[Title 40 CFR 60.48Da]
[Code of Federal Regulations (annual edition) - July 1, 2009 Edition]
[Title 40 - PROTECTION OF ENVIRONMENT]
[Chapter I - ENVIRONMENTAL PROTECTION AGENCY (CONTINUED)]
[Subchapter C - AIR PROGRAMS (CONTINUED)]
[Part 60 - STANDARDS OF PERFORMANCE FOR NEW STATIONARY SOURCES--]
[Subpart Da - Standards of Performance for Electric Utility Steam]
[Sec. 60.48da - Compliance provisions.]
[From the U.S. Government Printing Office]


40PROTECTION OF ENVIRONMENT62009-07-012009-07-01false60.48DaSec. 60.48DaPROTECTION OF ENVIRONMENTENVIRONMENTAL PROTECTION AGENCY (CONTINUED)AIR PROGRAMS (CONTINUED)STANDARDS OF PERFORMANCE FOR NEW STATIONARY SOURCES--Standards of Performance for Electric Utility Steam
Sec. 60.48Da  Compliance provisions.

    (a) Compliance with the PM emission limitation under Sec. 
60.42Da(a)(1) constitutes compliance with the percent reduction 
requirements for PM under Sec. 60.42Da(a)(2) and (3).
    (b) Compliance with the NOX emission limitation under 
Sec. 60.44Da(a)(1) constitutes compliance with the percent reduction 
requirements under Sec. 60.44Da(a)(2).
    (c) The PM emission standards under Sec. 60.42Da, the 
NOX emission standards under Sec. 60.44Da, and the Hg 
emission standards under Sec. 60.45Da apply at all times except during 
periods of startup, shutdown, or malfunction.
    (d) During emergency conditions in the principal company, an 
affected facility with a malfunctioning flue gas desulfurization system 
may be operated if SO2 emissions are minimized by:
    (1) Operating all operable flue gas desulfurization system modules, 
and bringing back into operation any malfunctioned module as soon as 
repairs are completed,
    (2) Bypassing flue gases around only those flue gas desulfurization 
system modules that have been taken out of operation because they were 
incapable of any SO2 emission reduction or which would have 
suffered significant physical damage if they had remained in operation, 
and
    (3) Designing, constructing, and operating a spare flue gas 
desulfurization system module for an affected facility larger than 365 
MW (1,250 MMBtu/hr) heat input (approximately 125 MW electrical output 
capacity). The Administrator may at his discretion require the owner or 
operator within 60 days of notification to demonstrate spare module 
capability. To demonstrate this capability, the owner or operator must 
demonstrate compliance with the appropriate requirements under paragraph 
under Sec. 60.43Da(a), (b), (d), (e), and (h) for any period of 
operation lasting from 24 hours to 30 days when:
    (i) Any one flue gas desulfurization module is not operated,
    (ii) The affected facility is operating at the maximum heat input 
rate,
    (iii) The fuel fired during the 24-hour to 30-day period is 
representative of the type and average sulfur content of fuel used over 
a typical 30-day period, and
    (iv) The owner or operator has given the Administrator at least 30 
days notice of the date and period of time over which the demonstration 
will be performed.

[[Page 162]]

    (e) After the initial performance test required under Sec. 60.8, 
compliance with the SO2 emission limitations and percentage 
reduction requirements under Sec. 60.43Da and the NOX 
emission limitations under Sec. 60.44Da is based on the average 
emission rate for 30 successive boiler operating days. A separate 
performance test is completed at the end of each boiler operating day 
after the initial performance test, and a new 30 day average emission 
rate for both SO2 and NOX and a new percent 
reduction for SO2 are calculated to show compliance with the 
standards.
    (f) For the initial performance test required under Sec. 60.8, 
compliance with the SO2 emission limitations and percent 
reduction requirements under Sec. 60.43Da and the NOX 
emission limitation under Sec. 60.44Da is based on the average emission 
rates for SO2, NOX, and percent reduction for 
SO2 for the first 30 successive boiler operating days. The 
initial performance test is the only test in which at least 30 days 
prior notice is required unless otherwise specified by the 
Administrator. The initial performance test is to be scheduled so that 
the first boiler operating day of the 30 successive boiler operating 
days is completed within 60 days after achieving the maximum production 
rate at which the affected facility will be operated, but not later than 
180 days after initial startup of the facility.
    (g) The owner or operator of an affected facility subject to 
emission limitations in this subpart shall determine compliance as 
follows:
    (1) Compliance with applicable 30-day rolling average SO2 
and NOX emission limitations is determined by calculating the 
arithmetic average of all hourly emission rates for SO2 and 
NOX for the 30 successive boiler operating days, except for 
data obtained during startup, shutdown, malfunction (NOX 
only), or emergency conditions (SO2 only).
    (2) Compliance with applicable SO2 percentage reduction 
requirements is determined based on the average inlet and outlet 
SO2 emission rates for the 30 successive boiler operating 
days.
    (3) Compliance with applicable daily average PM emission limitations 
is determined by calculating the arithmetic average of all hourly 
emission rates for PM each boiler operating day, except for data 
obtained during startup, shutdown, and malfunction. Averages are only 
calculated for boiler operating days that have valid data for at least 
18 hours of unit operation during which the standard applies. Instead, 
all of the valid hourly emission rates of the operating day(s) not 
meeting the minimum 18 hours valid data daily average requirement are 
averaged with all of the valid hourly emission rates of the next boiler 
operating day with 18 hours or more of valid PM CEMS data to determine 
compliance.
    (h) If an owner or operator has not obtained the minimum quantity of 
emission data as required under Sec. 60.49Da of this subpart, 
compliance of the affected facility with the emission requirements under 
Sec. Sec. 60.43Da and 60.44Da of this subpart for the day on which the 
30-day period ends may be determined by the Administrator by following 
the applicable procedures in section 7 of Method 19 of appendix A of 
this part.
    (i) Compliance provisions for sources subject to Sec. 
60.44Da(d)(1), (e)(1), (e)(2)(i), (e)(3)(i), or (f). The owner or 
operator of an affected facility subject to Sec. 60.44Da(d)(1), (e)(1), 
(e)(2)(i), (e)(3)(i), or (f) shall calculate NOX emissions as 
1.194 x 10-\7\ lb/scf-ppm times the average hourly 
NOX output concentration in ppm (measured according to the 
provisions of Sec. 60.49Da(c)), times the average hourly flow rate 
(measured in scfh, according to the provisions of Sec. 60.49Da(l) or 
Sec. 60.49Da(m)), divided by the average hourly gross energy output 
(measured according to the provisions of Sec. 60.49Da(k)). 
Alternatively, for oil-fired and gas-fired units, NOX 
emissions may be calculated by multiplying the hourly NOX 
emission rate in lb/MMBtu (measured by the CEMS required under 
Sec. Sec. 60.49Da(c) and (d)), by the hourly heat input rate (measured 
according to the provisions of Sec. 60.49Da(n)), and dividing the 
result by the average gross energy output (measured according to the 
provisions of Sec. 60.49Da(k)).
    (j) Compliance provisions for duct burners subject to Sec. 
60.44Da(a)(1). To determine compliance with the emissions limits for 
NOX required by Sec. 60.44Da(a) for duct burners used in 
combined cycle systems, either of the procedures

[[Page 163]]

described in paragraph (j)(1) or (2) of this section may be used:
    (1) The owner or operator of an affected duct burner shall conduct 
the performance test required under Sec. 60.8 using the appropriate 
methods in appendix A of this part. Compliance with the emissions limits 
under Sec. 60.44Da(a)(1) is determined on the average of three (nominal 
1-hour) runs for the initial and subsequent performance tests. During 
the performance test, one sampling site shall be located in the exhaust 
of the turbine prior to the duct burner. A second sampling site shall be 
located at the outlet from the heat recovery steam generating unit. 
Measurements shall be taken at both sampling sites during the 
performance test; or
    (2) The owner or operator of an affected duct burner may elect to 
determine compliance by using the CEMS specified under Sec. 60.49Da for 
measuring NOX and oxygen (O2) (or carbon dioxide 
(CO2)) and meet the requirements of Sec. 60.49Da. 
Alternatively, data from a NOX emission rate (i.e., 
NOX-diluent) CEMS certified according to the provisions of 
Sec. 75.20(c) of this chapter and appendix A to part 75 of this 
chapter, and meeting the quality assurance requirements of Sec. 75.21 
of this chapter and appendix B to part 75 of this chapter, may be used, 
with the following caveats. Data used to meet the requirements of Sec. 
60.51Da shall not include substitute data values derived from the 
missing data procedures in subpart D of part 75 of this chapter, nor 
shall the data have been bias adjusted according to the procedures of 
part 75 of this chapter. The sampling site shall be located at the 
outlet from the steam generating unit. The NOX emission rate 
at the outlet from the steam generating unit shall constitute the 
NOX emission rate from the duct burner of the combined cycle 
system.
    (k) Compliance provisions for duct burners subject to Sec. 
60.44Da(d)(1) or (e)(1). To determine compliance with the emission 
limitation for NOX required by Sec. 60.44Da(d)(1) or (e)(1) 
for duct burners used in combined cycle systems, either of the 
procedures described in paragraphs (k)(1) and (2) of this section may be 
used:
    (1) The owner or operator of an affected duct burner used in 
combined cycle systems shall determine compliance with the applicable 
NOX emission limitation in Sec. 60.44Da(d)(1) or (e)(1) as 
follows:
    (i) The emission rate (E) of NOX shall be computed using 
Equation 2 in this section:
[GRAPHIC] [TIFF OMITTED] TR13JN07.012

Where:

E = Emission rate of NOX from the duct burner, ng/J (lb/MWh) 
gross output;
Csg = Average hourly concentration of NOX exiting 
the steam generating unit, ng/dscm (lb/dscf);
Cte = Average hourly concentration of NOX in the 
turbine exhaust upstream from duct burner, ng/dscm (lb/dscf);
Qsg = Average hourly volumetric flow rate of exhaust gas from 
steam generating unit, dscm/hr (dscf/hr);
Qte = Average hourly volumetric flow rate of exhaust gas from 
combustion turbine, dscm/hr (dscf/hr);
Osg = Average hourly gross energy output from steam 
generating unit, J (MWh); and
h = Average hourly fraction of the total heat input to the steam 
generating unit derived from the combustion of fuel in the affected duct 
burner.

    (ii) Method 7E of appendix A of this part shall be used to determine 
the NOX concentrations (Csg and Cte). 
Method 2, 2F or 2G of appendix A of this part, as appropriate, shall be 
used to determine the volumetric flow rates (Qsg and 
Qte) of the exhaust gases. The volumetric flow rate 
measurements shall be taken at the same time as the concentration 
measurements.
    (iii) The owner or operator shall develop, demonstrate, and provide 
information satisfactory to the Administrator to determine the average 
hourly gross energy output from the steam generating unit, and the 
average hourly percentage of the total heat input to the steam 
generating unit derived from the combustion of fuel in the affected duct 
burner.
    (iv) Compliance with the applicable NOX emission 
limitation in Sec. 60.44Da(d)(1) or (e)(1) is determined by the three-
run average (nominal 1-hour runs) for the initial and subsequent 
performance tests.

[[Page 164]]

    (2) The owner or operator of an affected duct burner used in a 
combined cycle system may elect to determine compliance with the 
applicable NOX emission limitation in Sec. 60.44Da(d)(1) or 
(e)(1) on a 30-day rolling average basis as indicated in paragraphs 
(k)(2)(i) through (iv) of this section.
    (i) The emission rate (E) of NOX shall be computed using 
Equation 3 in this section:
[GRAPHIC] [TIFF OMITTED] TR13JN07.013

Where:

E = Emission rate of NOX from the duct burner, ng/J (lb/MWh) 
gross output;
Csg = Average hourly concentration of NOX exiting 
the steam generating unit, ng/dscm (lb/dscf);
Qsg = Average hourly volumetric flow rate of exhaust gas from 
steam generating unit, dscm/hr (dscf/hr); and
Occ = Average hourly gross energy output from entire combined 
cycle unit, J (MWh).

    (ii) The CEMS specified under Sec. 60.49Da for measuring 
NOX and O2 (or CO2) shall be used to 
determine the average hourly NOX concentrations 
(Csg). The continuous flow monitoring system specified in 
Sec. 60.49Da(l) or Sec. 60.49Da(m) shall be used to determine the 
volumetric flow rate (Qsg) of the exhaust gas. If the option 
to use the flow monitoring system in Sec. 60.49Da(m) is selected, the 
flow rate data used to meet the requirements of Sec. 60.51Da shall not 
include substitute data values derived from the missing data procedures 
in subpart D of part 75 of this chapter, nor shall the data have been 
bias adjusted according to the procedures of part 75 of this chapter. 
The sampling site shall be located at the outlet from the steam 
generating unit.
    (iii) The continuous monitoring system specified under Sec. 
60.49Da(k) for measuring and determining gross energy output shall be 
used to determine the average hourly gross energy output from the entire 
combined cycle unit (Occ), which is the combined output from 
the combustion turbine and the steam generating unit.
    (iv) The owner or operator may, in lieu of installing, operating, 
and recording data from the continuous flow monitoring system specified 
in Sec. 60.49Da(l), determine the mass rate (lb/hr) of NOX 
emissions by installing, operating, and maintaining continuous fuel 
flowmeters following the appropriate measurements procedures specified 
in appendix D of part 75 of this chapter. If this compliance option is 
selected, the emission rate (E) of NOX shall be computed 
using Equation 4 in this section:
[GRAPHIC] [TIFF OMITTED] TR13JN07.014

Where:

E = Emission rate of NOX from the duct burner, ng/J (lb/MWh) 
gross output;
ERsg = Average hourly emission rate of NOX exiting 
the steam generating unit heat input calculated using appropriate F 
factor as described in Method 19 of appendix A of this part, ng/J (lb/
MMBtu);
Hcc = Average hourly heat input rate of entire combined cycle 
unit, J/hr (MMBtu/hr); and
Occ = Average hourly gross energy output from entire combined 
cycle unit, J (MWh).

    (3) When an affected duct burner steam generating unit utilizes a 
common steam turbine with one or more affected duct burner steam 
generating units, the owner or operator shall either:
    (i) Determine compliance with the applicable NOX 
emissions limits by measuring the emissions combined with the emissions 
from the other unit(s) utilizing the common steam turbine; or
    (ii) Develop, demonstrate, and provide information satisfactory to 
the Administrator on methods for apportioning the combined gross energy 
output from the steam turbine for each of the affected duct burners. The 
Administrator may approve such demonstrated substitute methods for 
apportioning the combined gross energy output measured at the steam 
turbine whenever the demonstration ensures accurate estimation of 
emissions regulated under this part.
    (l) Compliance provisions for sources subject to Sec. 60.45Da. The 
owner or operator of an affected facility subject to Sec. 60.45Da (new 
sources constructed or reconstructed after January 30, 2004) shall 
calculate the Hg emission rate (lb/MWh) for each calendar month of

[[Page 165]]

the year, using hourly Hg concentrations measured according to the 
provisions of Sec. 60.49Da(p) in conjunction with hourly stack gas 
volumetric flow rates measured according to the provisions of Sec. 
60.49Da(l) or (m), and hourly gross electrical outputs, determined 
according to the provisions in Sec. 60.49Da(k). Compliance with the 
applicable standard under Sec. 60.45Da is determined on a 12-month 
rolling average basis.
    (m) Compliance provisions for sources subject to Sec. 
60.43Da(i)(1)(i), (i)(2)(i), (i)(3)(i), (j)(1)(i), (j)(2)(i), or 
(j)(3)(i). The owner or operator of an affected facility subject to 
Sec. 60.43Da(i)(1)(i), (i)(2)(i), (i)(3)(i), (j)(1)(i), (j)(2)(i), or 
(j)(3)(i) shall calculate SO2 emissions as 1.660 x 
10-7 lb/scf-ppm times the average hourly SO2 
output concentration in ppm (measured according to the provisions of 
Sec. 60.49Da(b)), times the average hourly flow rate (measured 
according to the provisions of Sec. 60.49Da(l) or Sec. 60.49Da(m)), 
divided by the average hourly gross energy output (measured according to 
the provisions of Sec. 60.49Da(k)). Alternatively, for oil-fired and 
gas-fired units, SO2 emissions may be calculated by 
multiplying the hourly SO2 emission rate (in lb/MMBtu), 
measured by the CEMS required under Sec. 60.49Da, by the hourly heat 
input rate (measured according to the provisions of Sec. 60.49Da(n)), 
and dividing the result by the average gross energy output (measured 
according to the provisions of Sec. 60.49Da(k)).
    (n) Compliance provisions for sources subject to Sec. 
60.42Da(c)(1). The owner or operator of an affected facility subject to 
Sec. 60.42Da(c)(1) shall calculate PM emissions by multiplying the 
average hourly PM output concentration (measured according to the 
provisions of Sec. 60.49Da(t)), by the average hourly flow rate 
(measured according to the provisions of Sec. 60.49Da(l) or Sec. 
60.49Da(m)), and divided by the average hourly gross energy output 
(measured according to the provisions of Sec. 60.49Da(k)). Compliance 
with the emission limit is determined by calculating the arithmetic 
average of the hourly emission rates computed for each boiler operating 
day.
    (o) Compliance provisions for sources subject to Sec. 60.42Da(c)(2) 
or (d). Except as provided for in paragraph (p) of this section, the 
owner or operator of an affected facility for which construction, 
reconstruction, or modification commenced after February 28, 2005, shall 
demonstrate compliance with each applicable emission limit according to 
the requirements in paragraphs (o)(1) through (o)(5) of this section.
    (1) You must conduct a performance test to demonstrate initial 
compliance with the applicable PM emissions limit in Sec. 60.42Da(c)(2) 
or (d) by the applicable date specified in Sec. 60.8(a). Thereafter, 
you must conduct each subsequent performance test within 12 calendar 
months following the date the previous performance test was required to 
be conducted. You must conduct each performance test according to the 
requirements in Sec. 60.8 using the test methods and procedures in 
Sec. 60.50Da. The owner or operator of an affected facility that has 
not operated for 60 consecutive calendar days prior to the date that the 
subsequent performance test would have been required had the unit been 
operating is not required to perform the subsequent performance test 
until 30 calendar days after the next boiler operating day. Requests for 
additional 30 day extensions shall be granted by the relevant air 
division or office director of the appropriate Regional Office of the 
U.S. EPA.
    (2) You must monitor the performance of each electrostatic 
precipitator or fabric filter (baghouse) operated to comply with the 
applicable PM emissions limit in Sec. 60.42Da(c)(2) or (d) using a 
continuous opacity monitoring system (COMS) according to the 
requirements in paragraphs (o)(2)(i) through (vi) unless you elect to 
comply with one of the alternatives provided in paragraphs (o)(3) and 
(o)(4) of this section, as applicable to your control device.
    (i) Each COMS must meet Performance Specification 1 in 40 CFR part 
60, appendix B.
    (ii) You must comply with the quality assurance requirements in 
paragraphs (o)(2)(ii)(A) through (E) of this section.
    (A) You must automatically (intrinsic to the opacity monitor) check 
the zero and upscale (span) calibration drifts at least once daily. For 
a particular COMS, the acceptable range of

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zero and upscale calibration materials is as defined in the applicable 
version of Performance Specification 1 in 40 CFR part 60, appendix B.
    (B) You must adjust the zero and span whenever the 24-hour zero 
drift or 24-hour span drift exceeds 4 percent opacity. The COMS must 
allow for the amount of excess zero and span drift measured at the 24-
hour interval checks to be recorded and quantified. The optical surfaces 
exposed to the effluent gases must be cleaned prior to performing the 
zero and span drift adjustments, except for systems using automatic zero 
adjustments. For systems using automatic zero adjustments, the optical 
surfaces must be cleaned when the cumulative automatic zero compensation 
exceeds 4 percent opacity.
    (C) You must apply a method for producing a simulated zero opacity 
condition and an upscale (span) opacity condition using a certified 
neutral density filter or other related technique to produce a known 
obscuration of the light beam. All procedures applied must provide a 
system check of the analyzer internal optical surfaces and all 
electronic circuitry including the lamp and photodetector assembly.
    (D) Except during periods of system breakdowns, repairs, calibration 
checks, and zero and span adjustments, the COMS must be in continuous 
operation and must complete a minimum of one cycle of sampling and 
analyzing for each successive 10 second period and one cycle of data 
recording for each successive 6-minute period.
    (E) You must reduce all data from the COMS to 6-minute averages. 
Six-minute opacity averages must be calculated from 36 or more data 
points equally spaced over each 6-minute period. Data recorded during 
periods of system breakdowns, repairs, calibration checks, and zero and 
span adjustments must not be included in the data averages. An 
arithmetic or integrated average of all data may be used.
    (iii) During each performance test conducted according to paragraph 
(o)(1) of this section, you must establish an opacity baseline level. 
The value of the opacity baseline level is determined by averaging all 
of the 6-minute average opacity values (reported to the nearest 0.1 
percent opacity) from the COMS measurements recorded during each of the 
test run intervals conducted for the performance test, and then adding 
2.5 percent opacity to your calculated average opacity value for all of 
the test runs. If your opacity baseline level is less than 5.0 percent, 
then the opacity baseline level is set at 5.0 percent.
    (iv) You must evaluate the preceding 24-hour average opacity level 
measured by the COMS each boiler operating day excluding periods of 
affected facility startup, shutdown, or malfunction. If the measured 24-
hour average opacity emission level is greater than the baseline opacity 
level determined in paragraph (o)(2)(iii) of this section, you must 
initiate investigation of the relevant equipment and control systems 
within 24 hours of the first discovery of the high opacity incident and 
take the appropriate corrective action as soon as practicable to adjust 
control settings or repair equipment to reduce the measured 24-hour 
average opacity to a level below the baseline opacity level. In cases 
when a wet scrubber is used in combination with another PM control 
device that serves as the primary PM control device, the wet scrubber 
must be maintained and operated.
    (v) You must record the opacity measurements, calculations 
performed, and any corrective actions taken. The record of corrective 
action taken must include the date and time during which the measured 
24-hour average opacity was greater than baseline opacity level, and the 
date, time, and description of the corrective action.
    (vi) If the measured 24-hour average opacity for your affected 
facility remains at a level greater than the opacity baseline level 
after 7 boiler operating days, then you must conduct a new PM 
performance test according to paragraph (o)(1) of this section and 
establish a new opacity baseline value according to paragraph (o)(2) of 
this section. This new performance test must be conducted within 60 days 
of the date that the measured 24-hour average opacity was first 
determined to exceed the baseline opacity level unless a waiver is 
granted by the permitting authority.

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    (3) As an alternative to complying with the requirements of 
paragraph (o)(2) of this section, an owner or operator may elect to 
monitor the performance of an electrostatic precipitator (ESP) operated 
to comply with the applicable PM emissions limit in Sec. 60.42Da(c)(2) 
or (d) using an ESP predictive model developed in accordance with the 
requirements in paragraphs (o)(3)(i) through (v) of this section.
    (i) You must calibrate the ESP predictive model with each PM control 
device used to comply with the applicable PM emissions limit in Sec. 
60.42Da(c)(2) or (d) operating under normal conditions. In cases when a 
wet scrubber is used in combination with an ESP to comply with the PM 
emissions limit, the wet scrubber must be maintained and operated.
    (ii) You must develop a site-specific monitoring plan that includes 
a description of the ESP predictive model used, the model input 
parameters, and the procedures and criteria for establishing monitoring 
parameter baseline levels indicative of compliance with the PM emissions 
limit. You must submit the site-specific monitoring plan for approval by 
the permitting authority. For reference purposes in preparing the 
monitoring plan, see the OAQPS ``Compliance Assurance Monitoring (CAM) 
Protocol for an Electrostatic Precipitator (ESP) Controlling Particulate 
Matter (PM) Emissions from a Coal-Fired Boiler.'' This document is 
available from the U.S. Environmental Protection Agency (U.S. EPA); 
Office of Air Quality Planning and Standards; Sector Policies and 
Programs Division; Measurement Policy Group (D243-02), Research Triangle 
Park, NC 27711. This document is also available on the Technology 
Transfer Network (TTN) under Emission Measurement Center Continuous 
Emission Monitoring.
    (iii) You must run the ESP predictive model using the applicable 
input data each boiler operating day and evaluate the model output for 
the preceding boiler operating day excluding periods of affected 
facility startup, shutdown, or malfunction. If the values for one or 
more of the model parameters exceed the applicable baseline levels 
determined according to your approved site-specific monitoring plan, you 
must initiate investigation of the relevant equipment and control 
systems within 24 hours of the first discovery of a model parameter 
deviation and, take the appropriate corrective action as soon as 
practicable to adjust control settings or repair equipment to return the 
model output to within the applicable baseline levels.
    (iv) You must record the ESP predictive model inputs and outputs and 
any corrective actions taken. The record of corrective action taken must 
include the date and time during which the model output values exceeded 
the applicable baseline levels, and the date, time, and description of 
the corrective action.
    (v) If after 7 consecutive days a model parameter continues to 
exceed the applicable baseline level, then you must conduct a new PM 
performance test according to paragraph (o)(1) of this section. This new 
performance test must be conducted within 60 calendar days of the date 
that the model parameter was first determined to exceed its baseline 
level unless a waiver is granted by the permitting authority.
    (4) As an alternative to complying with the requirements of 
paragraph (o)(2) of this section, an owner or operator may elect to 
monitor the performance of a fabric filter (baghouse) operated to comply 
with the applicable PM emissions limit in Sec. 60.42Da(c)(2) or (d) by 
using a bag leak detection system according to the requirements in 
paragraphs (o)(4)(i) through (v) of this section.
    (i) Each bag leak detection system must meet the specifications and 
requirements in paragraphs (o)(4)(i)(A) through (H) of this section.
    (A) The bag leak detection system must be certified by the 
manufacturer to be capable of detecting PM emissions at concentrations 
of 1 milligram per actual cubic meter (0.00044 grains per actual cubic 
foot) or less.
    (B) The bag leak detection system sensor must provide output of 
relative PM loadings. The owner or operator must continuously record the 
output from the bag leak detection system using electronic or other 
means (e.g., using a strip chart recorder or a data logger.)

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    (C) The bag leak detection system must be equipped with an alarm 
system that will react when the system detects an increase in relative 
particulate loading over the alarm set point established according to 
paragraph (o)(4)(i)(D) of this section, and the alarm must be located 
such that it can be noticed by the appropriate plant personnel.
    (D) In the initial adjustment of the bag leak detection system, you 
must establish, at a minimum, the baseline output by adjusting the 
sensitivity (range) and the averaging period of the device, the alarm 
set points, and the alarm delay time.
    (E) Following initial adjustment, you must not adjust the averaging 
period, alarm set point, or alarm delay time without approval from the 
permitting authority except as provided in paragraph (d)(1)(vi) of this 
section.
    (F) Once per quarter, you may adjust the sensitivity of the bag leak 
detection system to account for seasonal effects, including temperature 
and humidity, according to the procedures identified in the site-
specific monitoring plan required by paragraph (o)(4)(ii) of this 
section.
    (G) You must install the bag leak detection sensor downstream of the 
fabric filter and upstream of any wet scrubber.
    (H) Where multiple detectors are required, the system's 
instrumentation and alarm may be shared among detectors.
    (ii) You must develop and submit to the permitting authority for 
approval a site-specific monitoring plan for each bag leak detection 
system. You must operate and maintain the bag leak detection system 
according to the site-specific monitoring plan at all times. Each 
monitoring plan must describe the items in paragraphs (o)(4)(ii)(A) 
through (F) of this section.
    (A) Installation of the bag leak detection system;
    (B) Initial and periodic adjustment of the bag leak detection 
system, including how the alarm set-point will be established;
    (C) Operation of the bag leak detection system, including quality 
assurance procedures;
    (D) How the bag leak detection system will be maintained, including 
a routine maintenance schedule and spare parts inventory list;
    (E) How the bag leak detection system output will be recorded and 
stored; and
    (F) Corrective action procedures as specified in paragraph 
(o)(4)(iii) of this section. In approving the site-specific monitoring 
plan, the permitting authority may allow owners and operators more than 
3 hours to alleviate a specific condition that causes an alarm if the 
owner or operator identifies in the monitoring plan this specific 
condition as one that could lead to an alarm, adequately explains why it 
is not feasible to alleviate this condition within 3 hours of the time 
the alarm occurs, and demonstrates that the requested time will ensure 
alleviation of this condition as expeditiously as practicable.
    (iii) For each bag leak detection system, you must initiate 
procedures to determine the cause of every alarm within 1 hour of the 
alarm. Except as provided in paragraph (o)(4)(ii)(F) of this section, 
you must alleviate the cause of the alarm within 3 hours of the alarm by 
taking whatever corrective action(s) are necessary. Corrective actions 
may include, but are not limited to the following:
    (A) Inspecting the fabric filter for air leaks, torn or broken bags 
or filter media, or any other condition that may cause an increase in 
particulate emissions;
    (B) Sealing off defective bags or filter media;
    (C) Replacing defective bags or filter media or otherwise repairing 
the control device;
    (D) Sealing off a defective fabric filter compartment;
    (E) Cleaning the bag leak detection system probe or otherwise 
repairing the bag leak detection system; or
    (F) Shutting down the process producing the particulate emissions.
    (iv) You must maintain records of the information specified in 
paragraphs (o)(4)(iv)(A) through (C) of this section for each bag leak 
detection system.
    (A) Records of the bag leak detection system output;

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    (B) Records of bag leak detection system adjustments, including the 
date and time of the adjustment, the initial bag leak detection system 
settings, and the final bag leak detection system settings; and
    (C) The date and time of all bag leak detection system alarms, the 
time that procedures to determine the cause of the alarm were initiated, 
if procedures were initiated within 1 hour of the alarm, the cause of 
the alarm, an explanation of the actions taken, the date and time the 
cause of the alarm was alleviated, and if the alarm was alleviated 
within 3 hours of the alarm.
    (v) If after any period composed of 30 boiler operating days during 
which the alarm rate exceeds 5 percent of the process operating time 
(excluding control device or process startup, shutdown, and 
malfunction), then you must conduct a new PM performance test according 
to paragraph (o)(1) of this section. This new performance test must be 
conducted within 60 calendar days of the date that the alarm rate was 
first determined to exceed 5 percent limit unless a waiver is granted by 
the permitting authority.
    (5) An owner or operator of a modified affected facility electing to 
meet the emission limitations in Sec. 60.42Da(d) shall determine the 
percent reduction in PM by using the emission rate for PM determined by 
the performance test conducted according to the requirements in 
paragraph (o)(1) of this section and the ash content on a mass basis of 
the fuel burned during each performance test run as determined by 
analysis of the fuel as fired.
    (p) As an alternative to meeting the compliance provisions specified 
in paragraph (o) of this section, an owner or operator may elect to 
install, evaluate, maintain, and operate a CEMS measuring PM emissions 
discharged from the affected facility to the atmosphere and record the 
output of the system as specified in paragraphs (p)(1) through (p)(8) of 
this section.
    (1) The owner or operator shall submit a written notification to the 
Administrator of intent to demonstrate compliance with this subpart by 
using a CEMS measuring PM. This notification shall be sent at least 30 
calendar days before the initial startup of the monitor for compliance 
determination purposes. The owner or operator may discontinue operation 
of the monitor and instead return to demonstration of compliance with 
this subpart according to the requirements in paragraph (o) of this 
section by submitting written notification to the Administrator of such 
intent at least 30 calendar days before shutdown of the monitor for 
compliance determination purposes.
    (2) Each CEMS shall be installed, evaluated, operated, and 
maintained according to the requirements in Sec. 60.49Da(v).
    (3) The initial performance evaluation shall be completed no later 
than 180 days after the date of initial startup of the affected 
facility, as specified under Sec. 60.8 of subpart A of this part or 
within 180 days of the date of notification to the Administrator 
required under paragraph (p)(1) of this section, whichever is later.
    (4) Compliance with the applicable emissions limit shall be 
determined based on the 24-hour daily (block) average of the hourly 
arithmetic average emissions concentrations using the continuous 
monitoring system outlet data. The 24-hour block arithmetic average 
emission concentration shall be calculated using EPA Reference Method 19 
of appendix A of this part, section 4.1.
    (5) At a minimum, valid CEMS hourly averages shall be obtained for 
75 percent of all operating hours on a 30-day rolling average basis. 
Beginning on January 1, 2012, valid CEMS hourly averages shall be 
obtained for 90 percent of all operating hours on a 30-day rolling 
average basis.
    (i) At least two data points per hour shall be used to calculate 
each 1-hour arithmetic average.
    (ii) [Reserved]
    (6) The 1-hour arithmetic averages required shall be expressed in 
ng/J, MMBtu/hr, or lb/MWh and shall be used to calculate the boiler 
operating day daily arithmetic average emission concentrations. The 1-
hour arithmetic averages shall be calculated using the data points 
required under Sec. 60.13(e)(2) of subpart A of this part.
    (7) All valid CEMS data shall be used in calculating average 
emission concentrations even if the minimum

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CEMS data requirements of paragraph (j)(5) of this section are not met.
    (8) When PM emissions data are not obtained because of CEMS 
breakdowns, repairs, calibration checks, and zero and span adjustments, 
emissions data shall be obtained by using other monitoring systems as 
approved by the Administrator or EPA Reference Method 19 of appendix A 
of this part to provide, as necessary, valid emissions data for a 
minimum of 90 percent (only 75 percent is required prior to January 1, 
2012) of all operating hours per 30-day rolling average.
    (q) Compliance provisions for sources subject to Sec. 60.42Da(b). 
An owner or operator of an affected facility subject to the opacity 
standard in Sec. 60.42Da(b) shall monitor the opacity of emissions 
discharged from the affected facility to the atmosphere according to the 
requirements in Sec. 60.49Da(a), as applicable to the affected 
facility.

[72 FR 32722, June 13, 2007, as amended at 74 FR 5079, Jan. 28, 2009]