[Code of Federal Regulations]
[Title 40, Volume 14]
[Revised as of July 1, 2003]
From the U.S. Government Printing Office via GPO Access
[CITE: 40CFR75.19]
[Page 225-242]
TITLE 40--PROTECTION OF ENVIRONMENT
CHAPTER I--ENVIRONMENTAL PROTECTION AGENCY (CONTINUED)
PART 75--CONTINUOUS EMISSION MONITORING--Table of Contents
Subpart B--Monitoring Provisions
Sec. 75.19 Optional SO2, NOX, and CO2
emissions calculation for low mass emissions (LME) units.
(a) Applicability and qualification. (1) For units that meet the
requirements of this paragraph (a)(1) and paragraphs (a)(2) and (b) of
this section, the low mass emissions excepted methodology in paragraph
(c) of this section may be used in lieu of continuous emission
monitoring systems or, if applicable, in lieu of excepted methods under
appendix D or E to this part, for the purpose of determining hourly heat
input and hourly NOX, SO2, and CO2 mass
emissions under this part.
(i) A low mass emissions unit is an affected unit that is gas-fired,
or oil-fired (as defined in Sec. 72.2 of this chapter), and for which:
(A) An initial demonstration is provided, in accordance with
paragraph
[[Page 226]]
(a)(2) of this section, which shows that the unit emits:
(1) No more than 25 tons of SO2 annually and less than
100 tons of NOX annually, for Acid Rain Program affected
units. If the unit is also subject to the provisions of subpart H of
this part, no more than 50 of the allowable annual tons of
NOX may be emitted during the ozone season; or
(2) Less than 100 tons of NOX annually and no more than
50 tons of NOX during the ozone season, for non-Acid Rain
Program units subject to the provisions of subpart H of this part, for
which the owner or operator reports emissions data on a year-round
basis, in accordance with Sec. 75.74(a) or Sec. 75.74(b); or
(3) No more than 50 tons of NOX per ozone season, for
non-Acid Rain Program units subject to the provisions of subpart H of
this part, for which the owner or operator reports emissions data only
during the ozone season, in accordance with Sec. 75.74(b); and
(B) An annual demonstration is provided thereafter, using one of the
allowable methodologies in paragraph (c) of this section, showing that
the low mass emissions unit continues to emit no more than the
applicable number of tons of SO2 and/or NOX
specified in paragraph (a)(1)(i)(A) of this section.
(C) This paragraph, (a)(1)(i)(C), applies only to a unit that is
subject to an SO2 emission limitation under the Acid Rain
Program, and that combusts a gaseous fuel other than pipeline natural
gas or natural gas (as defined in Sec. 72.2 of this chapter). The owner
or operator of such a unit must quantify the sulfur content and
variability of the gaseous fuel by performing the demonstration
described in section 2.3.6 of appendix D to this part, in order for the
unit to qualify for LME unit status. If the results of that
demonstration show that the gaseous fuel qualifies under paragraph (b)
of section 2.3.6 to use a default SO2 emission rate to report
SO2 mass emissions under this part, the unit is eligible for
LME unit status.
(ii) Each qualifying LME unit must start using the low mass
emissions excepted methodology as follows:
(A) For a unit that reports emission data on a year-round basis,
begin using the methodology in the first unit operating hour in the
calendar year designated in the certification application as the first
year that the methodology will be used; or
(B) For a unit that is subject to Subpart H of this part and that
reports only during the ozone season according to Sec. 75.74(c), begin
using the methodology in the first unit operating hour in the ozone
season designated in the certification application as the first ozone
season that the methodology will be used.
(C) For a new or newly-affected unit, see paragraph (b)(4) of this
section for additional guidance.
(2) A unit may initially qualify as a low mass emissions unit if the
designated representative submits a certification application to use the
LME methodology (as described in Sec. 75.63(a)(1)(ii) and in this
paragraph, (a)(2)) and the Administrator (or permitting authority, as
applicable) certifies the use of such methodology. The certification
application shall be submitted no later than 45 days prior to the date
on which use of the low mass emissions methodology is expected to
commence, and the application must contain:
(i) A statement identifying the projected date on which the LME
methodology will first be used. The projected commencement date shall be
consistent with paragraphs (a)(1)(ii) and (b)(4) of this section, as
applicable; and
(ii) Either:
(A) Actual SO2 and/or NOX mass emissions data
(as applicable) for each of the three calendar years (or ozone seasons)
prior to the calendar year in which the certification application is
submitted demonstrating to the satisfaction of the Administrator or (if
applicable) the permitting authority, that the unit emitted less than
the applicable number of tons of SO2 and/or NOX
specified in paragraph (a)(1)(i)(A) of this section. For the purposes of
this paragraph, (a)(2)(ii)(A), the required actual SO2 or
NOX mass emissions for each qualifying year or ozone season
shall be determined using the SO2, NOX and heat
input data reported to the Administrator in the electronic quarterly
reports required under Sec. 75.64 or under the Ozone Transport
Commission (OTC)
[[Page 227]]
NOX Budget Trading Program. Notwithstanding this requirement,
in the absence of such electronic reports, an estimate of the actual
emissions for each of the previous three years (or ozone seasons) shall
be provided, using either the maximum rated heat input methodology
described in paragraph (c)(3)(i) of this section or procedures
consistent with the long term fuel flow heat input methodology described
in paragraph (c)(3)(ii) of this section, in conjunction with the
appropriate SO2 or NOX emission rate from
paragraph (c)(1)(i) of this section for SO2, and paragraph
(c)(1)(ii) or (c)(1)(iv) of this section for NOX.
Alternatively, the initial estimate of the NOX emission rate
may be based on historical emission test data that is representative of
operation at normal load or historical data from a CEMS certified under
part 60 of this chapter or under a state CEM program; or
(B) When the three full years (or ozone seasons) of actual
SO2 and NOX mass emissions data (or reliable
estimates thereof) described under paragraph (a)(2)(ii)(A) of this
section do not exist, the designated representative may submit an
application to use the low mass emissions excepted methodology based
upon a combination of actual historical SO2 and
NOX mass emissions data and projected SO2 and
NOX mass emissions, totaling three years (or ozone seasons).
Except as provided in paragraph (a)(3) of this section, actual data must
be used for any years (or ozone seasons) in which such data exists and
projected data should be used for any remaining future years (or ozone
seasons) needed to provide emissions data for three consecutive calender
years (or ozone seasons). For example, if a unit commenced operation two
years ago, the designated representative may submit actual, historical
data for the previous two years and one year of projected emissions for
the current calendar year or, for a new unit, the designated
representative may submit three years of projected emissions, beginning
with the current calendar year. Any actual or projected annual emissions
must demonstrate to the satisfaction of the Administrator that the unit
will emit less than the applicable number of tons of SO2 and/
or NOX specified in paragraph (a)(1)(i)(A) of this section.
Projected emissions shall be calculated using either the appropriate
default emission rates from paragraphs (c)(1)(i) and (c)(1)(ii) of this
section (or, alternatively for NOX, a conservative estimate
of the NOX emission rate, as described in paragraph (a)(4) of
this section), in conjunction with projections of unit operating hours
or fuel type and fuel usage, according to one of the allowable
calculation methodologies in paragraph (c) of this section; and
(iii) A description of the methodology from paragraph (c) of this
section that will be used to demonstrate on-going compliance under
paragraph (b) of this section; and
(iv) Appropriate documentation demonstrating that the unit is
eligible to use projected emissions to qualify for LME status under
paragraph (a)(3) of this section (if applicable).
(3) In the following circumstances, projected emissions for a future
year (or years) may be used in lieu of the actual emissions data from
one (or more) of the three years (or ozone seasons) preceding the year
of the certification application:
(i) If the owner or operator takes an enforceable permit restriction
on the number of annual or ozone season unit operating hours for the
future year (or years), such that the unit will emit no more than the
applicable number of tons of SO2 and/or NOX
specified in paragraph (a)(1)(i)(A) of this section; or
(ii) If the actual emissions for one (or more) of the three years
(or ozone seasons) prior to the year of the certification application is
not representative of the present and expected future emissions from the
unit, because the owner or operator has recently installed emission
controls on the unit.
(4) When the owner or operator elects to demonstrate initial LME
qualification and on-going compliance using a fuel-and-unit-specific
NOX emission rate in accordance with paragraph (c)(1)(iv) of
this section, there will be instances (e.g., for a new or newly-affected
unit) where it is not possible to determine that NOX emission
rate prior to submitting the certification application. In such cases,
if the generic default NOX emission rates in Table LM-
[[Page 228]]
2 of this section are inappropriately high for the unit, the owner or
operator may use a more representative, but conservatively high estimate
of the expected NOX emission rate, for the purposes of the
initial monitoring plan submittal and to calculate the unit's projected
annual or ozone season emissions under paragraph (a)(2)(ii)(B) of this
section. For example, the NOX emission rate could, as
described in paragraph (a)(2)(ii)(A) of this section, be estimated using
historical CEM data or historical emission test data that is
representative of operation at normal load. The NOX emission
limit specified in the operating permit for the unit could also be used
to estimate the NOX emission rate (except for units equipped
with SCR or SNCR), or, consistent with paragraph (c)(1)(iv)(C)(4) of
this section, for a unit that uses SCR or SNCR to control NOX
emissions, an estimated default NOX emission rate of 0.15 lb/
mmBtu could be used. However, these estimated NOX emission
rates may not be used for reporting purposes in the time period
extending from the first hour in which the LME methodology is used to
the date and hour on which the fuel-and-unit-specific NOX
emission rate testing is completed. Rather, in that interval, the owner
or operator shall either report the appropriate default NOX
emission rate from Table LM-2, or shall report the maximum potential
NOX emission rate, calculated in accordance with Sec. 72.2 of
this chapter and section 2.1.2.1 of appendix A to this part. Then,
beginning with the first unit operating hour after completion of the
tests, the appropriate default NOX emission rate(s) obtained
from the fuel-and-unit-specific testing shall be used for emissions
reporting.
(b) On-going qualification and disqualification. (1) Once a low mass
emissions unit has qualified for and has started using the low mass
emissions excepted methodology, an annual demonstration is required,
showing that the unit continues to emit no more than the applicable
number of tons of SO2 and/or NOX specified in
paragraph (a)(1)(i)(A) of this section. The calculation methodology used
for the annual demonstration shall be the methodology described in the
certification application under paragraph (a)(2)(iii) of this section.
(2) If any low mass emissions unit fails to provide the required
annual demonstration under paragraph (b)(1) of this section, such that
the calculated cumulative emissions for the unit exceed the applicable
number of tons of SO2 and/or NOX specified in
paragraph (a)(1)(i)(A) of this section at the end of any calendar year
or ozone season, then:
(i) The low mass emissions unit shall be disqualified from using the
low mass emissions excepted methodology; and
(ii) The owner or operator of the low mass emissions unit shall
install and certify monitoring systems that meet the requirements of
Secs. 75.11, 75.12, and 75.13, and shall report SO2 (Acid
Rain Program units, only), NOX, and CO2 (Acid Rain
Program units, only) emissions data and heat input data from such
monitoring systems by December 31 of the calendar year following the
year in which the unit exceeded the number of tons of SO2
and/or NOX specified in paragraph (a)(1)(i)(A) of this
section; and
(iii) If the required monitoring systems have not been installed and
certified by the applicable deadline in paragraph (b)(2)(ii) of this
section, the owner or operator shall report the following values for
each unit operating hour, beginning with the first operating hour after
the deadline and continuing until the monitoring systems have been
provisionally certified: the maximum potential hourly heat input for the
unit, as defined in Sec. 72.2 of this chapter; the SO2
emissions, in lb/hr, calculated using the applicable default
SO2 emission rate from paragraph (c)(1)(i) of this section
and the maximum potential hourly unit heat input; the CO2
emissions, in tons/hr, calculated using the applicable default
CO2 emission rate from paragraph (c)(1)(iii) of this section
and the maximum potential hourly unit heat input; and the maximum
potential NOX emission rate, as defined in Sec. 72.2 of this
chapter.
(3) If a low mass emissions unit that initially qualifies to use the
low mass emissions excepted methodology under this section changes
fuels, such that a fuel other than those allowed for use in
[[Page 229]]
the low mass emissions methodology is combusted in the unit, the unit
shall be disqualified from using the low mass emissions excepted
methodology as of the first hour that the new fuel is combusted in the
unit. The owner or operator shall install and certify SO2
(Acid Rain Program units, only), NOX, and CO2
(Acid Rain Program units, only) and flow (if necessary) monitoring
systems that meet the requirements of Secs. 75.11, 75.12, and 75.13
prior to a change to such fuel, and shall report emissions data from
such monitoring systems beginning with the date and hour on which the
new fuel is first combusted in the unit. If the required monitoring
systems are not installed and certified prior to the fuel switch, the
owner or operator shall report (as applicable) the maximum potential
concentration of SO2, CO2 and NOX, the
maximum potential NOX emission rate, the maximum potential
flowrate, the maximum potential hourly heat input and the maximum (or
minimum, if appropriate) potential moisture percentage, from the date
and hour of the fuel switch until the monitoring systems are certified
or until probationary calibration error tests of the monitors are passed
and the conditional data validation procedures in Sec. 75.20(b)(3) begin
to be used. All maximum and minimum potential values shall be specific
to the new fuel and shall be determined in a manner consistent with
section 2 of appendix A to this part and Sec. 72.2 of this chapter. The
owner or operator must notify the Administrator (or the permitting
authority) in the case where a unit switches fuels without previously
having installed and certified a SO2, NOX and
CO2 monitoring system meeting the requirements of
Secs. 75.11, 75.12, and 75.13.
(4) If a new of newly-affected unit initially qualifies to use the
low mass emissions excepted methodology under this section and the owner
or operator wants to use the low mass emissions methodology for the
unit, he or she must:
(i) Keep the records specified in paragraph (c)(2) of this section,
beginning with the date and hour of commencement of commercial
operation, for a new unit subject to an Acid Rain emission limitation,
and beginning with the date and hour of the commencement of operation,
for a new unit subject to a NOX mass reduction program under
subpart H of this part. For newly-affected units, the records in
paragraph (c)(2) of this section shall be kept as follows:
(A) For Acid Rain Program units, begin keeping the records as of the
first hour of commercial operation of the unit following the date on
which the unit becomes affected; or
(B) For units subject to a NOX mass reduction program
under subpart H of this part, begin keeping the records as of the first
hour of unit operation following the date on which the unit becomes an
affected unit;
(ii) Use these records to determine the cumulative heat input and
SO2, CO2, and/or NOX mass emissions in
order to continue to qualify as a low mass emissions unit; and
(iii) Determine the cumulative SO2 and/or NOX
mass emissions according to paragraph (c) of this section using the same
procedures used after the certification deadline for the unit, for
purposes of demonstrating eligibility to use the excepted methodology
set forth in this section. For example, use the default emission rates
in Tables LM-1, LM-2, and LM-3 of this section or use the fuel-and-unit-
specific NOX emission rate determined according to paragraph
(c)(1)(iv) of this section. For Acid Rain Program LME units, the
Administrator will not count SO2 mass emissions calculated
for the period between commencement of commercial operation and the
certification deadline for the unit under Sec. 75.4 against
SO2 allowances to be held in the unit account.
(5) A low mass emissions unit that has been disqualified from using
the low mass emissions excepted methodology may subsequently submit an
application to qualify again to use the low mass emissions methodology
under paragraph (a)(2) of this section only if, following the non-
compliant year (or ozone season), at least three full years (or ozone
seasons) of actual, monitored emissions data is obtained showing that
the unit emitted no more than the applicable number of tons of
SO2 and/or NOX specified in paragraph (a)(1)(i)(A)
of this section. Further, the designated representative or authorized
account
[[Page 230]]
representative must certify in the application that the unit operation
for the years or ozone seasons for which the emissions were monitored
are representative of the projected future operation of the unit.
(c) Low mass emissions excepted methodology, calculations, and
values. (1) Determination of SO2, NOX, and
CO2 emission rates.
(i) If the unit combusts only natural gas and/or fuel oil, use Table
LM-1 of this section to determine the appropriate SO2
emission rate for use in calculating hourly SO2 mass
emissions under this section (Acid Rain Program units, only). If the
unit combusts gaseous fuel(s) other than natural gas, the owner or
operator shall use the procedures in section 2.3.6 of appendix D to this
part to document the total sulfur content of each such fuel and to
determine the appropriate default SO2 emission rate for each
such fuel.
(ii) If the unit combusts only natural gas and/or fuel oil, use
either the appropriate NOX emission factor from Table LM-2 of
this section, or a fuel-and-unit-specific NOX emission rate
determined according to paragraph (c)(1)(iv) of this section, to
calculate hourly NOX mass emissions under this section. If
the unit combusts a gaseous fuel other than pipeline natural gas or
natural gas, the owner or operator shall determine a fuel-and-unit-
specific NOX emission rate according to paragraph (c)(1)(iv)
of this section.
(iii) If the unit combusts only natural gas and/or fuel oil, use
Table LM-3 of this section to determine the appropriate CO2
emission rate for use in calculating hourly CO2 mass
emissions under this section (Acid Rain Program units, only). If the
unit combusts a gaseous fuel other than pipeline natural gas or natural
gas, the owner or operator shall determine a fuel-and-unit-specific
CO2 emission rate for the fuel, as follows:
(A) Derive a carbon-based F-factor for the fuel, using fuel sampling
and analysis, as described in section 3.3.6 of appendix F to this part;
and
(B) Use Equation G-4 in appendix G to this part to derive the
default CO2 emission rate. Rearrange the equation, solving it
for the ratio of WCO2/H (this ratio will yield an emission
rate, in units of tons/mmBtu). Then, substitute the carbon-based F-
factor determined in paragraph (c)(1)(iii)(A) of this section into the
rearranged equation to determine the default CO2 emission
rate for the unit.
(iv) In lieu of using the default NOX emission rate from
Table LM-2 of this section, the owner or operator may, for each fuel
combusted by a low mass emissions unit, determine a fuel-and-unit-
specific NOX emission rate for the purpose of calculating
NOX mass emissions under this section. This option may be
used by any unit which qualifies to use the low mass emission excepted
methodology under paragraph (a) of this section, and also by groups of
units which combust fuel from a common source of supply and which use
the long term fuel flow methodology under paragraph (c)(3)(ii) of this
section to determine heat input. The testing must be completed in a
timely manner, such that the test results are reported electronically no
later than the end of the calendar year or ozone season in which the LME
methodology is first used. If this option is chosen, the following
procedures shall be used.
(A) Except as otherwise provided in paragraphs (c)(1)(iv)(F),
(c)(1)(iv)(G), and (c)(1)(iv)(I) of this section, determine a fuel-and-
unit-specific NOX emission rate by conducting a four load
NOX emission rate test procedure as specified in section 2.1
of appendix E to this part, for each type of fuel combusted in the unit.
For a group of units sharing a common fuel supply, the appendix E
testing must be performed on each individual unit in the group, unless
some or all of the units in the group belong to an identical group of
units, as defined in paragraph (c)(1)(iv)(B) of this section, in which
case, representative testing may be conducted on units in the identical
group of units, as described in paragraph (c)(1)(iv)(B) of this section.
For the purposes of this section, make the following modifications to
the appendix E test procedures:
(1) Do not measure the heat input as required under 2.1.3 of
appendix E to this part.
(2) Do not plot the test results as specified under 2.1.6 of
appendix E to this part.
[[Page 231]]
(3) When using Method 20 for turbines do not correct the
NOX concentration to 15% O2.
(4) If the testing is performed on an uncontrolled diffusion flame
turbine, a correction to the observed average NOX
concentration from each run of the Method 20 test must be applied using
the following Equation LM-1a.
[GRAPHIC] [TIFF OMITTED] TR12JN02.000
Where:
NOXcorr = Corrected NOX concentration (ppm).
NOXobs = Average measured NOX concentration for
each run of the Method 20 test (ppm).
Pr = Average annual atmospheric pressure (or average ozone
season atmospheric pressure for a Subpart H unit that reports data only
during the ozone season) at the nearest weather station (e.g., a
standardized NOAA weather station located at the airport) for the year
(or ozone season) prior to the year of the test (mm Hg).
Po = Observed atmospheric pressure during the test run (mm
Hg).
Hr = Average annual atmospheric humidity ratio (or average
ozone season humidity ratio for a Subpart H unit that reports data only
during the ozone season) at the nearest weather station, for the year
(or ozone season) prior to the year of the test (g H2O/g
air).
Ho = Observed humidity ratio during the test run (g
H2O/g air).
Tr = Average annual atmospheric temperature (or average ozone
season atmospheric temperature for a Subpart H unit that reports data
only during the ozone season) at the nearest weather station, for the
year (or ozone season) prior to the year of the test ( deg. K).
Ta = Observed atmospheric temperature during the test run
( deg. K).
(B) Representative appendix E testing may be done on low mass
emission units in a group of identical units. All of the units in a
group of identical units must combust the same fuel type but do not have
to share a common fuel supply.
(1) To be considered identical, all low mass emission units must be
of the same size (based on maximum rated hourly heat input),
manufacturer and model, and must have the same history of modifications
(e.g., have the same controls installed, the same types of burners and
have undergone major overhauls at the same frequency (based on hours of
operation)). Also, under similar operating conditions, the stack or
turbine outlet temperature of each unit must be within 50
degrees Fahrenheit of the average stack or turbine outlet temperature
for all of the units.
(2) If all of the low mass emission units in the group qualify as
identical, then representative testing of the units in the group may be
performed according to Table LM-4 of this section.
(3) [Reserved]
(4) If the acceptance criteria in paragraph (c)(1)(iv)(B)(1) of this
section are not met then the group of low mass emission units is not
considered an identical group of units and individual appendix E testing
of each unit is required.
(5) Fuel and unit specific NOX emission rates determined
according to paragraphs (c)(1)(iv)(F) and (c)(1)(iv)(G) of this section
may be used in lieu of appendix E testing for one or more low mass
emission units in a group of identical units.
(C) Based on the results of the part 75 appendix E testing,
determine the fuel-and-unit-specific NOX emission rate as
follows:
(1) Except for LME units that use selective catalytic reduction
(SCR) or selective non-catalytic reduction (SNCR) to control
NOX emissions, the highest three-run average NOX
emission rate obtained at any load in the appendix E test for a
particular type of fuel shall
[[Page 232]]
be the fuel-and-unit-specific NOX emission rate, for that
type of fuel.
(2) [Reserved]
(3) For a group of identical low mass emissions units (except for
units that use SCR or SNCR to control NOX emissions), the
fuel-and-unit-specific NOX emission rate for all units in the
group, for a particular type of fuel, shall be the highest three-run
average NOX emission rate obtained at any tested load from
any unit tested in the group, for that type of fuel.
(4) Except as provided in paragraphs (c)(1)(iv)(C)(7) and
(c)(1)(iv)(C)(8) of this section, for an individual low mass emissions
unit which uses SCR or SNCR to control NOX emissions, the
fuel-and-unit-specific NOX emission rate for each type of
fuel combusted in the unit shall be the higher of:
(i) The highest three-run average emission rate from any load of the
appendix E test for that type of fuel; or
(ii) 0.15 lb/mmBtu.
(5) [Reserved]
(6) Except as provided in paragraphs (c)(1)(iv)(C)(7) and
(c)(1)(iv)(C)(8) of this section, for a group of identical low mass
emissions units that are all equipped with SCR or SNCR to control
NOX emissions, the fuel-and-unit-specific NOX
emission rate for each unit in the group of units, for a particular type
of fuel, shall be the higher of:
(i) The highest three-run average NOX emission rate at
any load from all appendix E tests of all tested units in the group, for
that type of fuel; or
(ii) 0.15 lb/mmBtu.
(7) Notwithstanding the requirements of paragraphs (c)(1)(iv)(C)(4)
and (c)(1)(iv)(C)(6) of this section, for a unit (or group of identical
units) equipped with SCR (or SNCR) and water (or steam) injection to
control NOX emissions:
(i) If the appendix E testing is performed when the water (or steam
) injection is in use and either upstream of the SCR or SNCR or during a
time period when the SCR or SNCR is out of service; then
(ii) The highest three-run average emission rate from the appendix E
testing may be used as the fuel-and-unit-specific NOX
emission rate for the unit (or, if applicable, for each unit in the
group), for each unit operating hour in which the water-to-fuel ratio is
within the acceptable range established during the appendix E testing.
(8) Notwithstanding the requirements of paragraphs (c)(1)(iv)(C)(4)
and (c)(1)(iv)(C)(6) of this section, for a unit (or group of identical
units) equipped with SCR (or SNCR) and uses dry low-NOX
technology to control NOX emissions:
(i) If the appendix E testing is performed during a time period when
the dry low-NOX controls are in use, but the SCR or SNCR is
out of service; then
(ii) The highest three-run average emission rate from the appendix E
testing may be used as the fuel-and-unit-specific NOX
emission rate for the unit (or, if applicable, for each unit in the
group), for each unit operating hour in which the parametric data
described in paragraph (c)(1)(iv)(H)(2) of this section demonstrate that
the dry low-NOX controls are operating in the premixed or
low-NOX mode.
(9) For an individual combustion turbine (or a group of identical
turbines) that operate principally at base load (or at a set point
temperature), but are capable of operating at a higher peak load (or
higher internal operating temperature), the fuel-and-unit-specific
NOX emission rate for the unit (or for each unit in the
group) shall be as follows:
(i) If the testing is done only at base load, use the three-run
average NOX emission rate for base load operating hours and
1.15 times that emission rate for peak load operating hours; or
(ii) If the testing is done at both base load and peak load, use the
three-run average NOX emission rate from the base load
testing for base load operating hours and the three-run average
NOX emission rate from the peak load testing for peak load
operating hours.
(D) For each low mass emissions unit, or group of identical units
for which the provisions of paragraph (c)(1)(iv) of this section are
used to account for NOX emission rate, the owner or operator
shall determine a new fuel-and-unit-specific NOX emission
rate every five years (20 calendar quarters), unless changes in the fuel
supply, physical changes to the unit, changes in the manner of unit
operation, or changes
[[Page 233]]
to the emission controls occur which may cause a significant increase in
the unit's actual NOX emission rate. If such changes occur,
the fuel-and-unit-specific NOX emission rate(s) shall be re-
determined according to paragraph (c)(1)(iv) of this section. Testing
shall be done at the number of loads specified in paragraph
(c)(1)(iv)(A) or (c)(1)(iv)(I) of this section, as applicable. If a low
mass emissions unit belongs to a group of identical units and it is
required to retest to determine a new fuel-and-unit-specific
NOX emission rate because of changes in the fuel supply,
physical changes to the unit, changes in the manner of unit operation or
changes to the emission controls occur which may cause a significant
increase in the unit's actual NOX emission rate, any other
unit in that group of identical units is not required to re-determine
the fuel-and-unit-specific NOX emission rate unless such unit
also undergoes changes in the fuel supply, physical changes to the unit,
changes in the manner of unit operation or changes to the emission
controls occur which may cause a significant increase in the unit's
actual NOX emission rates.
(E) Each low mass emissions unit or each low mass emissions unit in
a group of identical units for which a fuel-and-unit-specific
NOX emission rate(s) are determined shall meet the quality
assurance and quality control provisions of paragraph (e) of this
section.
(F) Low mass emission units may use the results of appendix E
testing, if such test results are available from a test conducted no
more than five years prior to the time of initial certification, to
determine the appropriate fuel-and-unit-specific NOX emission
rate(s). However, fuel-and-unit-specific NOX emission rates
from historical testing may not be used longer than five years after the
appendix E testing was conducted.
(G) Low mass emissions units for which at least 3 years of quality-
assured NOX emission rate data from a NOX-diluent
CEMS and corresponding fuel usage data are available may determine fuel-
and-unit-specific NOX emission rates from the actual data
using the following procedure. Separate the actual NOX
emission rate data into groups, according to the type of fuel combusted.
Discard data from periods when multiple fuels were combusted. Each fuel-
specific data set must contain at least 168 hours of data and must
represent all normal operating ranges of the unit when combusting the
fuel. Sort the data in each fuel-specific data set in ascending order
according to NOX emission rate. Determine the 95th percentile
NOX emission rate for each data set as defined in Sec. 72.2
of this chapter. Use the 95th percentile value for each data set as the
fuel-and-unit-specific NOX emission rate, except that for a
unit that uses SCR or SNCR for NOX emission control, if the
95th percentile value is less than 0.15 lb/mmBtu, a value of 0.15 lb/
mmBtu shall be used as the fuel-and-unit-specific NOX
emission rate.
(H) For low mass emission units with add-on NOX emission
controls, and for units that use dry low-NOX technology, the
owner or operator shall, during every hour of unit operation during the
test period, monitor and record parameters, as required under paragraph
(e)(5) of this section, which indicate that the NOX emission
controls are operating properly. After the test period, these same
parameters shall be monitored and recorded and kept for all operating
hours in order to determine whether the NOX controls are
operating properly and to allow the determination of the correct
NOX emission rate as required under paragraph (c)(1)(iv) of
this section.
(1) For low mass emission units with steam or water injection, the
steam-to-fuel or water-to-fuel ratio used during the testing must be
documented. The water-to-fuel or steam-to-fuel ratio must be maintained
during unit operations for a unit to use the fuel and unit specific
NOX emission rate determined during the test. Owners or
operators must include in the monitoring plan the acceptable range of
the water-to-fuel or steam-to-fuel ratio, which will be used to indicate
hourly, proper operation of the NOX controls for each unit.
The water-to-fuel or steam-to-fuel ratio shall be monitored and recorded
during each hour of unit operation. If the water-to-fuel or steam-to-
fuel ratio is not within the acceptable
[[Page 234]]
range in a given hour the fuel and unit specific NOX emission
rate may not be used for that hour, and the appropriate default
NOX emission rate from Table LM-2 shall be reported instead.
(2) For a low mass emissions unit that uses dry low-NOX
premix technology to control NOX emissions, proper operation
of the emission controls means that the unit is in the low-
NOX or premixed combustion mode, and fired with natural gas.
Evidence of operation in the low-NOX or premixed mode shall
be provided by monitoring the appropriate turbine operating parameters.
These parameters may include percentage of full load, turbine exhaust
temperature, combustion reference temperature, compressor discharge
pressure, fuel and air valve positions, dynamic pressure pulsations,
internal guide vane (IGV) position, and flame detection or flame scanner
condition. The acceptable values and ranges for all parameters monitored
shall be specified in the monitoring plan for the unit, and the
parameters shall be monitored during each subsequent operating hour. If
one or more of these parameters is not within the acceptable range or at
an acceptable value in a given operating hour, the fuel-and-unit-
specific NOX emission rate may not be used for that hour, and
the appropriate default NOX emission rate from Table LM-2
shall be reported instead. When the unit is fired with oil the
appropriate default value from Table LM-2 shall be reported.
(3) For low mass emission units with other types of add-on
NOX controls, appropriate parameters and the acceptable range
of the parameters which indicate hourly proper operation of the
NOX controls must be specified in the monitoring plan. These
parameters shall be monitored during each subsequent operating hour. If
any of these parameters are not within the acceptable range in a given
operating hour, the fuel and unit specific NOX emission rates
may not be used in that hour, and the appropriate default NOX
emission rate from Table LM-2 shall be reported instead.
(I) Notwithstanding the requirements in paragraph (c)(1)(iv)(A) of
this section, the appendix E testing to determine (or re-determine) the
fuel-specific, unit-specific NOX emission rate for a unit (or
for each unit in a group of identical units) may be performed at fewer
than four loads, under the following circumstances:
(1) Testing may be done at one load level if the data analysis
described in paragraph (c)(1)(iv)(J) of this section is performed and
the results show that the unit has operated (or all units in the group
of identical units have operated) at a single load level for at least
85.0 percent of all operating hours in the previous three years (12
calendar quarters) prior to the calendar quarter of the appendix E
testing. For combustion turbines that are operated to produce
approximately constant output (in MW) but which use internal operating
and exhaust temperatures and not the actual output in MW to control the
operation of the turbine, the internal operating temperature set point
may be used as a surrogate for load in demonstrating that the unit
qualifies for single-load testing. If the data analysis shows that the
unit does not qualify for single-load testing, testing may be done at
two (or three) load levels if the unit has operated (or if all units in
the group of identical units have operated) cumulatively at two (or
three) load levels for at least 85.0 percent of all operating hours in
the previous three years; or
(2) If a multiple-load appendix E test was initially performed for a
unit (or group of identical units) to determine the fuel-and-unit
specific NOX emission rate, then the periodic retests
required under paragraph (c)(1)(iv)(D) of this section may be single-
load tests, performed at the load level for which the highest average
NOX emission rate was obtained in the initial test.
(J) To determine whether a unit qualifies for testing at fewer than
four loads under paragraph (c)(1)(iv)(I) of this section, follow the
procedures in paragraph (c)(1)(iv)(J)(1) or (c)(1)(iv)(J)(2) of this
section, as applicable.
(1) Determine the range of operation of the unit, according to
section 6.5.2.1 of appendix A to this part. Divide the range of
operation into four equal load bands. For example, if the range of
operation extends from 20 MW to 100 MW, the four equal load bands would
be:
[[Page 235]]
band 1: from 20 MW to 40 MW; band 2: from 41 MW to 60
MW; band 3: from 61 MW to 80 MW; and band 4: from 81
to 100 MW. Then, perform a historical load analysis for all unit
operating hours in the 12 calendar quarters preceding the quarter of the
test. Alternatively, for sources that report emissions data only during
the ozone season, the historical load analysis may be based on unit
operation in the previous three ozone seasons, rather than unit
operation in the previous 12 calendar quarters. Determine the percentage
of the data that fall into each load band. For a unit that is not part
of a group of identical units, if 85.0% or more of the data fall into
one load band, single-load testing may be performed at any point within
that load band. For a group of identical units, if each unit in the
group meets the 85.0% criterion, then representative single-load testing
within the load band may be performed. If the 85.0% criterion cannot be
met to qualify for single-load testing but this criterion can be met
cumulatively for two (or three) load levels, then testing may be
performed at two (or three) loads instead of four.
(2) For a combustion turbine that uses exhaust temperature and not
the actual output in megawatts to control the operation of the turbine
(or for a group of identical units of this type), the owner or operator
must document that the unit (or each unit in the group) has operated
within 10% of the set point temperature for 85.0% of the
operating hours in the previous 12 calendar quarters to qualify for
single-load testing. Alternatively, for sources that report emissions
data only during the ozone season, the historical set point temperature
analysis may be based on unit operation in the previous three ozone
seasons, rather than unit operation in the previous 12 calendar
quarters. When the set point temperature is used rather than unit load
to justify single-load testing, the designated representative shall
certify in the monitoring plan for the unit that this is the normal
manner of unit operation and shall document the setpoint temperature.
(2) Records of operating time, fuel usage, unit output and
NOX emission control operating status. The owner or operator
shall keep the following records on-site, for three years, in a form
suitable for inspection, except that for unmanned facilities, the
records may be kept at a central location, rather than on-site:
(i) For each low mass emissions unit, the owner or operator shall
keep hourly records which indicate whether or not the unit operated
during each clock hour of each calendar year. The owner or operator may
report partial operating hours or may assume that for each hour the unit
operated the operating time is a whole hour. Units using partial
operating hours and the maximum rated hourly heat input to calculate
heat input for each hour must report partial operating hours.
(ii) For each low mass emissions unit, the owner or operator shall
keep hourly records indicating the type(s) of fuel(s) combusted in the
unit during each hour of unit operation.
(iii) For each low mass emissions unit using the long term fuel flow
methodology under paragraph (c)(3)(ii) of this section to determine
hourly heat input, the owner or operator shall keep hourly records of
unit load (in megawatts or thousands of pounds of steam per hour), for
the purpose of apportioning heat input to the individual unit operating
hours.
(iv) For each low mass emissions unit with add-on NOX
emission controls of any kind and each unit that uses dry low-
NOX technology, the owner or operator shall keep hourly
records of the hourly value of the parameter(s) specified in
(c)(1)(iv)(H) of this section used to indicate proper operation of the
unit's NOX controls.
(3) Heat input. Hourly, quarterly and annual heat input for a low
mass emissions unit shall be determined using either the maximum rated
hourly heat input method under paragraph (c)(3)(i) of this section or
the long term fuel flow method under paragraph (c)(3)(ii) of this
section.
(i) Maximum rated hourly heat input method. (A) For the purposes of
the mass emission calculation methodology of paragraph (c)(3) of this
section, HIhr, the hourly heat input (mmBtu) to a low mass
emissions unit shall be deemed to equal the maximum
[[Page 236]]
rated hourly heat input, as defined in Sec. 72.2 of this chapter,
multiplied by the operating time of the unit for each hour. The owner or
operator may choose to record and report partial operating hours or may
assume that a unit operated for a whole hour for each hour the unit
operated. However, the owner or operator of a unit may petition the
Administrator under Sec. 75.66 for a lower value for maximum rated
hourly heat input than that defined in Sec. 72.2 of this chapter. The
Administrator may approve such lower value if the owner or operator
demonstrates that either the maximum hourly heat input specified by the
manufacturer or the highest observed hourly heat input, or both, are not
representative, and such a lower value is representative, of the unit's
current capabilities because modifications have been made to the unit,
limiting its capacity permanently.
(B) The quarterly heat input, HIqtr, in mmBtu, shall be
determined using Equation LM-1:
[GRAPHIC] [TIFF OMITTED] TR12JN02.001
Where:
n = Number of unit operating hours in the quarter.
HIhr = Hourly heat input under paragraph (c)(3)(i)(A) of this
section (mmBtu).
(C) The year-to-date cumulative heat input (mmBtu) shall be the sum
of the quarterly heat input values for all of the calendar quarters in
the year to date.
(D) For a unit subject to the provisions of subpart H of this part,
which is not required to report emission data on a year-round basis and
elects to report only during the ozone season, the quarterly heat input
for the second calendar quarter of the year shall, for compliance
purposes, include only the heat input for the months of May and June,
and the cumulative ozone season heat input shall be the sum of the heat
input values for May, June and the third calendar quarter of the year.
(ii) Long term fuel flow heat input method. The owner or operator
may, for the purpose of demonstrating that a low mass emissions unit or
group of low mass emission units sharing a common fuel supply meets the
requirements of this section, use records of long-term fuel flow, to
calculate hourly heat input to a low mass emissions unit.
(A) This option may be used for a group of low mass emission units
only if:
(1) The low mass emission units combust fuel from a common source of
supply; and
(2) Records are kept of the total amount of fuel combusted by the
group of low mass emission units and the hourly output (in megawatts or
pounds of steam) from each unit in the group; and
(3) All of the units in the group are low mass emission units.
(B) For each fuel used during the quarter, the volume in standard
cubic feet (for gas) or gallons (for oil) may be determined using any of
the following methods;
(1) Fuel billing records (for low mass emission units, or groups of
low mass emission units, which purchase fuel from non-affiliated
sources);
(2) American Petroleum Institute (API) standard, American Petroleum
Institute (API) Petroleum Measurement Standards, Chapter 3, Tank
Gauging: Section 1A, Standard Practice for the Manual Gauging of
Petroleum and Petroleum Products, December 1994; Section 1B, Standard
Practice for Level Measurement of Liquid Hydrocarbons in Stationary
Tanks by Automatic Tank Gauging, April 1992 (reaffirmed January 1997);
Section 2, Standard Practice for Gauging Petroleum and Petroleum
Products in Tank Cars, September 1995; Section 3, Standard Practice for
Level Measurement of Liquid Hydrocarbons in Stationary Pressurized
Storage Tanks by Automatic Tank Gauging, June 1996; Section 4, Standard
Practice for Level Measurement of Liquid Hydrocarbons on Marine Vessels
by Automatic Tank Gauging, April 1995; and Section 5, Standard Practice
for Level Measurement of Light Hydrocarbon Liquids Onboard Marine
Vessels by Automatic Tank Gauging, March 1997; Shop Testing of Automatic
Liquid Level Gages,
[[Page 237]]
Bulletin 2509 B, December 1961 (Reaffirmed August 1987, October 1992)
(incorporated by reference under Sec. 75.6); or;
(3) A fuel flow meter certified and maintained according to appendix
D to this part.
(C) Except as provided in paragraph (c)(3)(ii)(C)(3) of this
section, for each fuel combusted during a quarter, the gross calorific
value of the fuel shall be determined by either:
(1) Using the applicable procedures for gas and oil analysis in
sections 2.2 and 2.3 of appendix D to this part. If this option is
chosen the highest gross calorific value recorded during the previous
calendar year shall be used (or, for a new or newly-affected unit, if
there are no sample results from the previous year, use the highest GCV
from the samples taken in the current year); or
(2) Using the appropriate default gross calorific value listed in
Table LM-5 of this section.
(3) For gaseous fuels other than pipeline natural gas or natural
gas, the GCV sampling frequency shall be daily unless the results of a
demonstration under section 2.3.5 of appendix D to this part show that
the fuel has a low GCV variability and qualifies for monthly sampling.
If daily GCV sampling is required, use the highest GCV obtained in the
calendar quarter as GCVmax in Equation LM-3, of this section.
(D) If Eq. LM-2 is used for heat input determination, the specific
gravity of each type of fuel oil combusted during the quarter shall be
determined either by:
(1) Using the procedures in section 2.2.6 of appendix D to this
part. If this option is chosen, use the highest specific gravity value
recorded during the previous calendar year (or, for a new or newly-
affected unit, if there are no sample results from the previous year,
use the highest specific gravity from the samples taken in the current
year); or
(2) Using the appropriate default specific gravity value in Table
LM-6 of this section.
(E) The quarterly heat input from each type of fuel combusted during
the quarter by a low mass emissions unit or group of low mass emissions
units sharing a common fuel supply shall be determined using either
Equation LM-2 or Equation LM-3 for oil (as applicable to the method used
to quantify oil usage) and Equation LM-3 for gaseous fuels. For a unit
subject to the provisions of subpart H of this part, which is not
required to report emission data on a year-round basis and elects to
report only during the ozone season, the quarterly heat input for the
second calendar quarter of the year shall include only the heat input
for the months of May and June.
[GRAPHIC] [TIFF OMITTED] TR12JN02.002
Where:
HIfuel-qtr = Quarterly total heat input from oil (mmBtu).
Mqtr = Mass of oil consumed during the quarter, determined as
the product of the volume of oil under paragraph (c)(3)(ii)(B) of this
section and the specific gravity under paragraph (c)(3)(ii)(D) of this
section (lb).
GCVmax = Gross calorific value of oil, as determined under
paragraph (c)(3)(ii)(C) of this section (Btu/lb)
10\6\ = Conversion of Btu to mmBtu.
[GRAPHIC] [TIFF OMITTED] TR12JN02.003
[[Page 238]]
Where:
HIfuel-qtr = Quarterly heat input from gaseous fuel or fuel
oil (mmBtu).
Qqtr = Volume of gaseous fuel or fuel oil combusted during
the quarter, as determined under paragraph (c)(3)(ii)(B) of this section
standard cubic feet (scf) or (gal), as applicable.
GCVmax = Gross calorific value of the gaseous fuel or fuel
oil combusted during the quarter, as determined under paragraph
(c)(3)(ii)(C) of this section (Btu/scf) or (Btu/gal), as applicable.
10\6\ = Conversion of Btu to mmBtu.
(F) Use Eq. LM-4 to calculate HIqtr-total, the quarterly
heat input (mmBtu) for all fuels. HIqtr-total shall be the
sum of the HIfuel-qtr values determined using Equations LM-2
and LM-3.
[GRAPHIC] [TIFF OMITTED] TR12JN02.004
(G) The year-to-date cumulative heat input (mmBtu) for all fuels
shall be the sum of all quarterly total heat input
(HIqtr-total) values for all calendar quarters in the year to
date. For a unit subject to the provisions of subpart H of this part,
which is not required to report emission data on a year-round basis and
elects to report only during the ozone season, the cumulative ozone
season heat input shall be the sum of the quarterly heat input values
for the second and third calendar quarters of the year.
(H) For each low mass emissions unit or each low mass emissions unit
in a group of identical units, the owner or operator shall determine the
cumulative quarterly unit load in megawatts or thousands of pounds of
steam per hour. The quarterly cumulative unit load shall be the sum of
the hourly unit load values recorded under paragraph (c)(2) of this
section and shall be determined using Equations LM-5 or LM-6. For a unit
subject to the provisions of subpart H of this part, which is not
required to report emission data on a year-round basis and elects to
report only during the ozone season, the quarterly cumulative load for
the second calendar quarter of the year shall include only the unit
loads for the months of May and June.
[GRAPHIC] [TIFF OMITTED] TR12JN02.005
[GRAPHIC] [TIFF OMITTED] TR12JN02.006
Where:
MWqtr =Sum of all unit operating loads recorded during the
quarter by the unit (MW).
STfuel-qtr = Sum of all hourly steam loads recorded during
the quarter by the unit (klb of steam/hr).
MW = Unit operating load for a particular unit operating hour (MW).
ST = Unit steam load for a particular unit operating hour (klb of steam/
hr).
(I) For a low mass emissions unit that is not included in a group of
low mass emission units sharing a common fuel supply, apportion the
total heat input for the quarter, HIqtr-total to each hour of
unit operation using either Equation LM-7 or LM-8:
[GRAPHIC] [TIFF OMITTED] TR27OC98.006
(Eq LM-7 for MW output)
[GRAPHIC] [TIFF OMITTED] TR27OC98.007
(Eq LM-8 for steam output)
Where:
HIhr = Hourly heat input to the unit (mmBtu).
MWhr = Hourly operating load for the unit (MW).
[[Page 239]]
SThr = Hourly steam load for the unit (klb of steam/hr).
(J) For each low mass emissions unit that is included in a group of
units sharing a common fuel supply, apportion the total heat input for
the quarter, HIqtr-total to each hour of operation using
either Equation LM-7a or LM-8a:
[GRAPHIC] [TIFF OMITTED] TR27OC98.008
(Eq LM-7a for MW output)
[GRAPHIC] [TIFF OMITTED] TR27OC98.009
(Eq LM-8a for steam output)
Where:
HIhr = Hourly heat input to the individual unit (mmBtu).
MWhr = Hourly operating load for the individual unit (MW).
SThr = Hourly steam load for the individual unit (klb of
steam/hr).
[Sigma]MWqtr = Sum of the quarterly operating
all-units loads (from Eq. LM-5) for all units in the group (MW).
[Sigma]STqtr = Sum of the quarterly steam
all-units loads (from Eq. LM-6) for all units in the group (klb of
steam/hr)
(4) Calculation of SO2, NOX and CO2
mass emissions. The owner or operator shall, for the purpose of
demonstrating that a low mass emissions unit meets the requirements of
this section, calculate SO2, NOX and
CO2 mass emissions in accordance with the following.
(i) SO2 mass emissions. (A) The hourly SO2
mass emissions (lbs) for a low mass emissions unit (Acid Rain Program
units, only) shall be determined using Equation LM-9 and the appropriate
fuel-based SO2 emission factor from Table LM-1 of this
section for the fuels combusted in that hour. If more than one fuel is
combusted in the hour, use the highest emission factor for all of the
fuels combusted in the hour. If records are missing as to which fuel was
combusted in the hour, use the highest emission factor for all of the
fuels capable of being combusted in the unit.
WSO2 = EFSO2 x HIhr (Eq. LM-9)
Where:
WSO2 = Hourly SO2 mass emissions (lbs.)
EFSO2 = Either the SO2 emission factor from Table
LM-1 of this section or the fuel-and-unit-specific SO2
emission rate from paragraph (c)(1)(i) of this section (lb/mmBtu).
HIhr = Either the maximum rated hourly heat input under
paragraph (c)(3)(i)(A) of this section or the hourly heat input under
paragraph (c)(3)(ii) of this section (mmBtu).
(B) The quarterly SO2 mass emissions (tons) for the low
mass emissions unit shall be the sum of all the hourly SO2
mass emissions in the quarter, as determined under paragraph
(c)(4)(i)(A) of this section, divided by 2000 lb/ton.
(C) The year-to-date cumulative SO2 mass emissions (tons)
for the low mass emissions unit shall be the sum of the quarterly
SO2 mass emissions, as determined under paragraph
(c)(4)(i)(B) of this section, for all of the calendar quarters in the
year to date.
(ii) NOX mass emissions. (A) The hourly NOX
mass emissions for the low mass emissions unit (lbs) shall be determined
using Equation LM-10. If more than one fuel is combusted in the hour,
use the highest emission rate for all of the fuels combusted in the
hour. If records are missing as to which fuel was combusted in the hour,
use the highest emission factor for all of the fuels capable of being
combusted in the unit. For low mass emission units with NOX
emission controls of any kind and for which a fuel-and-unit-specific
NOX emission rate is determined under paragraph (c)(1)(iv) of
this section, for any hour in which the parameters under paragraph
(c)(1)(iv)(A) of this section do not show that the NOX
emission controls are operating properly, use the NOX
emission rate from Table LM-2 of this section for the fuel combusted
during the hour with the highest NOX emission rate.
WNOX = EFNOX x HIhr (Eq. LM-10)
Where:
WNOX = Hourly NOX mass emissions (lbs).
EFNOX = Either the NOX emission factor from Table
LM-2 of this section or the fuel- and unit-specific NOX
emission rate determined under paragraph (c)(1)(iv) of this section (lb/
mmBtu).
HIhr = Either the maximum rated hourly heat input from
paragraph (c)(3)(i)(A) of this section or the hourly heat input as
determined under paragraph(c)(3)(ii) of this section (mmBtu).
[[Page 240]]
(B) The quarterly NOX mass emissions (tons) for the low
mass emissions unit shall be the sum of all of the hourly NOX
mass emissions in the quarter, as determined under paragraph
(c)(4)(ii)(A) of this section, divided by 2000 lb/ton.
(C) The year-to-date cumulative NOX mass emissions (tons)
for the low mass emissions unit shall be the sum of the quarterly
NOX mass emissions, as determined under paragraph
(c)(4)(ii)(B) of this section, for all of the calendar quarters in the
year to date. For a unit subject to the provisions of subpart H of this
part, which is not required to report emission data on a year-round
basis and elects to report only during the ozone season, the ozone
season NOX mass emissions for the unit shall be the sum of
the quarterly NOX mass emissions, as determined under
paragraph (c)(4)(ii)(B) of this section, for the second and third
calendar quarters of the year, and the second quarter report shall
include emissions data only for May and June.
(iii) CO2 Mass Emissions. (A) The hourly CO2
mass emissions (tons) for the affected low mass emissions unit (Acid
Rain Program units, only) shall be determined using Equation LM-11 and
the appropriate fuel-based CO2 emission factor from Table LM-
3 of this section for the fuel being combusted in that hour. If more
than one fuel is combusted in the hour, use the highest emission factor
for all of the fuels combusted in the hour. If records are missing as to
which fuel was combusted in the hour, use the highest emission factor
for all of the fuels capable of being combusted in the unit.
WCO2 = EFCO2 x HIhr (Eq. LM-11)
Where:
WCO2 = Hourly CO2 mass emissions (tons).
EFCO2 = Either the fuel-based CO2 emission factor
from Table LM-3 of this section or the fuel-and-unit-specific
CO2 emission rate from paragraph (c)(1)(iii) of this section
(tons/mmBtu).
HIhr = Either the maximum rated hourly heat input from
paragraph (c)(3)(i)(A) of this section or the hourly heat input as
determined under paragraph (c)(3)(ii) of this section (mmBtu).
(B) The quarterly CO2 mass emissions (tons) for the low
mass emissions unit shall be the sum of all of the hourly CO2
mass emissions in the quarter, as determined under paragraph
(c)(4)(iii)(A)of this section.
(C) The year-to-date cumulative CO2 mass emissions (tons)
for the low mass emissions unit shall be the sum of all of the quarterly
CO2 mass emissions, as determined under paragraph
(c)(4)(iii)(B) of this section, for all of the calendar quarters in the
year to date.
(d) Each unit that qualifies under this section to use the low mass
emissions methodology must follow the recordkeeping and reporting
requirements pertaining to low mass emissions units in subparts F and G
of this part.
(e) The quality control and quality assurance requirements in
Sec. 75.21 are not applicable to a low mass emissions unit for which the
low mass emissions excepted methodology under paragraph (c) of this
section is being used in lieu of a continuous emission monitoring system
or an excepted monitoring system under appendix D or E to this part,
except for fuel flowmeters used to meet the provisions in paragraph
(c)(3)(ii) of this section. However, the owner or operator of a low mass
emissions unit shall implement the following quality assurance and
quality control provisions:
(1) For low mass emission units or groups of units which use the
long term fuel flow methodology under paragraph (c)(3)(ii) of this
section and which use fuel billing records to determine fuel usage, the
owner or operator shall keep, at the facility, for three years, the
records of the fuel billing statements used for long term fuel flow
determinations.
(2) For low mass emissions units or groups of units which use the
long term fuel flow methodology under paragraph (c)(3)(ii) of this
section and which use one of the methods specified in paragraph
(c)(3)(ii)(B)(2) of this section to determine fuel usage, the owner or
operator shall keep, at the facility, a copy of the standard used and
shall keep records, for three years, of all measurements obtained for
each quarter using the methodology.
(3) For low mass emission units or groups of units which use the
long term fuel flow methodology under paragraph (c)(3)(ii) of this
section and
[[Page 241]]
which use a certified fuel flow meter to determine fuel usage, the owner
or operator shall comply with the quality control quality assurance
requirements for a fuel flow meter under section 2.1.6 of appendix D of
this part.
(4) For each low mass emissions unit for which fuel-and-unit-
specific NOX emission rates are determined in accordance with
paragraph (c)(1)(iv) of this section, the owner or operator shall keep,
at the facility, records which document the results of all
NOX emission rate tests conducted according to appendix E to
this part. If CEMS data are used to determine the fuel-and-unit-specific
NOX emission rates under paragraph (c)(1)(iv)(G) of this
section, the owner or operator shall keep, at the facility, records of
the CEMS data and the data analysis performed to determine a fuel-and-
unit-specific NOX emission rate. The appendix E test records
and historical CEMS data records shall be kept until the fuel and unit
specific NOX emission rates are re-determined.
(5) For each low mass emissions unit for which fuel-and-unit-
specific NOX emission rates are determined in accordance with
paragraph (c)(1)(iv) of this section and which has add-on NOX
emission controls of any kind or uses dry low-NOX technology,
the owner or operator shall develop and keep on-site a quality assurance
plan which explains the procedures used to document proper operation of
the NOX emission controls. The plan shall include the
parameters monitored (e.g., water-to-fuel ratio) and the acceptable
ranges for each parameter used to determine proper operation of the
unit's NOX controls.
(6) For unmanned facilities, the records required by paragraphs
(e)(1), (e)(2) and (e)(4) of this section may be kept at a central
location, rather than at the facility.
Table LM-1--SO2 Emission Factors (lb/mmBtu) for Various Fuel Types
------------------------------------------------------------------------
Fuel type SO2 emission factors
------------------------------------------------------------------------
Pipeline Natural Gas...................... 0.0006 lb/mmBtu.
Other Natural Gas......................... 0.06 lb/mmBtu.
Residual Oil.............................. 2.1 lb/mmBtu.
Diesel Fuel............................... 0.5 lb/mmBtu.
------------------------------------------------------------------------
Table LM-2--NOX Emission Rates (lb/mmBtu) for Various Boiler/Fuel Types
------------------------------------------------------------------------
NOX
Unit type Fuel type emission
rate
------------------------------------------------------------------------
Turbine................................ Gas................. 0.7
Turbine................................ Oil................. 1.2
Boiler................................. Gas................. 1.5
Boiler................................. Oil................. 2
------------------------------------------------------------------------
Table LM-3--CO2 Emission Factors (ton/mmBtu) for Gas and Oil
------------------------------------------------------------------------
Fuel type CO2 emission factors
------------------------------------------------------------------------
Pipeline (or other) Natural Gas........... 0.059 ton/mmBtu.
Oil....................................... 0.081 ton/mmBtu.
------------------------------------------------------------------------
Table LM-4--Identical Unit Testing Requirements
------------------------------------------------------------------------
Number of appendix E tests
Number of identical units in the group required
------------------------------------------------------------------------
2......................................... 1
3 to 6.................................... 2
7......................................... 3
7............................. n tests; wheren n = number
of units divided by 3 and
rounded to nearest integer.
------------------------------------------------------------------------
Table LM-5--Default Gross Calorific Values (GCVs) for Various Fuels
------------------------------------------------------------------------
GCV for use in equation LM-2
Fuel or LM-3
------------------------------------------------------------------------
Pipeline Natural Gas...................... 1050 Btu/scf.
Other Natural Gas......................... 1100 Btu/scf.
Residual Oil.............................. 19,700 Btu/lb or 167,500 Btu/
gallon.
Diesel Fuel............................... 20,500 Btu/lb or 151,700 Btu/
gallon.
------------------------------------------------------------------------
Table LM-6--Default Specific Gravity Values for Fuel Oil
------------------------------------------------------------------------
Specific
Fuel gravity
(lb/gal)
------------------------------------------------------------------------
Residual Oil................................................ 8.5
Diesel Fuel................................................. 7.4
------------------------------------------------------------------------
[[Page 242]]
[63 FR 57500, Oct. 27, 1998, as amended at 64 FR 28592, May 26, 1999; 64
FR 37582, July 12, 1999; 67 FR 40424, 40425, June 12, 2002; 67 FR 53504,
Aug. 16, 2002]