NR 440.207(2)(s)(s) “Oil” means crude oil or petroleum, or a liquid fuel derived from crude oil or petroleum, including distillate oil and residual oil. NR 440.207(2)(t)(t) “Potential sulfur dioxide emission rate” means the theoretical SO2 emissions, nanograms per joule (ng/J) or pounds per million Btu (lb/million Btu) heat input, that would result from combusting fuel in an uncleansed state and without using emission control systems. NR 440.207(2)(u)(u) “Process heater” means a device that is primarily used to heat a material to initiate or promote a chemical reaction to which the material participates as a reactant or catalyst. NR 440.207(2)(v)(v) “Residual oil” means crude oil, fuel oil that does not comply with the specifications under the definition of distillate oil, and all fuel oil numbers 4, 5 and 6, as defined by the American Society for Testing and Materials in ASTM D396-98, Standard Specification for Fuel Oils, incorporated by reference in s. NR 440.17 (2) (a) 13. NR 440.207(2)(w)(w) “Steam generating unit” means a device that combusts any fuel and produces steam or heats water or any other heat transfer medium. This term includes any duct burner that combusts fuel and is part of a combined cycle system. This term does not include process heaters as defined in this section. NR 440.207(2)(x)(x) “Steam generating unit operating day” means a 24-hour period between 12:00 midnight and the following midnight during which any fuel is combusted at any time in the steam generating unit. It is not necessary for fuel to be combusted continuously for the entire 24-hour period. NR 440.207(2)(y)(y) “Wet flue gas desulfurization technology” means an SO2 control system that is located between the steam generating unit and the exhaust vent or stack, and that removes sulfur oxides from the combustion gases of the steam generating unit by contacting the combustion gases with an alkaline slurry or solution and forming a liquid material. This definition includes devices where the liquid material is subsequently converted to another form. Alkaline reagents used in wet flue gas desulfurization systems include, but are not limited to, lime, limestone and sodium compounds. NR 440.207(2)(z)(z) “Wet scrubber system” means any emission control device that mixes an aqueous stream or slurry with the exhaust gases from a steam generating unit to control emissions of particulate matter (PM) or SO2. NR 440.207(2)(zm)(zm) “Wood” means wood, wood residue, bark or any derivative fuel or residue thereof, in any form, including but not limited to sawdust, sanderdust, wood chips, scraps, slabs, millings, shavings and processed pellets made from wood or other forest residues. NR 440.207(3)(a)(a) Except as provided in pars. (b), (c) and (e), on and after the date on which the initial performance test is completed or required to be completed under s. NR 440.08, whichever date comes first, the owner or operator of an affected facility that combusts only coal may neither: NR 440.207(3)(a)1.1. Cause to be discharged into the atmosphere from that affected facility any gases that contain SO2 in excess of 10% (0.10) of the potential SO2 emission rate, 90% reduction; nor NR 440.207(3)(a)2.2. Cause to be discharged into the atmosphere from that affected facility any gases that contain SO2 in excess of 520 ng/J (1.2 lb/million Btu) heat input. If coal is combusted with other fuels, the affected facility is subject to the 90% SO2 reduction requirement specified in this paragraph and the emission limit is determined pursuant to par. (e) 2. NR 440.207(3)(b)(b) Except as provided in pars. (c) and (e), on and after the date on which the initial performance test is completed or required to be completed under s. NR 440.08, whichever date comes first, the owner or operator of an affected facility that: NR 440.207(3)(b)1.1. Combusts coal refuse alone in a fluidized bed combustion steam generating unit may neither: NR 440.207(3)(b)1.a.a. Cause to be discharged into the atmosphere from that affected facility any gases that contain SO2 in excess of 20% (0.20) of the potential SO2 emission rate (80% reduction); nor NR 440.207(3)(b)1.b.b. Cause to be discharged into the atmosphere from that affected facility any gases that contain SO2 in excess of 520 ng/J (1.2 lb/million Btu) heat input. If coal is fired with coal refuse, the affected facility is subject to par. (a). If oil or any other fuel, except coal, is fired with coal refuse, the affected facility is subject to the 90% SO2 reduction requirement specified in par. (a) and the emission limit determined pursuant to par. (e) 2. NR 440.207(3)(b)2.2. Combusts only coal and that uses an emerging technology for the control of SO2 emissions may neither: NR 440.207(3)(b)2.a.a. Cause to be discharged into the atmosphere from that affected facility any gases that contain SO2 in excess of 50% (0.50) of the potential SO2 emission rate, 50% reduction; nor NR 440.207(3)(b)2.b.b. Cause to be discharged into the atmosphere from that affected facility any gases that contain SO2 in excess of 260 ng/J (0.60 lb/million Btu) heat input. If coal is combusted with other fuels, the affected facility is subject to the 50% SO2 reduction requirement specified in this paragraph and the emission limit determined pursuant to par. (e) 2. NR 440.207(3)(c)(c) On and after the date on which the initial performance test is completed or required to be completed under s. NR 440.08, whichever date comes first, no owner or operator of an affected facility that combusts coal, alone or in combination with any other fuel, and is listed in subd. 1., 2., 3. or 4. may cause to be discharged into the atmosphere from that affected facility any gases that contain SO2 in excess of the emission limit determined pursuant to par. (e) 2. Percent reduction requirements are not applicable to affected facilities under this paragraph. NR 440.207(3)(c)1.1. Affected facilities that have a heat input of 22 MW (75 million Btu/hr) or less. NR 440.207(3)(c)2.2. Affected facilities that have an annual capacity for coal of 55% (0.55) or less and are subject to a federally enforceable requirement limiting operation of the affected facility to an annual capacity factor for coal of 55% (0.55) or less. NR 440.207(3)(c)4.4. Affected facilities that combust coal in a duct burner as part of a combined cycle system where 30% (0.30) or less of the heat entering the steam generating unit is from combustion of coal in the duct burner and 70% (0.70) or more of the heat entering the steam generating unit is from exhaust gases entering the duct burner. NR 440.207(3)(d)(d) On and after the date on which the initial performance test is completed or required to be completed under s. NR 440.08, whichever date comes first, no owner or operator of an affected facility that combusts oil may cause to be discharged into the atmosphere from that affected facility any gases that contain SO2 in excess of 215 ng/J (0.50 lb/million Btu) heat input; or, as an alternative, no owner or operator of an affected facility that combusts oil shall combust oil in the affected facility that contains greater than 0.5 weight percent sulfur. The percent reduction requirements are not applicable to affected facilities under this paragraph. NR 440.207(3)(e)(e) On and after the date on which the initial performance test is completed or required to be completed under s. NR 440.08, whichever date comes first, no owner or operator of an affected facility that combusts coal, oil, or coal and oil with any other fuel may cause to be discharged into the atmosphere from that affected facility any gases that contain SO2 in excess of the following: NR 440.207(3)(e)1.1. The percent of potential SO2 emission rate required under par. (a) or (b) 2., as applicable, for any affected facility that: NR 440.207(3)(e)2.2. The emission limit determined according to the following formula for any affected facility that combusts coal, oil, or coal and oil with any other fuel: Es = (KaHa + KbHb + KcHc)/(Ha + Hb + Hc)
where:
Es is the SO2 emission limit, expressed in ng/J or lb/million Btu heat input
Ka is 520 ng/J (1.2 lb/million Btu)
Kb is 260 ng/J (0.60 lb/million Btu)
Kc is 215 ng/J (0.50 lb/million Btu)
Ha is the heat input from the combustion of coal, except coal combusted in an affected facility subject to par. (b) 2., in joules (J) (million Btu)
Hb is the heat input from the combustion of coal, in an affected facility subject to par. (b) 2., in J (million Btu)
Hc is the heat input from the combustion of oil, in J (million Btu)
NR 440.207(3)(f)(f) Reduction in the potential SO2 emission rate through fuel pretreatment is not credited toward the percent reduction requirement under par. (b) 2. unless: NR 440.207(3)(f)1.1. Fuel pretreatment results in a 50% (0.50) or greater reduction in the potential SO2 emission rate; and NR 440.207(3)(f)2.2. Emissions from the pretreated fuel, without either combustion or post-combustion SO2 control, are equal to or less than the emission limits specified under par. (b) 2. NR 440.207(3)(g)(g) Except as provided in par. (h), compliance with the percent reduction requirements, fuel oil sulfur limits, and emission limits of this subsection shall be determined on a 30-day rolling average basis. NR 440.207(3)(h)(h) For affected facilities listed under subd. 1., 2. or 3., compliance with the emission limits or fuel oil sulfur limits under this subsection may be determined based on a certification from the fuel supplier, as described under sub. (9) (f) 1., 2. or 3., as applicable. NR 440.207(3)(h)1.1. Distillate oil-fired affected facilities with heat input capacities between 2.9 and 29 MW (10 and 100 million Btu/hr). NR 440.207(3)(h)2.2. Residual oil-fired affected facilities with heat input capacities between 2.9 and 8.7 MW (10 and 30 million Btu/hr). NR 440.207(3)(h)3.3. Coal-fired facilities with heat input capacities between 2.9 and 8.7 MW (10 and 30 million Btu/hr). NR 440.207(3)(i)(i) The SO2 emission limits, fuel oil sulfur limits and percent reduction requirements under this subsection apply at all times, including periods of startup, shutdown and malfunction. NR 440.207(3)(j)(j) Only the heat input supplied to the affected facility from the combustion of coal and oil is counted under this subsection. No credit is provided for the heat input to the affected facility from wood or other fuels or for heat derived from exhaust gases from other sources, such as stationary gas turbines, internal combustion engines and kilns. NR 440.207(4)(a)(a) On and after the date on which the initial performance test is completed or required to be completed under s. NR 440.08, whichever date comes first, no owner or operator of an affected facility that combusts coal or combusts mixtures of coal with other fuels and has a heat input capacity of 8.7 MW (30 million Btu/hr) or greater, may cause to be discharged into the atmosphere from that affected facility any gases that contain PM in excess of the following emission limits: NR 440.207(4)(a)1.1. 22 ng/J (0.051 lb/million Btu) heat input if the affected facility combusts only coal, or combusts coal with other fuels and has an annual capacity factor for the other fuels of 10% (0.10) or less. NR 440.207(4)(a)2.2. 43 ng/J (0.10 lb/million Btu) heat input if the affected facility combusts coal with other fuels, has an annual capacity factor for the other fuels greater than 10% (0.10), and is subject to a federally enforceable requirement limiting operation of the affected facility to an annual capacity factor greater than 10% (0.10) for fuels other than coal. NR 440.207(4)(b)(b) On and after the date on which the initial performance test is completed or required to be completed under s. NR 440.08, whichever date comes first, no owner or operator of an affected facility that combusts wood or combusts mixtures of wood with other fuels, except coal, and has a heat input capacity of 8.7 MW (30 million Btu/hr) or greater, may cause to be discharged into the atmosphere from that affected facility any gases that contain PM in excess of the following emission limits: NR 440.207(4)(b)1.1. 43 ng/J (0.10 lb/million Btu) heat input if the affected facility has an annual capacity factor for wood greater than 30% (0.30); or NR 440.207(4)(b)2.2. 130 ng/J (0.30 lb/million Btu) heat input if the affected facility has an annual capacity factor for wood of 30% (0.30) or less and is subject to a federally enforceable requirement limiting operation of the affected facility to an annual capacity factor for wood of 30% (0.30) or less. NR 440.207(4)(c)(c) On and after the date on which the initial performance test is completed or required to be completed under s. NR 440.08, whichever date comes first, no owner or operator of an affected facility that combusts coal, wood or oil and has a heat input capacity of 8.7 MW (30 million Btu/hr) or greater may cause to be discharged into the atmosphere from that affected facility any gases that exhibit greater than 20% opacity (6-minute average), except for one 6-minute period per hour of not more than 27% opacity. NR 440.207(4)(d)(d) The PM and opacity standards under this subsection apply at all times, except during periods of startup, shutdown or malfunction. NR 440.207(5)(5) Compliance and performance test methods and procedures for sulfur dioxide. NR 440.207(5)(a)(a) Except as provided in pars. (g) and (h) and in s. NR 440.08 (2), performance tests required under s. NR 440.08 shall be conducted following the procedures specified in pars. (b) to (f), as applicable. The cited methods and procedures are in Appendix A of 40 CFR part 60, incorporated by reference in s. NR 440.17. Section NR 440.08 (6) does not apply to this subsection. The 30-day notice required in s. NR 440.08 (4) applies only to the initial performance test unless otherwise specified by the department. NR 440.207(5)(b)(b) The initial performance test required under s. NR 440.08 shall be conducted over 30 consecutive operating days of the steam generating unit. Compliance with the percent reduction requirements and SO2 emission limits under sub. (3) shall be determined using a 30-day average. The first operating day included in the initial performance test shall be scheduled within 30 days after achieving the maximum production rate at which the affected facility will be operated, but not later than 180 days after the initial startup of the facility. The steam generating unit load during the 30-day period does not have to be the maximum design heat input capacity, but shall be representative of future operating conditions. NR 440.207(5)(c)(c) After the initial performance test required under par. (b) and s. NR 440.08, compliance with the percent reduction requirements and SO2 emission limits under sub. (3) is based on the average percent reduction and the average SO2 emission rates for 30 consecutive steam generating unit operating days. A separate performance test is completed at the end of each steam generating unit operating day, and a new 30-day average percent reduction and SO2 emission rate are calculated to show compliance with the standard. NR 440.207(5)(d)(d) If only coal, only oil, or a mixture of coal and oil is combusted in an affected facility, the procedures in Method 19 are used to determine the hourly SO2 emission rate (Eho) and the 30-day average SO2 emission rate (Eao). The hourly averages are obtained from the continuous emission monitoring system (CEMS). Method 19 shall be used to calculate Eao when using daily fuel sampling or Method 6B. NR 440.207(5)(e)(e) If coal, oil, or coal and oil are combusted with other fuels: NR 440.207(5)(e)1.1. An adjusted Eho (Ehoo) is used in equation 19-19 of Method 19 to compute the adjusted Eao (Eaoo). The Ehoo is computed using the following formula: Ehoo = (Eho - Ew(1 - Xk))/Xk
where:
Ehoo is the adjusted Eho, ng/J (lb/million Btu)
Eho is the hourly SO2 emission rate, ng/J (lb/million Btu)
Ew is the SO2 concentration in fuels other than coal and oil combusted in the affected facility, as determined by fuel sampling and analysis procedures in Method 9, ng/J (lb/million Btu). The value Ew for each fuel lot is used for each hourly average during the time that the lot is being combusted. The owner or operator does not have to measure Ew if the owner or operator elects to assume Ew = 0
Xk is the fraction of the total heat input from fuel combustion derived from coal and oil, as determined by applicable procedures in Method 19
NR 440.207(5)(e)2.2. The owner or operator of an affected facility that qualifies under the provisions of sub. (3) (c) or (d), where percent reduction is not required, does not have to measure the parameters Ew or Xk if the owner or operator of the affected facility elects to measure emission rates of the coal or oil using the fuel sampling and analysis procedures under Method 19. NR 440.207(5)(f)(f) Affected facilities subject to the percent reduction requirements under sub. (3) (a) or (b) shall determine compliance with the SO2 emission limits under sub. (3) pursuant to par. (d) or (e), and shall determine compliance with the percent reduction requirements using the following procedures: NR 440.207(5)(f)1.1. If only coal is combusted, the percent of potential SO2 emission rate is computed using the following formula: %Ps = 100 (1 - %Rg/100) (1 - %Rf/100)
where:
%Ps is the percent of potential SO2 emission rate, in percent
%Rg is the SO2 removal efficiency of the control device as determined by Method 19, in percent
%Rf is the SO2 removal efficiency of fuel pretreatment as determined by Method 19, in percent
NR 440.207(5)(f)2.2. If coal, oil, or coal and oil are combusted with other fuels, the same procedures required in subd. 1. are used, except as provided for in the following: NR 440.207(5)(f)2.a.a. To compute the %Ps, an adjusted %Rg (%Rgo) is computed from Eaoo from par. (e) 1. and an adjusted SO2 inlet rate (Eaio) using the following formula: %Rgo = 100 [1.0 - (Eaoo/Eai)]
where:
%Rgo is the adjusted %Rg, in percent
Eaoo is the adjusted Eao, ng/J (lb/million Btu)
Eaio is the adjusted average SO2 inlet rate, ng/J (lb/million Btu)
NR 440.207(5)(f)2.b.b. To compute Eaio, an adjusted hourly SO2 inlet rate (Ehio) is used. The Ehio is computed using the following formula:
