Any position holder, refiner, or enterer, or biofuel
production facility who is required to report under section
95101 of this article must comply
with Subpart MM of 40 CFR Part 98 (§§
98.390 to
98.398) in reporting emissions and
related data to ARB, except as otherwise provided in this section.
(a)
GHGs to Report.
(1) In addition to the
CO
2 emissions specified under
40 CFR §
98.392, all refiners that produce liquefied
petroleum gas must report the CO
2,
CH
4, N
2O and
CO
2e emissions that would result from the complete
combustion or oxidation of the annual quantity of liquefied petroleum gas sold
or delivered, except for fuel for which a final destination outside California
can be demonstrated.
(2) Refiners,
position holders of fossil fuels and biomass-derived fuels that supply fuel at
California terminal racks, and enterers that import fossil transportation fuels
for distribution outside the bulk transfer/terminal system must report the
CO
2, CO
2 from biomass-derived
fuels, CH
4, N
2O, and
CO
2e emissions that would result from the complete
combustion or oxidation of each Blendstock, Distillate Fuel Oil or
biomass-derived fuel (Biomass-Based Fuel and Biomass) listed in Table 2-4 of
this section. However, emissions reporting is not required for fuel in which a
final destination outside California, where a use in exclusively aviation or
marine applications can be demonstrated, or for fossil transportation fuels
that can be demonstrated to have been previously delivered by a position holder
or refiner out of an upstream California terminal or refinery rack prior to
delivery out of a second terminal rack. The volume of all Blendstocks,
Distillate Fuel Oils, and biomass-derived fuels that are excluded from
emissions reporting based on the criteria in this paragraph must be reported
pursuant to the requirements in section
95121(d)(9). No
fuel shall be reported as finished fuel. Fuels must be reported as the
individual Blendstock, Distillate Fuel Oil or biomass-derived fuel listed in
Table 2-4 of this section. For purposes of this article, CARBOB blendstocks are
reported as RBOB blendstocks.
(b)
Calculating GHG
emissions.
(1) Refiners, position
holders at California terminals, and enterers that import fossil transportation
fuels for distribution outside the bulk transfer system must use Equation MM-1
as specified in 40 CFR
§
98.393(a)(1) to
estimate the CO
2 emissions that would result from the
complete combustion of the fuel. Emissions must be based on the quantity of
fuel removed from the rack (for refiners and position holders), fuel imported
for distribution outside the bulk transfer/terminal system (by enterers), and
fuel sold to unlicensed entities as specified in section
95121(d)(3) (by
refiners). For fuels that are blended, emissions must be reported for each
individual Blendstock, Distillate Fuel Oil or biomass-derived fuel listed in
Table 2-5 of this section separately, and not as motor gasoline (finished),
biofuel blends, or other similar finished fuel. Emissions from denatured fuel
ethanol must be calculated as 100 percent ethanol only. The volume of
denaturant is assumed to be zero and is not required to be reported. Emission
factors must be taken from column C of
40 CFR
98 Table MM-1 or MM-2 as specified in
Calculation Method 1 of 40
CFR §
98.393(f)(1),
except that the emission factor for renewable diesel is equivalent to the
emission factor for Distillate No. 2. If a position holder in diesel or
biodiesel fuel does not have sealed or financial transaction meters at the
rack, and the position holder is the sole position holder at the terminal, the
position holder must calculate emissions based on the delivering entity's
invoiced volume of fuel or a meter that meets the requirements of section
95103(k) either
at the rack or at a point prior to the fuel going into the terminal storage
tanks.
(2) Refiners that produce
liquefied petroleum gas must use Equation MM-1 as specified in
40 CFR §
98.393(a)(1) to estimate the
CO
2 emissions that would result from the complete
combustion of the fuel supplied. For calculating the emissions from liquefied
petroleum gas, the emissions from the individual components must be summed.
Emission factors must be taken from column C of 40 CFR Part
98 Table MM-1 as
specified in Calculation Method 1 of
40 CFR §
98.393(f)(1).
(3) Refiners, position holders at California
terminals, and enterers identified in this section must estimate and report
CH
4 and N
2O emissions using
Equation C-8 and Table C-2 as described in
40 CFR §
98.33(c)(1), except that the
emission factors in Table 2-4 of this section will be used for each fuel
required to be reported in section
95121(a)(2)
above.
Table 2-4. Transportation Fuel
CH4 and N2O emission
factors
Fuel
|
CH4
(g/bbl)
|
N2O
(g/bbl)
|
Blendstock |
20 |
20 |
Distillate |
2 |
1 |
Ethanol |
37 |
27 |
Biodiesel and Renewable Diesel |
2 |
1 |
(4) All fuel suppliers in this section must
estimate CO
2e emissions using the following equation:
Click
here to view image
Where:
CO2e = Carbon dioxide
equivalent, metric tons/year.
GHGi = Mass emissions of
CO2, CH4,
N2O from fuels combusted or oxidized.
GWPi = Global warming potential
for each greenhouse gas as specified in the "global warming potential"
definition of this article.
n = Number of greenhouse gases
emitted.
(c)
Monitoring and QA/QC Requirements. For the emissions
calculation method chosen under section
95121(b), the
operator must meet all the monitoring and QA/QC requirements as specified in
40 CFR §
98.394, and the requirements of
40 CFR §
98.3(i) as further specified
in section
95103 of this article and below.
(1) Position holders are exempt from
40 CFR §
98.3(i) calibration
requirements except when the position holder and entity receiving the fuel have
common ownership or are owned by subsidiaries or affiliates of the same
company. In such cases the 40 CFR §
98.3(i) calibration
requirements apply, unless:
(A) The fuel
supplier does not operate the fuel billing meter;
(B) The fuel billing meter is also used by
companies that do not share common ownership with the fuel supplier;
or
(C) The fuel billing meter is
sealed with a valid seal from the county sealer of weights and measures and the
operator has no reason to suspect inaccuracies.
(2) As required by
40 CFR §
98.394(a)(1)(iii), for fuels
that are liquid at 60 degrees Fahrenheit and one standard atmosphere, the
volume reported must be temperature- and pressure-adjusted to these conditions.
For liquefied petroleum gas the volume reported must be temperature-adjusted to
60 degrees Fahrenheit.
(d)
Data Reporting
Requirements. In addition to reporting the information required in
40 CFR §
98.3(c), the following
entities must also report the information identified below:
(1) California position holders must report
the annual quantity in barrels, as reported by the terminal operator, of each
Blendstock, Distillate Fuel Oil, or biomass-derived fuel listed in Table 2-5 of
this section, that is delivered across the rack in California, except for fuel
for which a final destination outside California, where use in exclusively
aviation or marine applications can be demonstrated, or for fossil
transportation fuels that can be demonstrated to have been previously delivered
by a position holder or refiner out of an upstream California terminal or
refinery rack prior to delivery out of a second terminal rack. Denatured fuel
ethanol will be reported with the entire volume as 100 percent ethanol only.
The volume of denaturant is assumed to be zero and is not required to be
reported.
(2) California position
holders that are also terminal operators and refiners must report the annual
quantity in barrels delivered across the rack of each Blendstock, Distillate
Fuel Oil, or biomass-derived fuel listed in Table 2-4 of this section, except
for fuel for which a final destination outside California, where a use in
exclusively aviation or marine applications can be demonstrated, or for fossil
transportation fuels that can be demonstrated to have been previously delivered
by a position holder or refiner out of an upstream California terminal or
refinery rack prior to delivery out of a second terminal rack. Denatured fuel
ethanol will be reported with the entire volume as 100 percent ethanol only.
The volume of denaturant is assumed to be zero and is not required to be
reported. If there is only a single position holder at the terminal, and only
diesel or biodiesel is being dispensed at the rack then the position holder
must report the annual quantity of fuel using a meter meeting the requirements
of section
95103(k) or
billing invoices from the entity delivering fuel to the terminal.
(3) Refiners that supply fuel within the bulk
transfer system to entities not licensed by the California Board of
Equalization as a fuel supplier must report the annual quantity in barrels
delivered of each Blendstock, Distillate Fuel Oil, or biomass-derived fuel
listed in Table 2-5 of this section, except for fuel for which a final
destination outside California or where a use in exclusively aviation or marine
applications can be demonstrated. Denatured fuel ethanol will be reported with
the entire volume as 100 percent ethanol only. The volume of denaturant is
assumed to be zero and is not required to be reported.
(4) Enterers delivering fossil transportation
fuels for distribution outside the bulk transfer/terminal system must report
the annual quantity in barrels, as reported on the bill of lading or other
shipping documents of each Blendstock, Distillate Fuel Oil, or biomass-derived
fuel listed in Table 2-5 of this section that is imported as a blended
component of a finished transportation fuel, except for fuel for which a final
destination outside California or where a use in exclusively aviation or marine
applications can be demonstrated. The denatured fuel ethanol component of a
finished transportation fuel must be reported with the entire denatured ethanol
volume as 100 percent ethanol only. The volume of denaturant is assumed to be
zero and is not required to be reported. Biodiesel or renewable diesel blends
containing no more than one percent petroleum diesel by volume are considered
to be 100 percent biodiesel or renewable diesel. Biomass-derived fuels are not
reported by enterers unless they are a blended component of an imported
finished transportation fuel.
(5)
In addition to the information required in
40 CFR §
98.396, refiners must also report the volume
of liquefied petroleum gas in barrels supplied in California as well as the
volumes of the individual components as listed in
40 CFR
98 Table MM-1, except for fuel for which a
final destination outside California can be demonstrated.
(6) All fuel suppliers identified in this
section must also report CO
2, CO
2
from biomass-derived fuels, CH
4,
N
2O and CO
2e emissions in metric
tons that would result from the complete combustion or oxidation of each
petroleum fuel identified in 95121(a)(2), liquefied petroleum gas, or
biomass-derived fuel reported in this section, calculated according to section
95121(b).
(7) All fuel suppliers identified in this
section, except for refiners that report pursuant to section
95113(m), must
report the total quantity of CARBOB, California Gasoline, California diesel
fuel, and biodiesel and/or renewable diesel that was imported from outside of
California for use in California. In addition, for CARBOB imports, the
designated percentage of oxygenate must be reported.
(8) Fuel suppliers identified in this
section, except for refiners that report pursuant to section
95113(m), must
report the total quantity of biodiesel and/or renewable diesel blended in
California diesel for use in California.
(9) Fuel suppliers identified in this section
must report the total quantity in barrels of each Blendstock, Distillate Fuel
Oil, or biomass-derived fuel listed in Table 2-4 of this section that is
excluded from emissions reporting due to demonstration of final destination
outside California or use in exclusively aviation or marine applications, or
demonstration that the fuel was previously delivered by a position holder or
refiner out of an upstream California terminal or refinery rack prior to
delivery out of a second terminal rack.
(e)
Procedures for Missing
Data. For quantities of fuels that are purchased, sold, or transferred
in any manner, fuel suppliers must follow the missing data procedures specified
in 40 CFR §
98.395. The supplier must document and retain
records of the procedure used for all missing data estimates pursuant to the
recordkeeping requirements of section
95105.
Table 2-5 Blendstocks, Distillate Fuel
Oils, and Biomass-Derived Fuels Subject to Reporting under section
95121
CBOB--Summer
Regular
Midgrade
Premium
CBOB--Winter
Regular
Midgrade
Premium
RBOB (CARBOB)--Summer
Regular
Midgrade
Premium
RBOB (CARBOB)--Winter
Regular
Midgrade
Premium
Distillate Fuel Oils
Distillate No. 1
Distillate No. 2
Liquefied Petroleum Gas (LPG)
Ethane
Ethylene
Propane
Propylene
Butane
Butylene
Isobutane
Isobutylene
Pentanes Plus
Biomass-Derived Fuel
Ethanol (100%)
Biodiesel (>=99%, methyl ester)
Renewable Diesel (>=99%)
Rendered Animal Fat
Vegetable Oil