Esg is the combined effluent emissions rate, in ng/J (lb/million Btu) heat input using appropriate F-Factor as described in Method 19
Hg is the heat input rate to the combustion turbine, in Joules/hour (million Btu/hour)
Hb is the heat input rate to the duct burner, in Joules/hour (million Btu/hour)
Eg is the emissions rate from the combustion turbine, in ng/J (lb/million Btu) heat input calculated using appropriate F-Factor as described in Method 19
NR 440.205(7)(f)1.b.b. Method 7E shall be used to determine the NOx concentrations. Method 3A or 3B shall be used to determine oxygen concentration. NR 440.205(7)(f)1.c.c. The owner or operator shall identify and demonstrate to the department’s satisfaction suitable methods to determine the average hourly heat input rate to the combustion turbine and the average hourly heat input rate to the affected duct burner. NR 440.205(7)(f)1.d.d. Compliance with the emissions limits under sub. (5) (a) 4. or (L) shall be determined by the 3-run average (nominal 1-hour runs) for the initial and subsequent performance tests. NR 440.205(7)(f)2.2. The owner or operator of an affected facility may elect to determine compliance on a 30-day rolling average basis by using the continuous emission monitoring system specified under sub. (9) for measuring NOx and oxygen and meet the requirements of sub. (9). The sampling site shall be located at the outlet from the steam generating unit. The NOx emissions rate at the outlet from the steam generating unit shall constitute the NOx emissions rate from the duct burner of the combined cycle system. NR 440.205(7)(g)(g) The owner or operator of an affected facility described in sub. (5) (j) or (k) shall demonstrate the maximum heat input capacity of the steam generating unit by operating the facility at maximum capacity for 24 hours. The owner or operator of an affected facility shall determine the maximum heat input capacity using the heat loss method described in Sections 5 and 7.3 of the ASME Power Test Codes 4.1, incorporated by reference in s. NR 440.17. This demonstration of maximum heat input capacity shall be made during the initial performance test for affected facilities that meet the criteria of sub. (5) (j). It shall be made 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 each facility, for affected facilities meeting the criteria of sub. (5) (k). Subsequent demonstrations may be required by the department at any other time. If this demonstration indicates that the maximum heat input capacity of the affected facility is less than that stated by the manufacturer of the affected facility, the maximum heat input capacity determined during this demonstration shall be used to determine the capacity utilization rate for the affected facility. Otherwise, the maximum heat input capacity provided by the manufacturer is used. NR 440.205(7)(h)(h) The owner or operator of an affected facility described in sub. (5) (j) that has a heat input capacity greater than 73 MW (250 million Btu/hour) shall: NR 440.205(7)(h)1.1. Conduct an initial performance test as required under s. NR 440.08 over a minimum of 24 consecutive steam generating unit operating hours at maximum heat input capacity to demonstrate compliance with the nitrogen oxides emission standards under sub. (5) using Method 7, 7A or 7E of 40 CFR part 60, Appendix A, incorporated by reference in s. NR 440.17, or other approved reference methods; and NR 440.205(7)(h)2.2. Conduct subsequent performance tests once per calendar year or every 400 hours or operation (whichever comes first) to demonstrate compliance with the nitrogen oxides emission standards under sub. (5) over a minimum of 3 consecutive steam generating unit operating hours at maximum heat input capacity using Method 7, 7A, 7E or other approved reference methods. NR 440.205(8)(a)(a) Except as provided in pars. (b) and (f), the owner or operator of an affected facility subject to the sulfur dioxide standards under sub. (3) shall install, calibrate, maintain, and operate continuous emission monitoring systems (CEMS) for measuring sulfur dioxide concentrations and either oxygen (O2) or carbon dioxide (CO2) concentrations and shall record the output of the systems. The sulfur dioxide and either oxygen or carbon dioxide concentrations shall both be monitored at the inlet and outlet of the sulfur dioxide control device. NR 440.205(8)(b)(b) As an alternative to operating CEMS as required under par. (a), an owner or operator may elect to determine the average sulfur dioxide emissions and percent reduction by: NR 440.205(8)(b)1.1. Collecting coal or oil samples in an as-fired condition at the inlet to the steam generating unit and analyzing them for sulfur and heat content according to Method 19 of Appendix A, 40 CFR part 60, incorporated by reference in s. NR 440.17. Method 19 provides procedures for converting these measurements into the format to be used in calculating the average sulfur dioxide input rate, or NR 440.205(8)(b)2.2. Measuring sulfur dioxide according to Method 6B of Appendix A, 40 CFR part 60, incorporated by reference in s. NR 440.17, at the inlet or outlet to the sulfur dioxide control system. An initial stratification test is required to verify the adequacy of the Method 6B sampling location. The stratification test shall consist of 3 paired runs of a suitable sulfur dioxide and carbon dioxide measurement train operated at the candidate location and a second similar train operated according to the procedures in Section 3.2 and the applicable procedures in Section 7 of Performance Specification 2 of Appendix B, 40 CFR part 60, incorporated by reference in s. NR 440.17. Method 6B, Method 6A, or a combination of Methods 6 and 3 or 3B or Methods 6C and 3A, all in Appendix A of 40 CFR part 60, incorporated by reference in s. NR 440.17, are suitable measurement techniques. If Method 6B is used for the second train, sampling time and timer operation may be adjusted for the stratification test as long as an adequate sample volume is collected; however, both sampling trains are to be operated similarly. For the location to be adequate for Method 6B 24-hour tests, the mean of the absolute difference between the 3 paired runs shall be less than 10%. NR 440.205(8)(b)3.3. A daily sulfur dioxide emission rate, ED, shall be determined using the procedure described in Method 6A, Section 7.6.2 (equation 6A-8) and stated in ng/J (lb/million Btu) heat input. NR 440.205(8)(b)4.4. The mean 30-day emission rate is calculated using the daily measured values in ng/J (lb/million Btu) for 30 successive steam generating unit operating days using equation 19-20 of Method 19. NR 440.205(8)(c)(c) The owner or operator of an affected facility shall obtain emission data for at least 75% of the operating hours in at least 22 out of 30 successive boiler operating days. If this minimum data requirement is not met with a single monitoring system, the owner or operator of the affected facility shall supplement the emission data with data collected with other monitoring systems as approved by the department or the reference methods and procedures as described in par. (b). NR 440.205(8)(d)(d) The 1-hour average sulfur dioxide emission rates measured by the CEMS required by par. (a) and required under s. NR 440.13 (8) shall be expressed in ng/J or lb/million Btu heat input and shall be used to calculate the average emission rates under sub. (3). Each 1-hour average sulfur dioxide emission rate shall be based on more than 30 minutes of steam generating unit operation and include at least 2 data points with each representing a 15-minute period. Hourly sulfur dioxide emission rates are not calculated if the affected facility is operated less than 30 minutes in a 1-hour period and are not counted toward determination of a steam generating unit operating day. NR 440.205(8)(e)(e) The procedures in s. NR 440.13 shall be followed for installation, evaluation, and operation of the CEMS. NR 440.205(8)(e)1.1. All CEMS shall be operated in accordance with the applicable procedures under Performance Specifications 1, 2, and 3, Appendix B, 40 CFR part 60, incorporated by reference in s. NR 440.17. NR 440.205(8)(e)2.2. Quarterly accuracy determinations and daily calibration drift tests shall be performed in accordance with Procedure 1 of Appendix F, 40 CFR part 60, incorporated by reference in s. NR 440.17. NR 440.205(8)(e)3.3. For affected facilities combusting coal or oil, alone or in combination with other fuels, the span value of the sulfur dioxide CEMS at the inlet to the sulfur dioxide control device shall be 125% of the maximum estimated hourly potential sulfur dioxide emissions of the fuel combusted, and the span value of the CEMS at the outlet to the sulfur dioxide control device shall be 50% of the maximum estimated hourly potential sulfur dioxide emissions of the fuel combusted. NR 440.205(8)(f)(f) The owner or operator of an affected facility that combusts very low sulfur oil is not subject to the emission monitoring requirements of this subsection if the owner or operator obtains fuel receipts as described in sub. (10) (r). NR 440.205(9)(9) Emission monitoring for particulate matter and nitrogen oxides. NR 440.205(9)(a)(a) The owner or operator of an affected facility subject to the opacity standard under sub. (4) shall install, calibrate, maintain, and operate a continuous monitoring system for measuring the opacity of emissions discharged to the atmosphere and record the output of the system. NR 440.205(9)(b)(b) Except as provided under pars. (g), (h) and (i), the owner or operator of an affected facility shall comply with one of the following: NR 440.205(9)(b)1.1. 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. NR 440.205(9)(b)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 requirements of this subsection, except that the owner or operator shall also meet the requirements of sub. (10). Data reported to meet the requirements of sub. (10) 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 440.205(9)(c)(c) The continuous monitoring systems required under par. (b) shall be operated and data recorded during all periods of operation of the affected facility except for continuous monitoring system breakdowns and repairs. Data shall be recorded during calibration checks, and zero and span adjustments. NR 440.205(9)(d)(d) The 1-hour average nitrogen oxides emission rates measured by the continuous nitrogen oxides monitor required by par. (b) and required under s. NR 440.13 shall be expressed in ng/J or lb/million Btu heat input and shall be used to calculate the average emission rates under sub. (5). The 1-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 each 1-hour average. NR 440.205(9)(e)(e) The procedures under s. NR 440.13 shall be followed for installation, evaluation, and operation of the continuous monitoring systems. NR 440.205(9)(e)1.1. For affected facilities combusting coal, wood or municipal-type solid waste, the span value for a continuous monitoring system for measuring opacity shall be between 60 and 80%. NR 440.205(9)(e)2.2. For affected facilities combusting coal, oil, or natural gas, the span value for nitrogen oxides is determined as follows: where:
x is the fraction of total heat input derived from natural gas
y is the fraction of total heat input derived from oil
z is the fraction of total heat input derived from coal
NR 440.205(9)(e)3.3. All span values computed under subd. 2. for combusting mixtures of regulated fuels shall be rounded to the nearest 500 PPM. NR 440.205(9)(f)(f) When nitrogen oxides emission data are not obtained because of continuous monitoring system breakdowns, repairs, calibration checks and zero and span adjustments, emission data will be obtained by using standby monitoring systems, Method 7 or 7A of Appendix A, 40 CFR part 60, incorporated by reference in s. NR 440.17, or other approved reference methods to provide emission data for a minimum of 75% of the operating hours in each steam generating unit operating day, in at least 22 out of 30 successive steam generating unit operating days. NR 440.205(9)(g)(g) The owner or operator of an affected facility that has a heat input capacity of 73 MW (250 million Btu/hour) or less, and which has an annual capacity factor for residual oil having a nitrogen content of 0.30 weight % or less, natural gas, distillate oil, or any mixture of these fuels, greater than 10% (0.10) shall: NR 440.205(9)(g)2.2. Monitor steam generating unit operating conditions and predict nitrogen oxides emission rates as specified in a plan submitted pursuant to sub. (10) (c). NR 440.205(9)(h)(h) The owner or operator of a duct burner, as described in sub. (2) (j), which is subject to the NOx standards of sub. (5) (a) 4. or (L), is not required to install or operate a continuous emissions monitoring system to measure NOx emissions. NR 440.205(9)(i)(i) The owner or operator of an affected facility described under sub. (5) (j) or (k) is not required to install or operate a continuous monitoring system for measuring nitrogen oxide emissions. NR 440.205(10)(a)(a) The owner or operator of each affected facility shall submit notification of the date of initial startup, as provided by s. NR 440.07. This notification shall include: NR 440.205(10)(a)1.1. The design heat input capacity of the affected facility and identification of the fuels to be combusted in the affected facility, NR 440.205(10)(a)2.2. If applicable, a copy of any federally enforceable requirement that limits the annual capacity factor for any fuel or mixture of fuels under subs. (3) (d) 1., (4) (a) 2., 3. c., (c) 2. b., (d) 2. c., (5) (c), (d), (e), (i), (j) or (k), (6) (d), (7) (g) or (h), or (9) (i), NR 440.205(10)(a)3.3. The annual capacity factor at which the owner or operator anticipates operating the facility based on all fuels fired and based on each individual fuel fired, and NR 440.205(10)(a)4.4. Notification that an emerging technology will be used for controlling emissions of sulfur dioxide. The administrator will examine the description of the emerging technology and will determine whether the technology qualifies as an emerging technology. In making this determination, the administrator may require the owner or operator of the affected facility to submit additional information concerning the control device. The affected facility is subject to the provisions of sub. (3) (a) unless and until this determination is made by the administrator. NR 440.205(10)(b)(b) The owner or operator of each affected facility subject to the sulfur dioxide, particulate matter, or nitrogen oxides emission limits under subs. (3), (4), and (5) shall submit to the department the performance test data from the initial performance test and the performance evaluation of the CEMS using the applicable performance specifications in Appendix B, 40 CFR part 60, incorporated by reference in s. NR 440.17. The owner or operator of each affected facility described in sub. (5) (j) or (k) shall submit to the department the maximum heat input capacity data from the demonstration of the maximum heat input capacity of the affected facility. NR 440.205(10)(c)(c) The owner or operator of each affected facility subject to the nitrogen oxides standard of sub. (5) who seeks to demonstrate compliance with those standards through the monitoring of steam generating unit operating conditions under the provisions of sub. (9) (g) 2. shall submit to the department for approval a plan that identifies the operating conditions to be monitored under sub. (9) (g) 2. and the records to be maintained under par. (j). This plan shall be submitted to the department for approval within 360 days of the initial startup of the affected facility. The plan shall: NR 440.205(10)(c)1.1. Identify the specific operating conditions to be monitored and the relationship between these operating conditions and nitrogen oxides emission rates (i.e., ng/J or lbs/million Btu heat input). Steam generating unit operating conditions include, but are not limited to, the degree of staged combustion (i.e., the ratio of primary air to secondary and/or tertiary air) and the level of excess air (i.e., flue gas oxygen level); NR 440.205(10)(c)2.2. Include the data and information that the owner or operator used to identify the relationship between nitrogen oxides emission rates and these operating conditions; NR 440.205(10)(c)3.3. Identify how these operating conditions, including steam generating unit load, will be monitored under sub. (9) (g) on an hourly basis by the owner or operator during the period of operation of the affected facility; the quality assurance procedures or practices that will be employed to ensure that the data generated by monitoring these operating conditions will be representative and accurate; and the type and format of the records of these operating conditions, including steam generating unit load, that will be maintained by the owner or operator under par. (j). If the plan is approved, the owner or operator shall maintain records of predicted nitrogen oxide emission rates and the monitored operating conditions, including steam generating unit load, identified in the plan. NR 440.205(10)(d)(d) The owner or operator of an affected facility shall record and maintain records of the amounts of each fuel combusted during each day and calculate the annual capacity factor individually for coal, distillate oil, residual oil, natural gas, wood, and municipal-type solid waste for the reporting period. The annual capacity factor is determined on a 12-month rolling average basis with a new annual capacity factor calculated at the end of each calendar month. NR 440.205(10)(e)(e) For an affected facility that combusts residual oil and meets the criteria under sub. (5) (j) or (k) or (7) (e) 4., the owner or operator shall maintain records of the nitrogen content of the residual oil combusted in the affected facility and calculate the average fuel nitrogen content for the reporting period. The nitrogen content shall be determined using ASTM method D3431-80 (reapproved 1987), Test Method for Trace Nitrogen in Liquid Petroleum Hydrocarbons, incorporated by reference in s. NR 440.17 (2) (a) 48., or fuel specification data obtained from fuel suppliers. If residual oil blends are being combusted, fuel nitrogen specifications may be prorated based on the ratio of residual oils of different nitrogen content in the fuel blend. NR 440.205(10)(f)(f) For facilities subject to the opacity standard under sub. (4), the owner or operator shall maintain records of opacity. NR 440.205(10)(g)(g) Except as provided under par. (p), the owner or operator of an affected facility subject to nitrogen oxides standards under sub. (5) shall maintain records of the following information for each steam generating unit operating day: NR 440.205(10)(g)2.2. The average hourly nitrogen oxides emission rates (expressed as NO2) (ng/J or lb/million Btu heat input) measured or predicted. NR 440.205(10)(g)3.3. The 30-day average nitrogen oxides emission rates (ng/J or lb/million Btu heat input) calculated at the end of each steam generating unit operating day from the measured or predicted hourly nitrogen oxide emission rates for the preceding 30 steam generating unit operating days. NR 440.205(10)(g)4.4. Identification of the steam generating unit operating days when the calculated 30-day average nitrogen oxides emission rates are in excess of the nitrogen oxides emissions standards under sub. (5), with the reasons for such excess emissions as well as a description of corrective actions taken. NR 440.205(10)(g)5.5. Identification of the steam generating unit operating days for which pollutant data have not been obtained, including reasons for not obtaining sufficient data and a description of corrective actions taken. NR 440.205(10)(g)6.6. Identification of the times when emission data have been excluded from the calculation of average emission rates and the reasons for excluding data. NR 440.205(10)(g)7.7. Identification of “F” factor used for calculations, method of determination, and type of fuel combusted. NR 440.205(10)(g)8.8. Identification of the times when the pollutant concentration exceeded full span of the continuous monitoring system. NR 440.205(10)(g)9.9. Description of any modifications to the continuous monitoring system that could affect the ability of the continuous monitoring system to comply with Performance Specification 2 or 3 of Appendix B, 40 CFR part 60, incorporated by reference in s. NR 440.17. NR 440.205(10)(h)(h) The owner or operator of any affected facility in any category listed in subd. 1. or 2. is required to submit excess emission reports to the department for any excess emissions which occurred during the reporting period. NR 440.205(10)(h)2.2. Any affected facility which is subject to the nitrogen oxides standard of sub. (5), and that: NR 440.205(10)(h)2.a.a. Combusts natural gas, distillate oil, or residual oil with a nitrogen content of 0.3 weight % or less, or NR 440.205(10)(h)2.b.b. Has a heat input capacity of 73 MW (250 million Btu/hour) or less and is required to monitor nitrogen oxides emissions on a continuous basis under sub. (9) (g) 1. or steam generating unit operating conditions under sub. (9) (g) 2. NR 440.205(10)(h)3.3. For the purpose of sub. (4), excess emissions are defined as all 6-minute periods during which the average opacity exceeds the opacity standards under sub. (4) (f). NR 440.205(10)(h)4.4. For purposes of sub. (9) (g) 1., excess emissions are defined as any calculated 30-day rolling average nitrogen oxides emission rate, as determined under sub. (7) (e), which exceeds the applicable emission limits in sub. (5). NR 440.205(10)(i)(i) The owner or operator of any affected facility subject to the continuous monitoring requirements for nitrogen oxides under sub. (9) shall submit reports to the department containing the information recorded under par. (g). NR 440.205(10)(j)(j) The owner or operator of any affected facility subject to the sulfur dioxide standards under sub. (3) shall submit reports to the department. NR 440.205(10)(k)(k) For each affected facility subject to the compliance and performance testing requirements of sub. (6) and the reporting requirement in par. (j) the following information shall be reported to the department: NR 440.205(10)(k)2.2. Each 30-day average sulfur dioxide emission rate (ng/J or lb/million Btu heat input) measured during the reporting period, ending with the last 30-day period; reasons for noncompliance with the emission standards; and a description of corrective actions taken. NR 440.205(10)(k)3.3. Each 30-day average percent reduction in sulfur dioxide emissions calculated during the reporting period, ending with the last 30-day period; reasons for noncompliance with the emission standards; and a description of corrective actions taken. NR 440.205(10)(k)4.4. Identification of the steam generating unit operating days that coal or oil was combusted and for which sulfur dioxide or diluent (oxygen or carbon dioxide) data have not been obtained by an approved method for at least 75% of the operating hours in the steam generating unit operating day; justification for not obtaining sufficient data; and description of corrective action taken. NR 440.205(10)(k)5.5. Identification of the times when emissions data have been excluded from the calculation of average emission rates; justification for excluding data; and description of corrective action taken if data have been excluded for periods other than those during which coal or oil were not combusted in the steam generating unit. NR 440.205(10)(k)6.6. Identification of “F” factor used for calculations, method of determination, and type of fuel combusted. NR 440.205(10)(k)7.7. Identification of times when hourly averages have been obtained based on manual sampling methods.
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Chs. NR 400-499; Environmental Protection – Air Pollution Control
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