En = [86 w + 130 x + 210 y + 260 z + 340 v] /100
where:
En is the applicable standard for nitrogen oxides when multiple fuels are combusted simultaneously (ng/J heat input)
w is the percentage of total heat input derived from the combustion of fuels subject to the 86 ng/J heat input standard
x is the percentage of total heat input derived from the combustion of fuels subject to the 130 ng/J heat input standard
y is the percentage of total heat input derived from the combustion of fuels subject to the 210 ng/J heat input standard
z is the percentage of total heat input derived from the combustion of fuels subject to the 260 ng/J heat input standard
v is the percentage of total heat input delivered from the combustion of fuels subject to the 340 ng/J heat input standard
NR 440.20(5)(d)1.1. On and after the date on which the initial performance test required to be conducted under
s. NR 440.08 is completed, no new source owner or operator subject to the provisions of this section may cause to be discharged into the atmosphere from any affected facility for which construction commenced after July 9, 1997 any gases which contain nitrogen oxides, expressed as NO
2, in excess of 200 nanograms per joule (1.6 pounds per megawatt-hour) gross energy output, based on a 30-day rolling average, except as provided under
sub. (6) (k) 1.
NR 440.20(5)(d)2.
2. On and after the date on which the initial performance test required to be conducted under
s. NR 440.08 is completed, no existing source owner or operator subject to the provisions of this section may cause to be discharged into the atmosphere from any affected facility for which construction commenced after July 9, 1997 any gases which contain nitrogen oxides, expressed as NO
2, in excess of 65 nanograms per joule (0.15 pounds per million Btu) heat input, based on a 30-day rolling average.
NR 440.20(6)(a)(a)
Percent reduction requirement for particulate matter. Compliance with the particulate matter emission limitation under
sub. (3) (a) 1. constitutes compliance with the percent reduction requirements for particulate matter under
sub. (3) (a) 2. and
3.
NR 440.20(6)(b)
(b)
Percent reduction requirement for NOx. Compliance with the nitrogen oxides emission limitation under
sub. (5) (a) 1. constitutes compliance with the percent reduction requirements under
sub. (5) (a) 2.
NR 440.20(6)(c)
(c)
Compliance exception. The particulate matter emissions standards under
sub. (3) and the nitrogen oxides emission standards under
sub. (5) apply at all times except during periods of startup, shutdown or malfunction. The sulfur dioxide emission standards under
sub. (4) apply at all times except during periods of startup, shutdown or when both emergency conditions exist and the procedures under
par. (d) are implemented.
NR 440.20(6)(d)
(d)
Operation with malfunctioning flue gas desulfurization. During emergency conditions in the principal company, an affected facility with a malfunctioning flue gas desulfurization system may be operated if sulfur dioxide emissions are minimized by:
NR 440.20(6)(d)1.
1. Operating all operable flue gas desulfurization system modules, and bringing back into operation any malfunctioned module as soon as repairs are completed.
NR 440.20(6)(d)2.
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 sulfur dioxide emission reduction or which would have suffered significant physical damage if they had remained in operation, and
NR 440.20(6)(d)3.
3. Designing, constructing and operating a spare flue gas desulfurization system module for an affected facility larger than 365 MW (1,250 million Btu/hr) heat input (approximately 125 MW electrical output capacity). The department may at its discretion require the owner or operator within 60 days of notification to demonstrate spare module capability. To demonstrate this capability, the owner or operator shall demonstrate compliance with the appropriate requirements under
sub. (4) (a),
(b),
(d) and
(h) for any period of operation lasting from 24 hours to 30 days when:
NR 440.20(6)(d)3.c.
c. 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
NR 440.20(6)(d)3.d.
d. The owner or operator has given the department at least 30 days notice of the date and period of time over which the demonstration will be performed.
NR 440.20(6)(e)
(e)
Compliance after the initial performance test. After the initial performance test required under
s. NR 440.08, compliance with the sulfur dioxide emission limitations and percentage reduction requirements under
sub. (4) and the nitrogen oxides emission limitations under
sub. (5) shall be 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 sulfur dioxide and nitrogen oxides and a new percent reduction of sulfur dioxide are calculated to show compliance with the standards.
NR 440.20(6)(f)
(f)
Initial performance test. For the initial performance test required under
s. NR 440.08, compliance with the sulfur dioxide emission limitations and percent reduction requirements under
sub. (4) and the nitrogen oxides emission limitation under
sub. (5) shall be based on the average emission rates for sulfur dioxide, nitrogen oxides, and percent reduction for sulfur dioxide 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 department. The initial performance test shall 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.
NR 440.20(6)(g)
(g)
Compliance calculations for SO2 and NOx. Compliance shall be determined by calculating the arithmetic average of all hourly emission rates for SO
2 and NO
x for the 30 successive boiler operating days, except for data obtained during startup, shutdown, malfunction (NO
x only) or emergency conditions (SO
2 only). Compliance with the percentage reduction requirement for SO
2 shall be determined based on the average inlet and average outlet SO
2 emission rates for the 30 successive boiler operating days.
NR 440.20(6)(h)
(h)
Quantity of emission data below minimum. If an owner or operator has not obtained the minimum quantity of emission data as required under
sub. (7), compliance of the affected facility with the emission requirements under
subs. (4) and
(5) for the day on which the 30-day period ends may be determined by the department by following the applicable procedures in section 7.0 of Method 19,
40 CFR part 60, Appendix A, incorporated by reference in
s. NR 440.17.
NR 440.20(6)(i)
(i)
Compliance provisions for sources subject to sub. (5) (d) 1. The owner or operator of an affected facility subject to
sub. (5) (d) 1. (new source constructed after July 7, 1997) shall calculate NO
x emissions by multiplying the average hourly NO
x output concentration measured according to the provisions of
sub. (7) (c) by the average hourly flow rate measured according to the provisions of
sub. (7) (L) and divided by the average hourly gross energy output measured according to the provisions of
sub. (7) (k).
NR 440.20(6)(j)
(j)
Compliance provisions for duct burners subject to sub. (5) (a) 1. To determine compliance with the emissions limits for NO
x required by
sub. (5) (a) for duct burners used in combined cycle systems, the owner or operator of an affected duct burner shall use one of the following procedures:
NR 440.20(6)(j)1.
1. Conduct the performance test required under
s. NR 440.08 using the appropriate methods in
40 CFR part 60, Appendix A, incorporated by reference in
s. NR 440.17 (1). Compliance with the emissions limits under
sub. (5) (a) 1. shall be determined on the average of 3 (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.
NR 440.20(6)(j)2.
2. Use the continuous emission monitoring system specified under
sub. (7) for measuring NO
x and oxygen and meet the requirements of
sub. (7). Data from a CEMS certified or recertified according to the provisions of
40 CFR 75.20, meeting the QA and QC requirements of
40 CFR 75.21, and validated according to
40 CFR 75.23, may be used. The sampling site shall be located at the outlet from the steam generating unit. The NO
x emission rate at the outlet from the steam generating unit shall constitute the NO
x emission rate from the duct burner of the combined cycle system.
NR 440.20(6)(k)
(k)
Compliance provisions for duct burners subject to sub. (5) (d) 1. To determine compliance with the emissions limits for NOx required by
sub. (5) (d) 1. for duct burners used in combined cycle systems, either of the procedures described in
subd. 1. or
2. shall be used.
where
E is the emission rate of NOx from the duct burner, ng/J (lb/Mwh) gross output
Csg is the average hourly concentration of NOx exiting the steam generating unit, ng/dscm (lb/dscf)
Cte is the average hourly concentration of NOx in the turbine exhaust upstream from duct burner, ng/dscm (lb/dscf)
Qsg is the average hourly volumetric flow rate of exhaust gas from steam generating unit, dscm/hr (dscf/hr)
Qte is the average hourly volumetric flow rate of exhaust gas from combustion turbine, dscm/hr (dscf/hr)
Osg is the average hourly gross energy output from steam generating unit, J (Mwh)
h is the average hourly fraction of the total heat input to the steam generating unit derived from the combustion of fuel in the affected duct burner
NR 440.20(6)(k)1.b.
b. Use Method 7E in
40 CFR part 60, Appendix A, incorporated by reference in
s. NR 440.17 (1), to determine the NO
x concentrations (Csg and Cte). Use Method 2, 2F or 2G in
40 CFR part 60, Appendix A, as appropriate, 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.
NR 440.20(6)(k)1.c.
c. Develop, demonstrate and provide information satisfactory to the department 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.
NR 440.20(6)(k)1.d.
d. Determine compliance with the emissions limits under
sub. (5) (d) 1. by the 3-run average (nominal 1-hour runs) for the initial and subsequent performance tests.
NR 440.20(6)(k)2.
2. Use a 30-day rolling average basis by doing all of the following:
where:
E is the emission rate of NOx from the duct burner, ng/J (lb/Mwh) gross output
Csg is the average hourly concentration of NOx exiting the steam generating unit, ng/dscm (lb/dscf)
Qsg is the average hourly volumetric flow rate of exhaust gas from steam generating unit, dscm/hr (dscf/hr)
Occ is the average hourly gross energy output from entire combined cycle unit, J (Mwh)
NR 440.20(6)(k)2.b.
b. Use the continuous emissions monitoring system specified under
sub. (7) for measuring NO
x and oxygen to determine the average hourly NO
x concentrations (Csg). The continuous flow monitoring system specified in
sub. (7) (L) shall be used to determine the volumetric flow rate (Qsg) of the exhaust gas. The sampling site shall be located at the outlet from the steam generating unit. Data from a continuous flow monitoring system certified or recertified following procedures specified in
40 CFR 75.20, meeting the quality assurance and quality control requirements of
40 CFR 75.21 and validated according to
40 CFR 75.23 may be used.
NR 440.20(6)(k)2.c.
c. Use the continuous monitoring system specified under
sub. (7) (k) for measuring and determining gross energy output 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.
NR 440.20(6)(k)2.d.
d. The owner or operator may, in lieu of installing, operating and recording data from the continuous flow monitoring system specified in
sub. (7) (L), determine the mass rate (lb/hr) of NO
x emissions by installing, operating and maintaining continuous fuel flow meters following the appropriate measurements procedures specified in
40 CFR part 75, Appendix D, incorporated by reference in
s. NR 440.17 (1). If this compliance option is selected, the emission rate (E) of NO
x shall be computed using the following equation:
where:
E is the emission rate of NOx from the duct burner, ng/J (lb/Mwh) gross output
ERsg is the average hourly emission rate of NO
x exiting the steam generating unit heat input calculated using appropriate F-factor as described in Method 19 in
40 CFR part 60, Appendix A, incorporated by reference in
s. NR 440.17 (1), ng/J (lb/million Btu)
Hcc is the average hourly heqt input rate of entire combined cycle unit, J/hr (million Btu/hr)
Occ is the average hourly gross energy output from entire combined cycle unit, J(Mwh)
NR 440.20(6)(k)3.
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 do one of the following:
NR 440.20(6)(k)3.a.
a. Determine compliance with the applicable NO
x emissions limits by measuring the emissions combined with the emissions from the other units utilizing the common steam turbine.
NR 440.20(6)(k)3.b.
b. Develop, demonstrate and provide information satisfactory to the department on methods for apportioning the combined gross energy output from the steam turbine for each of the affected duct burners. The department may approve a demonstrated substitute method for apportioning the combined gross energy output measured at the steam turbine whenever the demonstration ensures accurate estimation of emissions regulated under this section.
NR 440.20(7)(a)(a) The owner or operator of an affected facility shall install, calibrate, maintain and operate a continuous monitoring system, and record the output of the system, for measuring the opacity of emissions discharged to the atmosphere, except where gaseous fuel is the only fuel combusted. If opacity interference due to water droplets exists in the stack (for example, from the use of a flue gas desulfurization (FGD) system), the opacity shall be monitored upstream of the interference (at the inlet to the FGD system). If opacity interference is experienced at all locations (both at the inlet and outlet of the sulfur dioxide control system), alternate parameters indicative of the particulate matter control system's performance shall be monitored (subject to the approval of the department).
NR 440.20(7)(b)
(b) The owner or operator of an affected facility shall install, calibrate, maintain and operate a continuous monitoring system, and record the output of the system, for measuring sulfur dioxide emissions, except where natural gas is the only fuel combusted, as follows:
NR 440.20(7)(b)1.
1. Sulfur dioxide emissions shall be monitored at both the inlet and outlet of the sulfur dioxide control device.
NR 440.20(7)(b)2.
2. For a facility which qualifies under the provisions of
sub. (4) (d), sulfur dioxide emissions shall only be monitored as discharged to the atmosphere.
NR 440.20(7)(b)3.
3. An “as fired" fuel monitoring system (upstream of coal pulverizers) meeting the requirements of Method 19,
40 CFR part 60, Appendix A, incorporated by reference in
s. NR 440.17, may be used to determine potential sulfur dioxide emissions in place of a continuous sulfur dioxide emission monitor at the inlet to the sulfur dioxide control device as required under
subd. 1.
NR 440.20(7)(c)1.1. The owner or operator of an affected facility shall install, calibrate, maintain and operate a continuous monitoring system, and record the output of the system for measuring nitrogen oxides emissions discharged to the atmosphere, except as provided in
subd. 2.
NR 440.20(7)(c)2.
2. If the owner or operator has installed a nitrogen oxides emission rate continuous emission monitoring system (CEMS) to meet the requirements of
40 CFR part 75 and is continuing to meet the ongoing requirements of
40 CFR part 75, that CEMS may be used to meet the requirement of this paragraph, except that the owner or operator shall also meet the requirements of
sub. (9). Data reported to meet the requirements of
sub. (9) may not include data substituted using the missing data procedures in
40 CFR part 75, subpart D, nor shall the data have been bias adjusted according to the procedures of
40 CFR part 75.
NR 440.20(7)(d)
(d) The owner or operator of an affected facility shall install, calibrate, maintain and operate a continuous monitoring system, and record the output of the system, for measuring the oxygen or carbon dioxide content of the flue gases at each location where sulfur dioxide or nitrogen oxides emissions are monitored.
NR 440.20(7)(e)
(e) The continuous monitoring systems under
pars. (b),
(c) and
(d) shall be operated and data recorded during all periods of operation of the affected facility including periods of startup, shutdown, malfunction or emergency conditions, except for continuous monitoring system breakdowns, repairs, calibration checks and zero and span adjustments.
NR 440.20(7)(f)
(f) The owner or operator shall obtain emission data for at least 18 hours in at least 22 out of 30 successive boiler operating days. If this minimum data requirement cannot be met with a continuous monitoring system, the owner or operator shall supplement emission data with other monitoring systems approved by the department or the reference methods and procedures as described in
par. (h).
NR 440.20(7)(g)
(g) The one-hour averages required under
s. NR 440.13 (8) shall be expressed in ng/J (lbs/million Btu) heat input and used to calculate the average emission rates under
sub. (6). The one-hour averages shall be calculated using the data points required under
s. NR 440.13 (2). At least 2 data points shall be used to calculate the one-hour averages.
NR 440.20(7)(h)
(h) When it becomes necessary to supplement continuous monitoring system data to meet the minimum data requirements in
par. (f), the owner or operator shall use the reference methods and procedures as specified in this paragraph. Acceptable alternative methods and procedures are given in
par. (j).
NR 440.20(7)(h)1.
1. Method 6 shall be used to determine the SO
2 concentration at the same location as the SO
2 monitor. Samples shall be taken at 60 minute intervals. The sampling time and sample volume for each sample shall be at least 20 minutes and 0.020 dscm (0.71 dscf). Each sample represents a 1-hour average.
NR 440.20(7)(h)2.
2. Method 7 shall be used to determine the NO
x concentration at the same location as the NO
x monitor. Samples shall be taken at 30-minute intervals. The arithmetic average of 2 consecutive samples represent a 1-hour average.
NR 440.20(7)(h)3.
3. The emission rate correction factor, integrated bag sampling and analysis procedure of Method 3B shall be used to determine the O
2 or CO
2 concentration at the same location as the O
2 or CO
2 monitor. Samples shall be taken for at least 30 minutes in each hour. Each sample represents a 1-hour average.
NR 440.20(7)(h)4.
4. The procedures in Method 19 shall be used to compute each 1-hour average concentration in ng/J (lb/million Btu) heat input.
NR 440.20(7)(i)
(i) The owner or operator shall use methods and procedures in this paragraph to conduct monitoring system performance evaluations under
s. NR 440.13 (3) and calibration checks under
s. NR 440.13 (4). Acceptable alternative methods and procedures are given in
par. (j).
NR 440.20(7)(i)1.
1. Methods 3B, 6 and 7 shall be used to determine O
2, SO
2 and NO
x concentrations, respectively.
NR 440.20(7)(i)2.
2. SO
2 or NO
x (NO), as applicable, shall be used for preparing the calibration gas mixtures (in N
2, as applicable) under Performance Specification 2 of Appendix B of
40 CFR part 60, incorporated by reference in
s. NR 440.17.
NR 440.20(7)(i)3.
3. For affected facilities burning only fossil fuel, the span value for a continuous monitoring system for measuring opacity shall be between 60 and 80% and for a continuous monitoring system measuring nitrogen oxides shall be determined as follows:
-
See PDF for table 
where:
