NR 440.207(6)(a)3.b.b. Method 17 may be used at affected facilities with or without wet scrubber systems provided the stack gas temperature does not exceed a temperature of 160°C (320°F). The procedures of Sections 8.1 and 11.1 of Method 5B may be used in Method 17 only if Method 17 is used in conjunction with a wet scrubber system. Method 17 may not be used in conjunction with a wet scrubber system if the emissions are saturated or laden with water droplets. NR 440.207(6)(a)4.4. The sampling time for each run shall be at least 120 minutes and the minimum sampling volume shall be 1.7 dscm (60 dscf) except that smaller sampling times or volumes may be approved by the department when necessitated by process variables or other factors. NR 440.207(6)(a)5.5. For Method 5 or Method 5B, the temperature of the sample gas in the probe and filter holder shall be monitored and maintained at 160 ± 14°C (320 ± 25°F). NR 440.207(6)(a)6.6. For determination of PM emissions, an oxygen or carbon dioxide measurement shall be obtained simultaneously with each run of Method 5, Method 5B or Method 17 by traversing the duct at the same sampling location. NR 440.207(6)(a)7.7. For each run using Method 5, Method 5B or Method 17, the emission rates expressed in ng/J (lb/million Btu) heat input shall be determined using: NR 440.207(6)(a)7.a.a. The oxygen or carbon dioxide measurements and PM measurements obtained under this subsection, NR 440.207(6)(a)8.8. Method 9 (6-minute average of 24 observations) shall be used for determining the opacity of stack emissions. NR 440.207(6)(b)(b) The owner or operator of an affected facility seeking to demonstrate compliance with the PM standards under sub. (4) (b) 2. shall demonstrate the maximum design heat input capacity of the steam generating unit by operating the steam generating unit at this capacity for 24 hours. This demonstration shall be made during the initial performance test, and a subsequent demonstration may be requested at any other time. If the demonstrated 24-hour average firing rate for the affected facility is less than the maximum design heat input capacity stated by the manufacturer of the affected facility, the demonstrated 24-hour average firing rate shall be used to the determine annual capacity factor for the affected facility; otherwise, the maximum design heat input capacity provided by the manufacturer shall be used. NR 440.207(7)(a)(a) Except as provided in pars. (d) and (e), the owner or operator of an affected facility subject to the SO2 emission limits under sub. (3) shall install, calibrate, maintain and operate a CEMS for measuring SO2 concentrations and either oxygen or carbon dioxide concentrations at the outlet of the SO2 control device (or the outlet of the steam generating unit if no SO2 control device is used), and shall record the output of the system. The owner or operator of an affected facility subject to the percent reduction requirements under sub. (3) shall measure SO2 concentrations and either oxygen or carbon dioxide concentrations at both the inlet and outlet of the SO2 control device. NR 440.207(7)(b)(b) The 1-hour average SO2 emission rates measured by a CEMS 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 SO2 emission rate shall be based on at least 30 minutes of operation and include at least 2 data points representing 2 15-minute periods. Hourly SO2 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 440.207(7)(c)(c) The procedure under s. NR 440.13 shall be followed for installation, evaluation and operation of the CEMS. NR 440.207(7)(c)1.1. All CEMS shall be operated in accordance with the applicable procedures under Performance Specifications 1, 2 and 3 of 40 CFR part 60 Appendix B, incorporated by reference in s. NR 440.17. NR 440.207(7)(c)2.2. Quarterly accuracy determinations and daily calibration drift tests shall be performed in accordance with Procedure 1 of 40 CFR part 60 Appendix F, incorporated by reference in s. NR 440.17. NR 440.207(7)(c)3.3. For affected facilities subject to the percent reduction requirements under sub. (3), the span value of the SO2 CEMS at the inlet to the SO2 control device shall be 125% of the maximum estimated hourly potential SO2 emission rate of the fuel combusted, and the span value of the SO2 CEMS at the outlet from the SO2 control device shall be 50% of the maximum estimated hourly potential SO2 rate of the fuel combusted. NR 440.207(7)(c)4.4. For affected facilities that are not subject to the percent reduction requirements of sub. (3), the span value of the SO2 CEMS at the outlet from the SO2 control device, or outlet of the steam generating unit if no SO2 control device is used, shall be 125% of the maximum estimated hourly potential SO2 emission rate of the fuel combusted. NR 440.207(7)(d)(d) As an alternative to operating a CEMS at the inlet to the SO2 control device, or outlet of the steam generating unit if no SO2 control device is used, as required under par. (a), an owner or operator may elect to determine the average SO2 emission rate by sampling the fuel prior to combustion. As an alternative to operating a CEMS at the outlet from the SO2 control device, or outlet of the steam generating unit if no SO2 control device is used, as required under par. (a), an owner or operator may elect to determine the average SO2 emission rate by using Method 6B. Fuel sampling shall be conducted pursuant to either subd. 1. or 2. Method 6B shall be conducted pursuant to subd. 3. NR 440.207(7)(d)1.1. For affected facilities combusting coal or oil, coal or oil samples shall be collected daily in an as-fired condition at the inlet to the steam generating unit and analyzed for sulfur content and heat content according to Method 19. Method 19 provides procedures for converting these measurements into the format to be used in calculating the average SO2 input rate. NR 440.207(7)(d)2.2. As an alternative fuel sampling procedure for affected facilities combusting oil, oil samples may be collected from the fuel tank for each steam generating unit immediately after the fuel tank is filled and before any oil is combusted. The owner or operator of an affected facility shall analyze the oil sample to determine the sulfur content of the oil. If a partially empty fuel tank is refilled, a new sample and analysis of the fuel in the tank is required upon filling. Results of the fuel analysis taken after each new shipment of oil is received shall be used as the daily value when calculating the 30-day rolling average until the next shipment is received. If the fuel analysis shows that the sulfur content in the fuel tank is greater than 0.5 weight percent sulfur, the owner or operator shall ensure that the sulfur content of subsequent oil shipments is low enough to cause the 30-day rolling average sulfur content to be 0.5 weight percent sulfur or less. NR 440.207(7)(d)3.3. Method 6B may be used in lieu of CEMS to measure SO2 at the inlet or outlet of the SO2 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 SO2 and carbon dioxide measurement train operated at the candidate location and a second similar train operated according to the procedures in s. 3.2 and the applicable procedures in section 7 of Performance Specification 2 of 40 CFR part 60 Appendix B, incorporated by reference in s. NR 440.17. Method 6B, Method 6A or a combination of Methods 6 and 3 or Methods 6C and 3A 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, then the mean of the absolute difference between the 3 paired runs shall be less than 10% (0.10). NR 440.207(7)(e)(e) The monitoring requirements of pars. (a) and (d) do not apply to affected facilities subject to sub. (3) (h) 1., 2. or 3. where the owner or operator of the affected facility seeks to demonstrate compliance with the SO2 standards based on fuel supplier certification, or as described under sub. (9) (f) 1., 2. or 3., as applicable. NR 440.207(7)(f)(f) The owner or operator of an affected facility operating a CEMS pursuant to par. (a), or conducting as-fired fuel sampling pursuant to par. (d) 1., shall obtain emission data for at least 75% of the operating hours in at least 22 out of 30 successive steam generating unit 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. NR 440.207(8)(a)(a) The owner or operator of an affected facility combusting coal, residual oil or wood that is subject to the opacity standards under sub. (4) shall install, calibrate, maintain and operate a CEMS for measuring the opacity of the emissions discharged to the atmosphere and record the output of the system. NR 440.207(8)(b)(b) All CEMS for measuring opacity shall be operated in accordance with the applicable procedures under Performance Specification 1 of 40 CFR part 60 Appendix B, incorporated by reference in s. NR 440.17. The span value of the opacity CEMS shall be between 60 and 80%.