NR 440.50(5)(b)2.2. As specified in s. NR 440.13 (5) (b), during each full unit operating hour, each monitor shall complete a minimum of one cycle of operation (sampling, analyzing and data recording) for each 15-minute quadrant of the hour, to validate the hour. For partial unit operating hours, at least one valid data point shall be obtained for each quadrant of the hour in which the unit operates. For unit operating hours in which required quality assurance and maintenance activities are performed on the CEMS, a minimum of 2 valid data points, one in each of 2 quadrants, are required to validate the hour.
NR 440.50(5)(b)3.3. For purposes of identifying excess emissions, CEMS data shall be reduced to hourly averages as specified in s. NR 440.13 (8).
NR 440.50(5)(b)3.a.a. For each unit operating hour in which a valid hourly average, as described in subd. 2., is obtained for both NOx and diluent, the data acquisition and handling system shall calculate and record the hourly NOx emissions in the units of the applicable NOx emission standard under sub. (3) (a), that is, percent NOx by volume, dry basis, corrected to 15% O2 and International Organization for Standardization (ISO) standard conditions, if required as given in sub. (6) (c) 1. For any hour in which the hourly average O2 concentration exceeds 19.0% O2, a diluent cap value of 19.0% O2 may be used in the emission calculations.
NR 440.50(5)(b)3.b.b. A worst case ISO correction factor may be calculated and applied using historical ambient data. For the purpose of this calculation, substitute the maximum humidity of ambient air (Ho), minimum ambient temperature (Ta), and minimum combustor inlet absolute pressure (Po) into the ISO correction equation.
NR 440.50(5)(b)3.c.c. If the owner or operator has installed a NOx CEMS to meet the requirements of 40 CFR part 75, and is continuing to meet the ongoing requirements of 40 CFR part 75, the CEMS may be used to meet the requirements of this section, except that the missing data substitution methodology provided for at 40 CFR part 75, subpart D, is not required for purposes of identifying excess emissions. Instead, periods of missing CEMS data are to be reported as monitor downtime in the excess emissions and monitoring performance report required in s. NR 440.07 (3).
NR 440.50(5)(c)(c) For any turbine that commenced construction, reconstruction or modification after October 3, 1977, but before July 8, 2004, and which does not use steam or water injection to control NOx emissions, the owner or operator may, for purposes of determining excess emissions, use a CEMS that meets the requirements of par. (b). Also, if the owner or operator has previously submitted and received EPA, department or local permitting authority approval of a petition for an alternative procedure of continuously monitoring compliance with the applicable NOx emission limit under sub. (3), that approved procedure may continue to be used.
NR 440.50(5)(d)(d) The owner or operator of any new turbine constructed after July 8, 2004, and which uses water or steam injection to control NOx emissions may elect to use either the requirements in par. (a) for continuous water or steam to fuel ratio monitoring or may use a NOx CEMS installed, certified, operated, maintained and quality-assured as described in par. (b).
NR 440.50(5)(e)(e) The owner or operator of any new turbine that commences construction after July 8, 2004, and which does not use water or steam injection to control NOx emissions may elect to use a NOx CEMS installed, certified, operated, maintained and quality-assured as described in par. (b). Other acceptable monitoring approaches include periodic testing approved by EPA, the department or local permitting authority or continuous parameter monitoring as described in par. (f).
NR 440.50(5)(f)(f) The owner or operator of a new turbine that commences construction after July 8, 2004, which does not use water or steam injection to control NOx emissions may perform continuous parameter monitoring as follows:
NR 440.50(5)(f)1.1. For a diffusion flame turbine without add-on selective catalytic reduction controls (SCR), the owner or operator shall define at least 4 parameters indicative of the unit’s NOx formation characteristics and shall monitor these parameters continuously.
NR 440.50(5)(f)2.2. For any lean premix stationary combustion turbine, the owner or operator shall continuously monitor the appropriate parameters to determine whether the unit is operating in low-NOx mode.
NR 440.50(5)(f)3.3. For any turbine that uses SCR to reduce NOx emissions, the owner or operator shall continuously monitor appropriate parameters to verify the proper operation of the emission controls.
NR 440.50(5)(f)4.4. For affected units that are also regulated under 40 CFR part 75, if the owner or operator elects to monitor the NOx emission rate using the methodology in Appendix E of 40 CFR part 75, incorporated by reference in s. NR 440.17 (1), or the low mass emissions methodology in 40 CFR 75.19, the requirements of this paragraph may be met by performing the parametric monitoring described in section 2.3 of Appendix E of 40 CFR part 75 or in 40 CFR 75.19 (c) (1) (iv) (H).
NR 440.50(5)(g)(g) The steam or water to fuel ratio or other parameters that are continuously monitored as described in par. (a), (d) or (f) shall be monitored during the performance test required under s. NR 440.08, to establish acceptable values and ranges. The owner or operator may supplement the performance test data with engineering analyses, design specifications, manufacturer’s recommendations and other relevant information to define the acceptable parametric ranges more precisely. The owner or operator shall develop and keep on-site a parameter monitoring plan which explains the procedures used to document proper operation of the NOx emission controls. The plan shall include the parameters monitored and the acceptable ranges of the parameters as well as the basis for designating the parameters and acceptable ranges. Any supplemental data such as engineering analyses, design specifications, manufacturer’s recommendations and other relevant information shall be included in the monitoring plan. For affected units that are also subject to 40 CFR part 75 and that use the low mass emissions methodology in 40 CFR 75.19 or the NOx emission measurement methodology in Appendix E of 40 CFR part 75, the owner or operator may meet the requirements of this paragraph by developing and keeping on-site (or at a central location for unmanned facilities) a quality-assurance plan, as described in 40 CFR 75.19 (e) (5) or in section 2.3 of Appendix E and section 1.3.6 of Appendix B of 40 CFR part 75, both incorporated by reference in s. NR 440.17 (1).
NR 440.50(5)(h)(h) The owner or operator of any stationary gas turbine subject to the provisions of this section:
NR 440.50(5)(h)1.1. Shall monitor the total sulfur content of the fuel being fired in the turbine, except as provided in subd. 3. The sulfur content of the fuel shall be determined using total sulfur methods described in sub. (6) (d). Alternatively, if the total sulfur content of the gaseous fuel during the most recent performance test was less than 0.4 weight percent (4000 ppmw), ASTM D4084-94, D5504-01, D6228-98, or Gas Processors Association Standard 2377-86, incorporated by reference in s. NR 440.17 (2) (a) 52., 64. and 68. and (m). respectively, which measure the major sulfur compounds may be used.
NR 440.50(5)(h)2.2. Shall monitor the nitrogen content of the fuel combusted in the turbine, if the owner or operator claims an allowance for fuel bound nitrogen, that is, if an F-value greater than zero is being or will be used by the owner or operator to calculate STD in sub. (3). The nitrogen content of the fuel shall be determined using methods described in sub. (6) (c) 9. or an approved alternative.
NR 440.50(5)(h)3.3. Notwithstanding the provisions of subd. 1., the owner or operator may elect not to monitor the total sulfur content of the gaseous fuel combusted in the turbine, if the gaseous fuel is demonstrated to meet the definition of natural gas in sub. (2) (L), regardless of whether an existing custom schedule approved by the department for this section requires the monitoring. The owner or operator shall use one of the following sources of information to make the required demonstration:
NR 440.50(5)(h)3.a.a. The gas quality characteristics in a current, valid purchase contract, tariff sheet or transportation contract for the gaseous fuel, specifying that the maximum total sulfur content of the fuel is 20.0 grains/100 scf or less.
NR 440.50(5)(h)3.b.b. Representative fuel sampling data which show that the sulfur content of the gaseous fuel does not exceed 20 grains/100 scf. At a minimum, the amount of fuel sampling data specified in section 2.3.1.4 or 2.3.2.4 of Appendix D to 40 CFR part 75, incorporated by reference in s. NR 440.17 (1), is required.
NR 440.50(5)(h)4.4. For any turbine that commenced construction, reconstruction or modification after October 3, 1977, but before July 8, 2004, and for which a custom fuel monitoring schedule has previously been approved, the owner or operator may, without submitting a special petition to the department, continue monitoring on this schedule.
NR 440.50(5)(i)(i) The frequency of determining the sulfur and nitrogen content of the fuel shall be as follows:
NR 440.50(5)(i)1.1. ’Fuel oil.’ For fuel oil, use one of the total sulfur sampling options and the associated sampling frequency described in sections 2.2.3, 2.2.4.1, 2.2.4.2, and 2.2.4.3 of Appendix D to 40 CFR part 75, incorporated by reference in s. NR 440.17 (1), that is, flow proportional sampling, daily sampling, sampling from the unit’s storage tank after each addition of fuel to the tank, or sampling each delivery prior to combining it with fuel oil already in the intended storage tank. If an emission allowance is being claimed for fuel-bound nitrogen, the nitrogen content of the oil shall be determined and recorded once per unit operating day.
NR 440.50(5)(i)2.2. ’Gaseous fuel.’ Any applicable nitrogen content value of the gaseous fuel shall be determined and recorded once per unit operating day. For owners and operators that elect not to demonstrate sulfur content using options in par. (h) 3., and for which the fuel is supplied without intermediate bulk storage, the sulfur content value of the gaseous fuel shall be determined and recorded once per unit operating day.
NR 440.50(5)(i)3.3. ’Custom schedules.’ Notwithstanding the requirements of subd. 2., operators or fuel vendors may develop custom schedules for determination of the total sulfur content of gaseous fuels, based on the design and operation of the affected facility and the characteristics of the fuel supply. Except as provided in subd. 3. a. and b., custom schedules shall be substantiated with data and shall be approved by the department before they can be used to comply with the standard in sub. (4).
NR 440.50(5)(i)3.a.a. The 2 custom sulfur monitoring schedules set forth in subd. 3 .a. 1) to 4) and in subd. 3. b. are acceptable, without prior department approval:
1) The owner or operator shall obtain daily total sulfur content measurements for 30 consecutive unit operating days, using the applicable methods specified in this section. Based on the results of the 30 daily samples, the required frequency for subsequent monitoring of the fuel’s total sulfur content shall be as specified in subd. 3. a. 2), 3) or 4), as applicable.
2) If none of the 30 daily measurements of the fuel’s total sulfur content exceeds 0.4 weight percent (4000 ppmw), subsequent sulfur content monitoring may be performed at 12-month intervals. If any of the samples taken at 12-month intervals has a total sulfur content between 0.4 and 0.8 weight percent (4000 and 8000 ppmw), follow the procedures in subd. 3. a. 3). If any measurement exceeds 0.8 weight percent (8000 ppmw), follow the procedures in subd. 3. a. 4).
3) If at least one of the 30 daily measurements of the fuel’s total sulfur content is between 0.4 and 0.8 weight percent (4000 and 8000 ppmw), but none exceeds 0.8 weight percent (8000 ppmw), then: