0
b. Revising paragraph (h).
0
c. Removing and reserving paragraph (j).
0
d. Adding new paragraphs (n) through (q).

Sec.  98.414  Monitoring and QA/QC requirements.

    (a) * * * If the measured mass includes more than one fluorinated
GHG, the concentrations of each of the fluorinated GHGs, other than
low-concentration constituents, shall be measured as set forth in
paragraph (n) of this section. For each fluorinated GHG, the mean of
the concentrations of that fluorinated GHG (mass fraction) measured
under paragraph (n) of this section shall be multiplied by the mass
measurement to obtain the mass of that fluorinated GHG coming out of
the production process.
* * * * *
    (h) You must measure the mass of each fluorinated GHG that is fed
into the destruction device and that was previously produced as defined
at Sec.  98.410(b). Such fluorinated GHGs include but are not limited
to quantities that are shipped to the facility by another facility for
destruction and quantities that are returned to the facility for
reclamation but are found to be irretrievably contaminated and are
therefore destroyed. You must use flowmeters, weigh scales, or a
combination of volumetric and density measurements with an accuracy and
precision of one percent of full scale or better. If the measured mass
includes more than trace concentrations of materials other than the
fluorinated GHG being destroyed, you must estimate the concentrations
of the fluorinated GHG being destroyed considering current or previous
representative concentration measurements and other relevant process
information. You must multiply this concentration (mass fraction) by
the mass measurement to obtain the mass of the fluorinated GHG fed into
the destruction device.
* * * * *
    (n) If the mass coming out of the production process includes more
than one fluorinated GHG, you shall measure the concentrations of all
of the fluorinated GHGs, other than low-concentration constituents, as
follows:
    (1) Analytical Methods. Use a quality-assured analytical
measurement technology capable of detecting the analyte of interest at
the concentration of interest and use a procedure validated with the
analyte of interest at the concentration of interest. Where standards
for the analyte are not available, a chemically similar surrogate may
be used. Acceptable analytical measurement technologies include but are
not limited to gas chromatography (GC) with an appropriate detector,
infrared (IR), fourier transform infrared (FTIR), and nuclear magnetic
resonance (NMR). Acceptable methods include EPA Method 18 in Appendix
A-1 of 40 CFR part 60; EPA Method 320 in Appendix A of 40 CFR part 63;
the Protocol for Measuring Destruction or Removal Efficiency (DRE) of
Fluorinated Greenhouse Gas Abatement Equipment in Electronics
Manufacturing, Version 1, EPA-430-R-10-003, (March 2010) (incorporated
by reference, see Sec.  98.7); ASTM D6348-03 Standard Test Method for
Determination of Gaseous Compounds by Extractive Direct Interface
Fourier Transform Infrared (FTIR) Spectroscopy (incorporated by
reference, see Sec.  98.7); or other analytical methods validated using
EPA Method 301 in Appendix A of 40 CFR part 63 or some other
scientifically sound validation protocol. The validation protocol may
include analytical technology manufacturer specifications or
recommendations.
    (2) Documentation in GHG Monitoring Plan. Describe the analytical
method(s) used under paragraph (n)(1) of this section in the site GHG
Monitoring Plan as required under Sec.  98.3(g)(5). At a minimum,
include in the description of the method a description of the
analytical measurement equipment and procedures, quantitative estimates
of the method's accuracy and precision for the analytes of interest at
the concentrations of interest, as well as a description of how these
accuracies and precisions were estimated, including the validation
protocol used.
    (3) Frequency of measurement. Perform the measurements at least
once by February 15, 2011 if the fluorinated GHG product is being
produced on December 17, 2010. Perform the measurements within 60 days
of commencing production of any fluorinated GHG product that was not

being produced on December 17, 2010. Repeat the measurements if an
operational or process change occurs that could change the identities
or significantly change the concentrations of the fluorinated GHG
constituents of the fluorinated GHG product. Complete the repeat
measurements within 60 days of the operational or process change.
    (4) Measure all product grades. Where a fluorinated GHG is produced
at more than one purity level (e.g., pharmaceutical grade and
refrigerant grade), perform the measurements for each purity level.
    (5) Number of samples. Analyze a minimum of three samples of the
fluorinated GHG product that have been drawn under conditions that are
representative of the process producing the fluorinated GHG product. If
the relative standard deviation of the measured concentrations of any
of the fluorinated GHG constituents (other than low-concentration
constituents) is greater than or equal to 15 percent, draw and analyze
enough additional samples to achieve a total of at least six samples of
the fluorinated GHG product.
    (o) All analytical equipment used to determine the concentration of
fluorinated GHGs, including but not limited to gas chromatographs and
associated detectors, IR, FTIR and NMR devices, shall be calibrated at
a frequency needed to support the type of analysis specified in the
site GHG Monitoring Plan as required under Sec.  98.414(n) and Sec.
98.3(g)(5) of this part. Quality assurance samples at the
concentrations of concern shall be used for the calibration. Such
quality assurance samples shall consist of or be prepared from
certified standards of the analytes of concern where available; if not
available, calibration shall be performed by a method specified in the
GHG Monitoring Plan.
    (p) Isolated intermediates that are produced and transformed at the
same facility are exempt from the monitoring requirements of this
section.
    (q) Low-concentration constituents are exempt from the monitoring
and QA/QC requirements of this section.

0
50. Section 98.416 is amended by:
0
a. Revising paragraph (a)(3).
0
b. Removing and reserving paragraph (a)(4).
0
c. Revising paragraphs (a)(11) and (a)(15).
0
d. Revising paragraphs (b) introductory text and (b)(1).
0
e. Revising paragraphs (c) introductory text, (c)(1), and (c)(10).
0
f. Revising paragraph (d) introductory text.
0
g. Revising paragraph (e) introductory text.
0
h. Adding paragraphs (f) through (h).

Sec.  98.416  Data reporting requirements.

* * * * *
    (a) * * *
    (3) Mass in metric tons of each fluorinated GHG that is destroyed
at that facility and that was previously produced as defined at Sec.
98.410(b). Quantities to be reported under this paragraph (a)(3) of
this section include but are not limited to quantities that are shipped
to the facility by another facility for destruction and quantities that
are returned to the facility for reclamation but are found to be
irretrievably contaminated and are therefore destroyed.
* * * * *
    (11) Mass in metric tons of each fluorinated GHG that is fed into
the destruction device and that was previously produced as defined at
Sec.  98.410(b). Quantities to be reported under this paragraph (a)(11)
of this section include but are not limited to quantities that are
shipped to the facility by another facility for destruction and
quantities that are returned to the facility for reclamation but are
found to be irretrievably contaminated and are therefore destroyed.
* * * * *
    (15) Names and addresses of facilities to which any fluorinated
GHGs were sent for destruction, and the quantities (metric tons) of
each fluorinated GHG that were sent to each for destruction.
* * * * *
    (b) By March 31, 2011 or within 60 days of commencing fluorinated
GHG destruction, whichever is later, a fluorinated GHG production
facility or importer that destroys fluorinated GHGs shall submit a one-
time report containing the following information for each destruction
process:
    (1) Destruction efficiency (DE).
* * * * *
    (c) Each bulk importer of fluorinated GHGs or nitrous oxide shall
submit an annual report that summarizes its imports at the corporate
level, except for shipments including less than twenty-five kilograms
of fluorinated GHGs or nitrous oxide, transshipments, and heels that
meet the conditions set forth at Sec.  98.417(e). The report shall
contain the following information for each import:
    (1) Total mass in metric tons of nitrous oxide and each fluorinated
GHG imported in bulk, including each fluorinated GHG constituent of the
fluorinated GHG product that makes up between 0.5 percent and 100
percent of the product by mass.
* * * * *
    (10) If applicable, the names and addresses of the persons and
facilities to which the fluorinated GHGs were sold or transferred for
destruction, and the quantities (metric tons) of each fluorinated GHG
that were sold or transferred to each facility for destruction.
    (d) Each bulk exporter of fluorinated GHGs or nitrous oxide shall
submit an annual report that summarizes its exports at the corporate
level, except for shipments including less than twenty-five kilograms
of fluorinated GHGs or nitrous oxide, transshipments, and heels. The
report shall contain the following information for each export:
* * * * *
    (e) By March 31, 2011, or within 60 days of commencing fluorinated
GHG production, whichever is later, a fluorinated GHG production
facility shall submit a one-time report describing the following
information:
* * * * *
    (f) By March 31, 2011, all fluorinated GHG production facilities
shall submit a one-time report that includes the concentration of each
fluorinated GHG constituent in each fluorinated GHG product as measured
under Sec.  98.414(n). If the facility commences production of a
fluorinated GHG product that was not included in the initial report or
performs a repeat measurement under Sec.  98.414(n) that shows that the
identities or concentrations of the fluorinated GHG constituents of a
fluorinated GHG product have changed, then the new or changed
concentrations, as well as the date of the change, must be reflected in
a revision to the report. The revised report must be submitted to EPA
by the March 31st that immediately follows the measurement under Sec.
98.414(n).
    (g) Isolated intermediates that are produced and transformed at the
same facility are exempt from the reporting requirements of this
section.
    (h) Low-concentration constituents are exempt from the reporting
requirements of this section.

0
51. Section 98.417 is amended by revising paragraphs (a)(2), (b), and
(d)(2); and by adding paragraphs (f) and (g) to read as follows:

Sec.  98.417  Records that must be retained.

    (a) * * *
    (2) Records documenting the initial and periodic calibration of the
analytical equipment (including but not limited to GC, IR, FTIR, or
NMR), weigh scales, flowmeters, and volumetric and density measures
used to measure the quantities reported under this subpart, including
the manufacturer directions or industry standards used for

calibration pursuant to Sec.  98.414(m) and (o).
    (b) In addition to the data required by paragraph (a) of this
section, any fluorinated GHG production facility that destroys
fluorinated GHGs shall keep records of test reports and other
information documenting the facility's one-time destruction efficiency
report in Sec.  98.416(b).
* * * * *
    (d) * * *
    (2) The invoice for the export.
* * * * *
    (f) Isolated intermediates that are produced and transformed at the
same facility are exempt from the recordkeeping requirements of this
section.
    (g) Low-concentration constituents are exempt from the
recordkeeping requirements of this section.

0
52. Section 98.418 is revised to read as follows:

Sec.  98.418  Definitions.

    Except as provided below, all of the terms used in this subpart
have the same meaning given in the Clean Air Act and subpart A of this
part. If a conflict exists between a definition provided in this
subpart and a definition provided in subpart A, the definition in this
subpart shall take precedence for the reporting requirements in this
subpart.
    Isolated intermediate means a product of a process that is stored
before subsequent processing. An isolated intermediate is usually a
product of chemical synthesis. Storage of an isolated intermediate
marks the end of a process. Storage occurs at any time the intermediate
is placed in equipment used solely for storage.
    Low-concentration constituent means, for purposes of fluorinated
GHG production and export, a fluorinated GHG constituent of a
fluorinated GHG product that occurs in the product in concentrations
below 0.1 percent by mass. For purposes of fluorinated GHG import, low-
concentration constituent means a fluorinated GHG constituent of a
fluorinated GHG product that occurs in the product in concentrations
below 0.5 percent by mass. Low-concentration constituents do not
include fluorinated GHGs that are deliberately combined with the
product (e.g., to affect the performance characteristics of the
product).

Subpart PP--[Amended]

0
53. Section 98.422 is amended by revising paragraphs (a) and (b) to
read as follows:

Sec.  98.422  GHGs to report.

    (a) Mass of CO2 captured from production process units.
    (b) Mass of CO2 extracted from CO2 production
wells.
* * * * *

0
54. Section 98.423 is amended by:
0
a. Revising the first sentence of paragraph (a) introductory text.
0
b. Revising the first sentences of paragraphs (a)(1) and (a)(2).
0
c. Revising the definitions of ``CCO2,p'' and
``Dp'' in Equation PP-2 in paragraph (a)(2).
0
d. Revising paragraph (a)(3).
0
e. Redesignating paragraph (b) as paragraph (c) and revising newly
designated paragraph (c).
0
f. Adding paragraph (b).

Sec.  98.423  Calculating CO2 Supply.

    (a) Except as allowed in paragraph (b) of this section, calculate
the annual mass of CO2 captured, extracted, imported, or
exported through each flow meter in accordance with the procedures
specified in either paragraph (a)(1) or (a)(2) of this section. * * *
    (1) For each mass flow meter, you shall calculate quarterly the
mass of CO2 in a CO2 stream in metric tons by
multiplying the mass flow by the composition data, according to
Equation PP-1 of this section. * * *
* * * * *
    (2) For each volumetric flow meter, you shall calculate quarterly
the mass of CO2 in a CO2 stream in metric tons by
multiplying the volumetric flow by the concentration and density data,
according to Equation PP-2 of this section. * * *
* * * * *
CCO2,p = Quarterly CO2 concentration
measurement in flow for flow meter u in quarter p (measured as
either volume % CO2 or weight % CO2).
* * * * *
Dp = Density of CO2 in quarter p (metric tons
CO2 per standard cubic meter) for flow meter u if
CCO2,p is measured as volume % CO2, or density
of the whole CO2 stream for flow meter u (metric tons per
standard cubic meter) if CCO2,p is measured as weight %
CO2.
* * * * *
    (3) To aggregate data, use either Equation PP-3a or PP-3b in this
paragraph, as appropriate.
    (i) For facilities with production process units that capture a
CO2 stream and either measure it after segregation or do not
segregate the flow, calculate the total CO2 supplied in
accordance with Equation PP-3a.
[GRAPHIC] [TIFF OMITTED] TR17DE10.012

Where:

CO2 = Total annual mass of CO2 (metric tons).
CO2,u = Annual mass of CO2 (metric tons)
through flow meter u.
u = Flow meter.

    (ii) For facilities with production process units that capture a
CO2 stream and measure it ahead of segregation, calculate
the total CO2 supplied in accordance with Equation PP-3b.
[GRAPHIC] [TIFF OMITTED] TR17DE10.013

Where:

CO2 = Total annual mass of CO2 (metric tons).
CO2,u = Annual mass of CO2 (metric tons)
through main flow meter u.
CO2,v = Annual mass of CO2 (metric tons)
through subsequent flow meter v for use on site.
u = Main flow meter.
v = Subsequent flow meter.

    (b) As an alternative to paragraphs (a)(1) through (3) of this
section for CO2 that is supplied in containers, calculate
the annual mass of CO2 supplied in containers delivered by
each CO2 stream

in accordance with the procedures specified in either paragraph (b)(1)
or (b)(2) of this section. If multiple CO2 streams are used
to deliver CO2 to containers, you shall calculate the annual
mass of CO2 supplied in containers delivered by all
CO2 streams according to the procedures specified in
paragraph (b)(3) of this section.
    (1) For each CO2 stream that delivers CO2 to
containers, for which mass is measured, you shall calculate
CO2 supply in containers using Equation PP-1 of this
section.

Where:

CO2,u = Annual mass of CO2 (metric tons)
supplied in containers delivered by CO2 stream u.
CCO2,p,u = Quarterly CO2 concentration
measurement of CO2 stream u that delivers CO2
to containers in quarter p (wt. %CO2).
Qp,u = Quarterly mass of contents supplied in all
containers delivered by CO2 stream u in quarter p (metric
tons).
p = Quarter of the year.
u = CO2 stream that delivers to containers.

    (2) For each CO2 stream that delivers to containers, for
which volume is measured, you shall calculate CO2 supply in
containers using Equation PP-2 of this section.

Where:

CO2,u = Annual mass of CO2 (metric tons)
supplied in containers delivered by CO2 stream u.
CCO2,p = Quarterly CO2 concentration
measurement of CO2 stream u that delivers CO2
to containers in quarter p (measured as either volume %
CO2 or weight % CO2).
Qp = Quarterly volume of contents supplied in all
containers delivered by CO2 stream u in quarter p
(standard cubic meters).
Dp = Quarterly CO2 density determination for
CO2 stream u in quarter p (metric tons per standard cubic
meter) if CO2,p is measured as volume %
CO2, or density of CO2 stream u (metric tons
per standard cubic meter) if CO2,p is measured as weight
% CO2.
p = Quarter of the year.
u = CO2 stream that delivers to containers.

    (3) To aggregate data, sum the mass of CO2 supplied in
containers delivered by all CO2 streams in accordance with
Equation PP-3a of this section.
Where:

CO2 = Annual mass of CO2 (metric tons)
supplied in containers delivered by all CO2 streams.
CO2,u = Annual mass of CO2 (metric tons)
supplied in containers delivered by CO2 stream u.
u = CO2 stream that delivers to containers.

    (c) Importers or exporters that import or export CO2 in
containers shall calculate the total mass of CO2 imported or
exported in metric tons based on summing the mass in each
CO2 container using weigh bills, scales, or load cells
according to Equation PP-4 of this section.
[GRAPHIC] [TIFF OMITTED] TR17DE10.014

Where:

CO2 = Annual mass of CO2 (metric tons).
Q = Annual mass in all CO2 containers imported or
exported during the reporting year (metric tons).

0
55. Section 98.424 is amended by:
0
a. Revising paragraphs (a)(1), (a)(2), and (a)(5).
0
b. Revising the second sentence of paragraph (b)(2).
0
c. Adding paragraph (c).

Sec.  98.424  Monitoring and QA/QC requirements.

    (a) * * *
    (1) Reporters following the procedures in Sec.  98.423(a) shall
determine quantity using a flow meter or meters located in accordance
with this paragraph.
    (i) If the CO2 stream is segregated such that only a
portion is captured for commercial application or for injection, you
must locate the flow meter according to the following:
    (A) For reporters following the procedures in Sec.
98.423(a)(3)(i), you must locate the flow meter(s) after the point of
segregation.
    (B) For reporters following the procedures in paragraph (a)(3)(ii)
of Sec.  98.423, you must locate the main flow meter(s) on the captured
CO2 stream(s) prior to the point of segregation and the
subsequent flow meter(s) on the CO2 stream(s) for on-site
use after the point of segregation. You may only follow the procedures
in paragraph (a)(3)(ii) of Sec.  98.423 if the CO2 stream(s)
for on-site use is/are the only diversion(s) from the main, captured
CO2 stream(s) after the main flow meter location(s).
    (ii) Reporters that have a mass flow meter or volumetric flow meter
installed to measure the flow of a CO2 stream that meets the
requirements of paragraph (a)(1)(i) of this section shall base
calculations in Sec.  98.423 of this subpart on the installed mass flow
or volumetric flow meters.
    (iii) Reporters that do not have a mass flow meter or volumetric
flow meter installed to measure the flow of the CO2 stream
that meets the requirements of paragraph (a)(1)(i) of this section
shall base calculations in Sec.  98.423 of this subpart on the flow of
gas transferred off site using a mass flow meter or a volumetric flow
meter located at the point of off-site transfer.
    (2) Reporters following the procedures in paragraph (b) of Sec.
98.423 shall determine quantity in accordance with this paragraph.
    (i) Reporters that supply CO2 in containers using weigh
bills, scales, or load cells shall measure the mass of contents of each
CO2 container to which the CO2 stream is
delivered, sum the mass of contents supplied in all containers to which
the CO2 stream is delivered during each quarter, sample the
CO2 stream delivering CO2 to containers on a
quarterly basis to determine the composition of the CO2
stream, and apply Equation PP-1.
    (ii) Reporters that supply CO2 in containers using
loaded container volumes shall measure the volume of contents of each
CO2 container to which the CO2 stream is
delivered, sum the volume of contents supplied in all containers to
which the CO2 stream is delivered during each quarter,
sample the CO2 stream on a quarterly basis to determine the
composition of the CO2 stream, determine the density
quarterly, and apply Equation PP-2.
* * * * *
    (5) Reporters using Equation PP-2 of this subpart and measuring
CO2 concentration as weight % CO2 shall determine
the density of the CO2 stream on a quarterly basis in order
to calculate the mass of the CO2 stream according to one of
the following procedures:
    (i) You may use a method published by a consensus-based standards
organization. Consensus-based standards organizations include, but are
not limited to, the following: ASTM International (100 Barr Harbor
Drive, P.O. Box CB700, West Conshohocken, Pennsylvania 19428-B2959,
(800) 262-1373, http://www.astm.org), the American National Standards
Institute (ANSI, 1819 L Street, NW., 6th floor, Washington, DC 20036,
(202) 293-8020, http://www.ansi.org), the American Gas Association
(AGA, 400 North Capitol Street, NW., 4th Floor, Washington, DC 20001,
(202) 824-7000, http://www.aga.org), the American Society of

Mechanical Engineers (ASME, Three Park Avenue, New York, NY 10016-5990,
(800) 843-2763, http://www.asme.org), the American Petroleum Institute
(API, 1220 L Street, NW., Washington, DC 20005-4070,<PHONE_NUMBER>,
http://www.api.org), and the North American Energy Standards Board
(NAESB, 801 Travis Street, Suite 1675, Houston, TX 77002, (713) 356-
0060, http://www.api.org). The method(s) used shall be documented in
the Monitoring Plan required under Sec.  98.3(g)(5).
    (ii) You may follow an industry standard method.
    (b) * * *
    (2) * * * Acceptable methods include, but are not limited to, the
U.S. Food and Drug Administration food-grade specifications for
CO2 (see 21 CFR 184.1240) and ASTM standard E1747-95
(Reapproved 2005) Standard Guide for Purity of Carbon Dioxide Used in
Supercritical Fluid Applications (ASTM International, 100 Barr Harbor
Drive, P.O. Box CB700, West Conshohocken, Pennsylvania 19428-B2959,
(800) 262-1373, http://www.astm.org).
    (c) You shall convert the density of the CO2 stream(s)
and all measured volumes of carbon dioxide to the following standard
industry temperature and pressure conditions: Standard cubic meters at
a temperature of 60 degrees Fahrenheit and at an absolute pressure of 1
atmosphere. If you apply the density value for CO2 at
standard conditions, you must use 0.001868 metric tons per standard
cubic meter.

0
56. Section 98.425 is amended by revising paragraph (a) introductory
text; and by adding paragraph (d) to read as follows:

Sec.  98.425  Procedures for estimating missing data.

    (a) Whenever the quality assurance procedures in Sec.  98.424(a)(1)
of this subpart cannot be followed to measure quarterly mass flow or
volumetric flow of CO2, the most appropriate of the
following missing data procedures shall be followed:
* * * * *
    (d) Whenever the quality assurance procedures in Sec.  98.424(a)(2)
of this subpart cannot be followed to measure quarterly quantity of
CO2 in containers, the most appropriate of the following
missing data procedures shall be followed:
    (1) A quarterly quantity of CO2 in containers that is
missing may be substituted with a quarterly value measured during
another representative quarter of the current reporting year.
    (2) A quarterly quantity of CO2 in containers that is
missing may be substituted with a quarterly value measured during the
same quarter from the past reporting year.
    (3) The quarterly quantity of CO2 in containers recorded
for purposes of product tracking and billing according to the
reporter's established procedures may be substituted for any period
during which measurement equipment is inoperable.

0
57. Section 98.426 is amended by:
0
a. Revising paragraphs (a) introductory text and (a)(2).
0
b. Adding paragraph (a)(5).
0
c. Revising paragraphs (b) introductory text, (b)(2), (b)(3), and
(b)(4).
0
d. Adding paragraph (b)(7).
0
e. Revising paragraphs (c) and (e)(1).

Sec.  98.426  Data reporting requirements.

* * * * *
    (a) If you use Equation PP-1 of this subpart, report the following
information for each mass flow meter or CO2 stream that
delivers CO2 to containers:
* * * * *
    (2) Quarterly mass in metric tons of CO2.
* * * * *
    (5) The location of the flow meter in your process chain in
relation to the points of CO2 stream capture, dehydration,
compression, and other processing.
* * * * *
    (b) If you use Equation PP-2 of this subpart, report the following
information for each volumetric flow meter or CO2 stream
that delivers CO2 to containers:
* * * * *
    (2) Quarterly volume in standard cubic meters of CO2.
    (3) Quarterly concentration of the CO2 stream in volume
or weight percent.
    (4) Report density as follows:
    (i) Quarterly density of CO2 in metric tons per standard
cubic meter if you report the concentration of the CO2
stream in paragraph (b)(3) of this section in weight percent.
    (ii) Quarterly density of the CO2 stream in metric tons
per standard cubic meter if you report the concentration of the
CO2 stream in paragraph (b)(3) of this section in volume
percent.
* * * * *
    (7) The location of the flow meter in your process chain in
relation to the points of CO2 stream capture, dehydration,
compression, and other processing.
    (c) For the aggregated annual mass of CO2 emissions
calculated using Equation PP-3a or PP-3b, report the following:
    (1) If you use Equation PP-3a of this subpart, report the annual
CO2 mass in metric tons from all flow meters and
CO2 streams that deliver CO2 to containers.
    (2) If you use Equation PP-3b of this subpart, report:
    (i) The total annual CO2 mass through main flow meter(s)
in metric tons.
    (ii) The total annual CO2 mass through subsequent flow
meter(s) in metric tons.
    (iii) The total annual CO2 mass supplied in metric tons.
    (iv) The location of each flow meter in relation to the point of
segregation.
* * * * *
    (e) * * *
    (1) The type of equipment used to measure the total flow of the
CO2 stream or the total mass or volume in CO2
containers.
* * * * *
[FR Doc. 2010-30286 Filed 12-16-10; 8:45 am]
BILLING CODE 6560-50-P


[Federal Register: March 20, 2009 (Volume 74, Number 53)]
[Notices]
[Page 11930]
[DOCID:fr20mr09-47]

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

DEPARTMENT OF ENERGY

Federal Energy Regulatory Commission

Combined Notice of Filings 1

March 13, 2009.
    Take notice that the Commission received the following electric
rate filings:
    Docket Numbers: ER03-752-003.
    Applicants: Solaro Energy Marketing Corporation.
    Description: Solaro Energy Marketing Corp submits supplement to
Substitute First Revised Sheet 1 to FERC Electric Tariff, Original 1,
in compliance with Order 697 under ER03-752.
    Filed Date: 03/11/2009.
    Accession Number: 20090312-0350.
    Comment Date: 5 p.m. Eastern Time on Wednesday, April 1, 2009.

    Docket Numbers: ER04-805-009.
    Applicants: Wabash Valley Power Association, Inc.
    Description: Wabash Valley Power Association, Inc submits a
supplemental filing to their 12/29/09 Updated Market Power Analysis
under ER04-805.
    Filed Date: 03/11/2009.
    Accession Number: 20090312-0352.
    Comment Date: 5 p.m. Eastern Time on Wednesday, April 1, 2009.

    Docket Numbers: ER06-1399-006.
    Applicants: Sunbury Generation LP.
    Description: Sunbury Generation, LP submits an amendment to the
June 2008 Compliance Filing under ER06-1399.
    Filed Date: 03/11/2009.
    Accession Number: 20090312-0351.
    Comment Date: 5 p.m. Eastern Time on Wednesday, April 1, 2009.

    Docket Numbers: ER09-405-001.
    Applicants: New York Independent System Operator, Inc.
    Description: New York Independent System Operator, Inc.'s Report on
Waiver Request under ER09-405.
    Filed Date: 03/11/2009.
    Accession Number: 20090311-5229.
    Comment Date: 5 p.m. Eastern Time on Wednesday, April 1, 2009.

    Docket Numbers: ER09-674-001.
    Applicants: ZZ Corporation.
    Description: ZZ Corporation submits a notice of cancellation of its
FERC Electric Tariff, Original Volume 1 under ER09-674.
    Filed Date: 03/11/2009.
    Accession Number: 20090312-0281.
    Comment Date: 5 p.m. Eastern Time on Monday, March 23, 2009.

    Docket Numbers: ER09-827-000.
    Applicants: Midwest Independent Transmission System Operator, Inc.
    Description: Midwest Independent Transmission System Operator, Inc
submits an executed amended and restated large generator
interconnection agreement with Green Lake Wind, LLC under ER09-827.
    Filed Date: 03/10/2009.
    Accession Number: 20090311-0056.
    Comment Date: 5 p.m. Eastern Time on Tuesday, March 31, 2009.

    Docket Numbers: ER09-828-000.
    Applicants: Public Service Electric & Gas Company.
    Description: Public Service Electric and Gas Company et al. request
for waivers of affiliate standards and authorizations for sales, as
well as a CD containing a Notice of Filing under ER09-828.
    Filed Date: 03/10/2009.
    Accession Number: 20090311-0057.
    Comment Date: 5 p.m. Eastern Time on Tuesday, March 31, 2009.

    Docket Numbers: ER09-829-000.
    Applicants: Southern California Edison Company.
    Description: Southern California Edison Company submits revised
rate sheets to the AES Huntington Beach Interconnection Service and
Facilities Agreement between SCE and AES Huntington Beach LLC under
ER09-829.
    Filed Date: 03/10/2009.
    Accession Number: 20090311-0064.
    Comment Date: 5 p.m. Eastern Time on Tuesday, March 31, 2009.

    Docket Numbers: ER09-830-000.
    Applicants: Consolidated Edison Company of New York, Inc.
    Description: Consolidated Edison Company of New York, Inc submits
First Revised Sheet 52 et al. to FERC Electric Tariff, First Revised
Rate Schedule 96: Pasny Delivery Service under ER09-830.
    Filed Date: 03/10/2009.
    Accession Number: 20090311-0063.
    Comment Date: 5 p.m. Eastern Time on Tuesday, March 31, 2009.

    Docket Numbers: ER09-831-000.
    Applicants: New York Independent System Operator, Inc.
    Description: New York Independent System Operator, Inc submits an
executed standard large generator interconnection agreement with Long
Island Lighting Company, d/b/a LIPA under ER09-831.
    Filed Date: 03/10/2009.
    Accession Number: 20090311-0055.
    Comment Date: 5 p.m. Eastern Time on Tuesday, March 31, 2009.
    Any person desiring to intervene or to protest in any of the above
proceedings must file in accordance with Rules 211 and 214 of the
Commission's Rules of Practice and Procedure (18 CFR 385.211 and
385.214) on or before 5 p.m. Eastern time on the specified comment
date. It is not necessary to separately intervene again in a subdocket
related to a compliance filing if you have previously intervened in the
same docket. Protests will be considered by the Commission in
determining the appropriate action to be taken, but will not serve to
make protestants parties to the proceeding. Anyone filing a motion to
intervene or protest must serve a copy of that document on the
Applicant. In reference to filings initiating a new proceeding,
interventions or protests submitted on or before the comment deadline
need not be served on persons other than the Applicant.
    The Commission encourages electronic submission of protests and
interventions in lieu of paper, using the FERC Online links at http://
www.ferc.gov. To facilitate electronic service, persons with Internet
access who will eFile a document and/or be listed as a contact for an
intervenor must create and validate an eRegistration account using the
eRegistration link. Select the eFiling link to log on and submit the
intervention or protests.
    Persons unable to file electronically should submit an original and
14 copies of the intervention or protest to the Federal Energy
Regulatory Commission, 888 First St., NE., Washington, DC 20426.
    The filings in the above proceedings are accessible in the
Commission's eLibrary system by clicking on the appropriate link in the
above list. They are also available for review in the Commission's
Public Reference Room in Washington, DC. There is an eSubscription link
on the Web site that enables subscribers to receive e-mail notification
when a document is added to a subscribed docket(s). For assistance with
any FERC Online service, please e-mail<EMAIL_ADDRESS>or
call<PHONE_NUMBER> (toll free). For TTY, call<PHONE_NUMBER>.

Nathaniel J. Davis, Sr.,
Deputy Secretary.
[FR Doc. E9-6081 Filed 3-19-09; 8:45 am]

BILLING CODE 6717-01-P


[Federal Register Volume 77, Number 109 (Wednesday, June 6, 2012)]
[Notices]
[Pages 33558-33559]
[FR Doc No: 2012-13662]

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DEPARTMENT OF TRANSPORTATION

Federal Motor Carrier Safety Administration

[Docket No. FMCSA-2012-0040]

Qualification of Drivers; Exemption Applications; Vision

AGENCY: Federal Motor Carrier Safety Administration (FMCSA), DOT.

ACTION: Notice of final disposition.

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SUMMARY: FMCSA announces its decision to exempt ten individuals from
the vision requirement in the Federal Motor Carrier Safety Regulations
(FMCSRs). The exemptions will enable these individuals to operate
commercial motor vehicles (CMVs) in interstate commerce without meeting
the prescribed vision requirement in one eye. The Agency has concluded
that granting these exemptions will provide a level of safety that is
equivalent to or greater than the level of safety maintained without
the exemptions for these CMV drivers.

DATES: The exemptions are effective June 6, 2012. The exemptions expire
on June 6, 2014.

FOR FURTHER INFORMATION CONTACT: Elaine M. Papp, Chief, Medical
Programs Division,<PHONE_NUMBER><EMAIL_ADDRESS>FMCSA,
Department of Transportation, 1200 New Jersey Avenue SE., Room W64-224,
Washington, DC 20590-0001. Office hours are from 8:30 a.m. to 5 p.m.
Monday through Friday, except Federal holidays.

SUPPLEMENTARY INFORMATION:

Electronic Access

    You may see all the comments online through the Federal Document
Management System (FDMS) at http://www.regulations.gov.
    Docket: For access to the docket to read background documents or
comments, go to http://www.regulations.gov at any time or Room W12-140
on the ground level of the West Building, 1200 New Jersey Avenue SE.,
Washington, DC, between 9 a.m. and 5 p.m., Monday through Friday,
except Federal holidays. The FDMS is available 24 hours each day, 365
days each year. If you want acknowledgement that we received your
comments, please include a self-addressed, stamped envelope or postcard
or print the acknowledgement page that appears after submitting
comments on-line.
    Privacy Act: Anyone may search the electronic form of all comments
received into any of our dockets by the name of the individual
submitting the comment (or of the person signing the comment, if
submitted on behalf of an association, business, labor union, etc.).
You may review DOT's Privacy Act Statement for the FDMS published in
the Federal Register on January 17, 2008 (73 FR 3316), or you may visit
http://edocket.access.gpo.gov/2008/pdf/E8-785.pdf.

Background

    On April 20, 2012, FMCSA published a notice of receipt of exemption
applications from certain individuals, and requested comments from the
public (77 FR 23779). That notice listed ten applicants' case
histories. The ten individuals applied for exemptions from the vision
requirement in 49 CFR 391.41(b)(10), for drivers who operate CMVs in
interstate commerce.
    Under 49 U.S.C. 31136(e) and 31315, FMCSA may grant an exemption
for a 2-year period if it finds ``such exemption would likely achieve a
level of safety that is equivalent to or greater than the level that
would be achieved absent such exemption.'' The statute also allows the
Agency to renew exemptions at the end of the 2-year period.
Accordingly, FMCSA has evaluated the ten applications on their merits
and made a determination to grant exemptions to each of them.

Vision and Driving Experience of the Applicants

    The vision requirement in the FMCSRs provides:
    A person is physically qualified to drive a commercial motor
vehicle if that person has distant visual acuity of at least 20/40
(Snellen) in each eye without corrective lenses or visual acuity
separately corrected to 20/40 (Snellen) or better with corrective
lenses, distant binocular acuity of a least 20/40 (Snellen) in both
eyes with or without corrective lenses, field of vision of at least
70[deg] in the horizontal meridian in each eye, and the ability to
recognize the colors of traffic signals and devices showing requirement
red, green, and amber (49 CFR 391.41(b)(10)).
    FMCSA recognizes that some drivers do not meet the vision
requirement but have adapted their driving to accommodate their vision
limitation and demonstrated their ability to drive safely. The ten
exemption applicants listed in this notice are in this category. They
are unable to meet the vision requirement in one eye for various
reasons, including amblyopia, macular degeneration, retinal scarring,
staphyloma, Coat's disease and prosthesis. In most cases, their eye
conditions were not recently developed. Nine of the applicants were
either born with their vision impairments or have had them since
childhood. The individual that sustained a vision condition as an adult
has had it for a period of four and a half years.
    Although each applicant has one eye which does not meet the vision
requirement in 49 CFR 391.41(b)(10), each has at least 20/40 corrected
vision in the other eye, and in a doctor's opinion, has sufficient
vision to perform all the tasks necessary to operate a CMV. Doctors'
opinions are supported by the applicants' possession of valid
commercial driver's licenses (CDLs) or non-CDLs to operate CMVs. Before
issuing CDLs, States subject drivers to knowledge and skills tests
designed to evaluate their qualifications to operate a CMV.
    All of these applicants satisfied the testing requirements for
their State of residence. By meeting State licensing requirements, the
applicants demonstrated their ability to operate a CMV, with their
limited vision, to the satisfaction of the State.
    While possessing a valid CDL or non-CDL, these ten drivers have
been authorized to drive a CMV in intrastate commerce, even though
their vision disqualified them from driving in interstate commerce.
They have driven CMVs with their limited vision for careers ranging
from 2 to 57 years. In the past 3 years, one of the drivers was
involved in a crash, and one was convicted of a moving violation in a
CMV.
    The qualifications, experience, and medical condition of each
applicant were stated and discussed in detail in the April 20, 2012
notice (77 FR 23799).

Basis for Exemption Determination

    Under 49 U.S.C. 31136(e) and 31315, FMCSA may grant an exemption
from the vision requirement in 49 CFR 391.41(b)(10) if the exemption is
likely to achieve an equivalent or greater level of safety than would
be achieved without the exemption. Without the exemption, applicants
will continue to be restricted to intrastate driving. With the
exemption, applicants can drive in interstate commerce. Thus, our
analysis focuses on whether an equal or greater level of safety is
likely to be achieved by permitting each of these drivers to drive in
interstate commerce as opposed to restricting him or her to driving in
intrastate commerce.
    To evaluate the effect of these exemptions on safety, FMCSA
considered the medical reports about the applicants' vision as well as
their driving records and experience with the vision deficiency.

    To qualify for an exemption from the vision requirement, FMCSA
requires a person to present verifiable evidence that he/she has driven
a commercial vehicle safely with the vision deficiency for the past 3
years. Recent driving performance is especially important in evaluating
future safety, according to several research studies designed to
correlate past and future driving performance. Results of these studies
support the principle that the best predictor of future performance by
a driver is his/her past record of crashes and traffic violations.
Copies of the studies may be found at Docket Number FMCSA-1998-3637.
    We believe we can properly apply the principle to monocular
drivers, because data from the Federal Highway Administration's (FHWA)
former waiver study program clearly demonstrate the driving performance
of experienced monocular drivers in the program is better than that of
all CMV drivers collectively (See 61 FR 13338, 13345, March 26, 1996).
The fact that experienced monocular drivers demonstrated safe driving
records in the waiver program supports a conclusion that other
monocular drivers, meeting the same qualifying conditions as those
required by the waiver program, are also likely to have adapted to
their vision deficiency and will continue to operate safely.
    The first major research correlating past and future performance
was done in England by Greenwood and Yule in 1920. Subsequent studies,
building on that model, concluded that crash rates for the same
individual exposed to certain risks for two different time periods vary
only slightly (See Bates and Neyman, University of California
Publications in Statistics, April 1952). Other studies demonstrated
theories of predicting crash proneness from crash history coupled with
other factors. These factors--such as age, sex, geographic location,
mileage driven and conviction history--are used every day by insurance
companies and motor vehicle bureaus to predict the probability of an
individual experiencing future crashes (See Weber, Donald C.,
``Accident Rate Potential: An Application of Multiple Regression
Analysis of a Poisson Process,'' Journal of American Statistical
Association, June 1971). A 1964 California Driver Record Study prepared
by the California Department of Motor Vehicles concluded that the best
overall crash predictor for both concurrent and nonconcurrent events is
the number of single convictions. This study used 3 consecutive years
of data, comparing the experiences of drivers in the first 2 years with
their experiences in the final year.
    Applying principles from these studies to the past 3-year record of
the ten applicants, one of the drivers was involved in a crash and one
was convicted of a moving violation in a CMV. All the applicants
achieved a record of safety while driving with their vision impairment,
demonstrating the likelihood that they have adapted their driving
skills to accommodate their condition. As the applicants' ample driving
histories with their vision deficiencies are good predictors of future
performance, FMCSA concludes their ability to drive safely can be
projected into the future.
    We believe that the applicants' intrastate driving experience and
history provide an adequate basis for predicting their ability to drive
safely in interstate commerce. Intrastate driving, like interstate
operations, involves substantial driving on highways on the interstate
system and on other roads built to interstate standards. Moreover,
driving in congested urban areas exposes the driver to more pedestrian
and vehicular traffic than exists on interstate highways. Faster
reaction to traffic and traffic signals is generally required because
distances between them are more compact. These conditions tax visual
capacity and driver response just as intensely as interstate driving
conditions. The veteran drivers in this proceeding have operated CMVs
safely under those conditions for at least 3 years, most for much
longer. Their experience and driving records lead us to believe that
each applicant is capable of operating in interstate commerce as safely
as he/she has been performing in intrastate commerce. Consequently,
FMCSA finds that exempting these applicants from the vision requirement
in 49 CFR 391.41(b)(10) is likely to achieve a level of safety equal to
that existing without the exemption. For this reason, the Agency is
granting the exemptions for the 2-year period allowed by 49 U.S.C.
31136(e) and 31315 to the ten applicants listed in the notice of April
20, 2012 (77 FR 23799).
    We recognize that the vision of an applicant may change and affect
his/her ability to operate a CMV as safely as in the past. As a
condition of the exemption, therefore, FMCSA will impose requirements
on the ten individuals consistent with the grandfathering provisions
applied to drivers who participated in the Agency's vision waiver
program.
    Those requirements are found at 49 CFR 391.64(b) and include the
following: (1) That each individual be physically examined every year
(a) by an ophthalmologist or optometrist who attests that the vision in
the better eye continues to meet the requirement in 49 CFR
391.41(b)(10) and (b) by a medical examiner who attests that the
individual is otherwise physically qualified under 49 CFR 391.41; (2)
that each individual provide a copy of the ophthalmologist's or
optometrist's report to the medical examiner at the time of the annual
medical examination; and (3) that each individual provide a copy of the
annual medical certification to the employer for retention in the
driver's qualification file, or keep a copy in his/her driver's
qualification file if he/she is self-employed. The driver must have a
copy of the certification when driving, for presentation to a duly
authorized Federal, State, or local enforcement official.

Discussion of Comments

    FMCSA received no comments in this proceeding.

Conclusion

    Based upon its evaluation of the ten exemption applications, FMCSA
exempts Rudolph P. Bisschop (MA), Richard Doroba (IL), Dennis E. Fisher
(NY), Charles W. Gajefski (CO), Steven M. Martin (IL), Charles A.
Padgett (FL), Joseph L. Ruff (GA), Tommy Thomas (CA), Malcom J.
Tilghman, Sr. (DE), and William S. Willis, Jr. (MD) from the vision
requirement in 49 CFR 391.41(b)(10), subject to the requirements cited
above (49 CFR 391.64(b)).
    In accordance with 49 U.S.C. 31136(e) and 31315, each exemption
will be valid for 2 years unless revoked earlier by FMCSA. The
exemption will be revoked if: (1) The person fails to comply with the
terms and conditions of the exemption; (2) the exemption has resulted
in a lower level of safety than was maintained before it was granted;
or (3) continuation of the exemption would not be consistent with the
goals and objectives of 49 U.S.C. 31136 and 31315.
    If the exemption is still effective at the end of the 2-year
period, the person may apply to FMCSA for a renewal under procedures in
effect at that time.

    Issued on: May 29, 2012.
Larry W. Minor,
Associate Administrator for Policy.
[FR Doc. 2012-13662 Filed 6-5-12; 8:45 am]
BILLING CODE 4910-EX-P


[Federal Register: November 16, 2007 (Volume 72, Number 221)]
[Notices]
[Page 64598]
[DOCID:fr16no07-49]

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DEPARTMENT OF ENERGY

Federal Energy Regulatory Commission

[Docket No. RP08-60-000]

Wisconsin Public Service Corporation, Complainant, v. ANR
Pipeline Company, Respondent; Notice of Complaint

November 8, 2007.
    Take notice that on November 7, 2007, Wisconsin Public Service
Corporation (WPSC), pursuant to Rule 206 of the Commission's Rules of
Practice and Procedure, 18 CFR 385.206, tendered for filing a complaint
against ANR Pipeline Company. WPSC states that it seeks an order from
the Commission finding that ANR may not require WPSC to reduce the
capacity under one particular transportation contract when it reduces
certain transportation and storage entitlements under another contract
as it is expressly permitted to do under section 35.4 of ANR's FERC Gas
Tariff. WPSC further states that it seeks expedited treatment of its
complaint.
    Any person desiring to intervene or to protest this filing must
file in accordance with Rules 211 and 214 of the Commission's Rules of
Practice and Procedure (18 CFR 385.211, 385.214). Protests will be
considered by the Commission in determining the appropriate action to
be taken, but will not serve to make protestants parties to the
proceeding. Any person wishing to become a party must file a notice of
intervention or motion to intervene, as appropriate. The Respondent's
answer and all interventions, or protests must be filed on or before
the comment date. The Respondent's answer, motions to intervene, and
protests must be served on the Complainants.
    The Commission encourages electronic submission of protests and
interventions in lieu of paper using the ``eFiling'' link at http://www.ferc.gov.
 Persons unable to file electronically should submit an

original and 14 copies of the protest or intervention to the Federal
Energy Regulatory Commission, 888 First Street, NE., Washington, DC
20426.
    This filing is accessible on-line at http://www.ferc.gov, using the

``eLibrary'' link and is available for review in the Commission's
Public Reference Room in Washington, DC. There is an ``eSubscription''
link on the web site that enables subscribers to receive e-mail
notification when a document is added to a subscribed docket(s). For
assistance with any FERC Online service, please e-mail
<EMAIL_ADDRESS>or call<PHONE_NUMBER> (toll free). For

TTY, call<PHONE_NUMBER>.
    Comment Date: 5 p.m. Eastern Time on November 28, 2007.

Kimberly D. Bose,
Secretary.
 [FR Doc. E7-22393 Filed 11-15-07; 8:45 am]

BILLING CODE 6717-01-P