NR 440.185(6)(b)(b) An owner or operator shall request the adjustment provided for in par. (c) or (d) for each change of an applicable time period or postmark deadline specified in this chapter. NR 440.185(6)(c)(c) Notwithstanding time periods or postmark deadlines specified in this chapter for submittal of information, or the review of information by the department, time periods or postmark deadlines may be changed by mutual agreement between the owner or operator and the department. An owner or operator wishing to request a change in a time period or postmark deadline for a particular requirement shall request the adjustment in writing as soon as practicable before the subject activity is required to take place. The owner or operator shall include in the request whatever information is considered useful to convince the department that an adjustment is warranted. NR 440.185(6)(d)(d) If, in the department’s judgement, an owner or operator’s request for an adjustment to a particular time period or postmark deadline is warranted, the department shall approve the adjustment. The department shall notify the owner or operator in writing of approval or disapproval of the request for an adjustment within 15 calendar days of receiving sufficient information to evaluate the request. NR 440.185(6)(e)(e) If the department is unable to meet a specified deadline, the department shall notify the owner or operator of any significant delay and inform the owner or operator of the amended schedule. NR 440.185 HistoryHistory: CR 06-109: cr. Register May 2008 No. 629, eff. 6-1-08. NR 440.19NR 440.19 Fossil-fuel-fired steam generators for which construction is commenced after August 17, 1971. NR 440.19(1)(1) Applicability and designation of affected facility. NR 440.19(1)(a)(a) The affected facilities to which the provisions of this section apply are: NR 440.19(1)(a)1.1. Each fossil-fuel-fired steam generating unit of more than 73 megawatts heat input rate (250 million Btu per hour). NR 440.19(1)(a)2.2. Each fossil-fuel and wood-residue-fired steam generating unit capable of firing fossil fuel at a heat input rate of more than 73 megawatts (250 million Btu per hour). NR 440.19(1)(b)(b) Any change to an existing fossil-fuel-fired steam generating unit to accommodate the use of combustible materials other than fossil fuels as defined in this section does not bring that unit under the applicability of this section. NR 440.19(1)(c)(c) Except as provided in par. (d), any facility under par. (a) that commenced construction or modification after August 17, 1971, is subject to the requirements of this section. NR 440.19(2)(2) Definitions. As used in this section, terms not defined in this subsection have the meanings given in s. NR 440.02. NR 440.19(2)(a)(a) “Coal” means all solid fuels classified as anthracite, bituminous, subbituminous, or lignite by ASTM D388-99 (reapproved 2004), incorporated by reference in s. NR 440.17 (2) (a) 12. NR 440.19(2)(b)(b) “Coal refuse” means waste-products of coal mining, cleaning and coal preparation operations (e.g. culm, gob, etc.) containing coal, matrix material, clay and other organic and inorganic material. NR 440.19(2)(c)(c) “Fossil fuel” means natural gas, petroleum, coal and any form of solid, liquid or gaseous fuel derived from such materials for the purpose of creating useful heat. NR 440.19(2)(d)(d) “Fossil-fuel and wood-residue-fired steam generating unit” means a furnace or boiler used in the process of burning fossil fuel and wood residue for the purpose of producing steam by heat transfer. NR 440.19(2)(e)(e) “Fossil-fuel-fired steam generating unit” means a furnace or boiler used in the process of burning fossil fuel for the purpose of producing steam by heat transfer. NR 440.19(2)(f)(f) “Wood residue” means bark, sawdust, slabs, chips, shavings, mill trim and other wood products derived from wood processing and forest management operations. NR 440.19(3)(a)(a) On and after the date on which the performance test required to be conducted by s. NR 440.08 is completed, no owner or operator subject to the provisions of this section may cause to be discharged into the atmosphere from any affected facility any gases which: NR 440.19(3)(a)1.1. Contain particulate matter in excess of 43 nanograms per joule heat input (0.10 lb per million Btu) derived from fossil fuel or fossil fuel and wood residue. NR 440.19(3)(a)2.2. Exhibit greater than 20% opacity except for one 6-minute period per hour of not more than 27% opacity. NR 440.19(4)(a)(a) On and after the date on which the performance test required to be conducted by s. NR 440.08 is completed, no owner or operator subject to the provisions of this section may cause to be discharged into the atmosphere from any affected facility any gases which contain sulfur dioxide in excess of: NR 440.19(4)(a)1.1. 340 nanograms per joule heat input (0.80 lb per million Btu) derived from liquid fossil fuel or liquid fossil fuel and wood residue. NR 440.19(4)(a)2.2. 520 nanograms per joule heat input (1.2 lb per million Btu) derived from solid fossil fuel or solid fossil fuel and wood residue. NR 440.19(4)(b)(b) When different fossil fuels are burned simultaneously in any combination, the applicable standard (in ng/J) shall be determined by proration using the following formula: in which:
is the prorated standard for sulfur dioxide when burning different fuels simultaneously, in nanograms per joule heat input derived from all fossil fuels fired or from all fossil fuels and wood residue fired y is the percentage of total heat input derived from liquid fossil fuel
z is the percentage of total heat input derived from solid fossil fuel
NR 440.19(4)(c)(c) Compliance shall be based on the total heat input from all fossil fuels burned, including gaseous fuels. NR 440.19(5)(a)(a) On and after the date on which the performance test required to be conducted by s. NR 440.08 is completed, no owner or operator subject to the provisions of this section may cause to be discharged into the atmosphere from any affected facility any gases which contain nitrogen oxides, expressed as NO2 in excess of: NR 440.19(5)(a)1.1. 86 nanograms per joule heat input (0.20 lb per million Btu) derived from gaseous fossil fuel. NR 440.19(5)(a)2.2. 129 nanograms per joule heat input (0.30 lb per million Btu) derived from liquid fossil fuel, liquid fossil fuel and wood residue, or gaseous fossil fuel and wood residue. NR 440.19(5)(a)3.3. 300 nanograms per joule heat input (0.70 lb per million Btu) derived from solid fossil fuel or solid fossil fuel and wood residue (except lignite or a solid fuel containing 25%, by weight, or more of coal refuse). NR 440.19(5)(a)4.4. 260 nanograms per joule heat input (0.60 lb per million Btu) derived from lignite or lignite and wood residue, except as provided under subd. 5. NR 440.19(5)(a)5.5. 340 nanograms per joule heat input (0.80 lb per million Btu) derived from lignite which is mined in North Dakota, South Dakota or Montana and which is burned in a cyclone-fired unit. NR 440.19(5)(b)(b) Except as provided under pars. (c) and (d), when different fossil fuels are burned simultaneously in any combination, the applicable standard (in ng/J) is determined by proration using the following formula: in which:
is the prorated standard for nitrogen oxides when burning different fuels simultaneously, in nanograms per joule heat input derived from all fossil fuels fired or from all fossil fuels and wood residue fired w is the percentage of total heat input derived from lignite
x is the percentage of total heat input derived from gaseous fossil fuel
y is the percentage of total heat input derived from liquid fossil fuel
z is the percentage of total heat input derived from solid fossil fuel (except lignite)
NR 440.19(5)(c)(c) When a fossil fuel containing at least 25%, by weight, of coal refuse is burned in combination with gaseous, liquid or other solid fossil fuel or wood residue, the standard for nitrogen oxides does not apply. NR 440.19(5)(d)(d) Cyclone-fired units which burn fuels containing at least 25% of lignite that is mined in North Dakota, South Dakota or Montana remain subject to par. (a) 5. regardless of the types of fuel combusted in combination with that lignite. NR 440.19(6)(a)(a) Each owner or operator shall install, calibrate, maintain and operate continuous monitoring systems for measuring the opacity of emissions, sulfur dioxide emissions, nitrogen oxides emissions, and either oxygen or carbon dioxide except as provided in par. (b). NR 440.19(6)(b)(b) Certain of the continuous monitoring system requirements under par. (a) do not apply to owners or operators under the following conditions: NR 440.19(6)(b)1.1. For a fossil-fuel-fired steam generator that burns only gaseous fossil fuel, continuous monitoring systems for measuring the opacity of emissions and sulfur dioxide emissions are not required. NR 440.19(6)(b)2.2. For a fossil-fuel-fired steam generator that does not use a flue gas desulfurization device, a continuous monitoring system for measuring sulfur dioxide emissions is not required if the owner or operator monitors sulfur dioxide emissions by fuel sampling and analysis. NR 440.19(6)(b)3.3. Notwithstanding s. NR 440.13 (2), installation of a continuous monitoring system for nitrogen oxides may be delayed until after the initial performance tests under s. NR 440.08 have been conducted. If the owner or operator demonstrates during the performance test that emissions of nitrogen oxides are less than 70% of the applicable standards in sub. (5), a continuous monitoring system for measuring nitrogen oxides emissions is not required. If the initial performance test results show that nitrogen oxide emissions are greater than 70% of the applicable standard, the owner or operator shall install a continuous monitoring system for nitrogen oxides within one year after the date of the initial performance tests under s. NR 440.08 and comply with all other applicable monitoring requirements under this chapter. NR 440.19(6)(b)4.4. If an owner or operator does not install any continuous monitoring systems for sulfur oxides and nitrogen oxides, as provided under subds. 1. and 3. or subds. 2. and 3., a continuous monitoring system for measuring either oxygen or carbon dioxide is not required. NR 440.19(6)(c)1.1. Methods 6, 7 and 3B of 40 CFR part 60, Appendix A, incorporated by reference in s. NR 440.17, as applicable, shall be used for the performance evaluations of sulfur dioxide and nitrogen oxides continuous monitoring systems. Acceptable alternative methods for Methods 6, 7 and 3B are given in sub. (7) (d). NR 440.19(6)(c)2.2. Sulfur dioxide or nitric oxide, as applicable, shall be used for preparing calibration gas mixtures under Performance Specification 2 of 40 CFR part 60, Appendix B, incorporated by reference in s. NR 440.17. NR 440.19(6)(c)3.3. For affected facilities burning fossil fuel, the span value for a continuous monitoring system measuring the opacity of emissions shall be 80, 90 or 100% and for a continuous monitoring system measuring sulfur oxides or nitrogen oxides the span value shall be determined as follows: in which:
x is the fraction of total heat input derived from gaseous fossil fuel
y is the fraction of total heat input derived from liquid fossil fuel
z is the fraction of total heat input derived from solid fossil fuel
NR 440.19(6)(c)4.4. All span values computed under subd. 3. for burning combinations of fossil fuels shall be rounded to the nearest 500 ppm. NR 440.19(6)(c)5.5. For a fossil-fuel-fired steam generator that simultaneously burns fossil fuel and nonfossil fuel, the span value of all continuous monitoring systems shall be subject to the department’s approval. NR 440.19(6)(e)(e) For any continuous monitoring system installed under par. (a), the conversion procedures of this paragraph shall be used to convert the continuous monitoring data into units of the applicable standards (ng/J, lb/million Btu). NR 440.19(6)(e)1.1. When a continuous monitoring system for measuring oxygen is selected, the measurement of the pollutant concentration and oxygen concentration shall each be on a consistent basis (wet or dry). Alternative procedures approved by the department shall be used when measurements are on a wet basis. When measurements are on a dry basis, the following conversion procedures shall be used: E = CF [20.9/(20.9 - percent O2)]
where E, C, F, and percent O2 are determined under par. (f).
NR 440.19(6)(e)2.2. When a continuous monitoring system for measuring carbon dioxide is selected, the measurement of the pollutant concentration and carbon dioxide concentration shall each be on a consistent basis (wet or dry) and the following conversion procedure shall be used: E = CFc [100/percent CO2]
where E, C, Fc and percent CO2 are determined under par. (f).
NR 440.19(6)(f)(f) The values used in the equations under par. (e) 1. and 2. are derived as specified in this paragraph. NR 440.19(6)(f)2.2. C is the pollutant concentration, ng/dscm (lb/dscf), determined by multiplying the average concentration (ppm) for each one-hour period by 4.15 × 104 M ng/dscm per ppm (2.59 × 10-9 M lb/dscf per ppm) where M is the pollutant molecular weight, g/g-mole (lb/lb-mole). M = 64.07 for sulfur dioxide and 46.01 for nitrogen oxides. NR 440.19(6)(f)3.3. %O2 or %CO2 is the oxygen or carbon dioxide volume expressed as percent, determined with equipment specified under par. (a). NR 440.19(6)(f)4.4. F, Fc are a factor representing a ratio of the volume of dry flue gases generated to the calorific value of the fuel combusted (F), and a factor representing a ratio of the volume of carbon dioxide generated to the calorific value of the fuel combusted (Fc), respectively. Values of Fc and F are: NR 440.19(6)(f)4.a.a. For anthracite coal as classified according to ASTM D388-99 (reapproved 2004), incorporated by reference in s. NR 440.17 (2) (a) 12., F = 2.723 x 10-7 dscm/J (10,140 dscf/million Btu) and Fc = 0.532 x 10-7 scm CO2/J (1,980 scf CO2/million Btu). NR 440.19(6)(f)4.b.b. For subbituminous and bituminous coal as classified according to ASTM D388-99 (reapproved 2004), incorporated by reference in s. NR 440.17 (2) (a) 12., F = 2.637 × 10-7 dscm/J (9,820 dscf/million Btu) and Fc = 0.486 × 10-7 scm CO2/J (1,810 scf CO2/million Btu). NR 440.19(6)(f)4.c.c. For liquid fossil fuels including crude, residual and distillate oils, F = 2.476 × 10-7 dscm/J (9,220 dscf/million Btu) and Fc = 0.384 × 10-7 scm CO2/J (1,430 scf CO2/million Btu). NR 440.19(6)(f)4.d.d. For gaseous fossil fuels, F = 2.347 × 10-7 dscm/J (8,740 dscf/million Btu). For natural gas, propane and butane fuels, Fc = 0.279 × 10-7 scm CO2/J (1,040 scf CO2/million Btu) for natural gas, 0.322 × 10-7 scm CO2/J (1,200 scf CO2/million Btu) for propane, and 0.338 × 10-7 scm CO2/J (1,260 scf CO2/million Btu) for butane. NR 440.19(6)(f)4.e.e. For bark, F = 2.589 × 10-7 dscm/J (9,640 dscf/million Btu) and Fc = 0.500 × 10-7 scm CO2/J (1,840 scf CO2/million Btu). For wood residue other than bark, F = 2.492 × 10-7 dscm/J (9,280 dscf/million Btu) and Fc = 0.494 × 10-7 scm CO2/J (1,860 scf CO2/million Btu). NR 440.19(6)(f)4.f.f. For lignite coal as classified according to ASTM D388-99 (reapproved 2004), incorporated by reference in s. NR 440.17 (2) (a) 12., F = 2.659 × 10-7 dscm/J (9900 dscf/million Btu) and Fc = 0.516 × 10-7 scm CO2/J (1,920 scf CO2/million Btu).
