Chapter NR 440

NR 440.26(6)(a)4.a. a. The span value for this instrument is 425 mg/dscm H2S.

NR 440.26(6)(a)4.b. b. Fuel gas combustion devices having a common source of fuel gas may be monitored at only one location, if monitoring at this location accurately represents the concentration of H2S in the fuel gas begin burned.

NR 440.26(6)(a)4.c. c. The performance evaluations for this H2S monitor under s. NR 440.13 (3) shall use Performance Specification 7 of 40 CFR part 60, Appendix B, incorporated by reference in s. NR 440.17 (1). Method 11, 15, 15A or 16 of 40 CFR part 60, Appendix A, incorporated by reference in s. NR 440.17 (1), shall be used for conducting the relative accuracy evaluations.

NR 440.26(6)(a)5. 5. For Claus sulfur recovery plants with oxidation control systems or reduction control systems followed by incineration subject to sub. (5) (a) 2. a., an instrument for continuously monitoring and recording the concentration (dry basis, zero percent excess air) of SO2 emissions into the atmosphere. The monitor shall include an oxygen monitor for correcting the data for excess air.

NR 440.26(6)(a)5.a. a. The span values for this monitor are 500 ppm SO2 and 25% O2.

NR 440.26(6)(a)5.b. b. The performance evaluations for the SO2 monitor under s. NR 440.13 (3) shall use Performance Specification 2 of 40 CFR part 60, Appendix B, incorporated by reference in s. NR 440.17 (1). Methods 6 or 6C and 3 or 3A of 40 CFR part 60, Appendix A, incorporated by reference in s. NR 440.17 (1), shall be used for conducting the relative accuracy evaluations.

NR 440.26(6)(a)6. 6. For Claus sulfur recovery plants with reduction control systems not followed by incineration subject to sub. (5) (a) 2. b., an instrument for continuously monitoring and recording the concentration of reduced sulfur and O2 emissions into the atmosphere. The reduced sulfur emission shall be calculated as SO2 (dry basis, zero percent excess air).

NR 440.26(6)(a)6.a. a. The span values for this monitor are 450 ppm reduced sulfur and 25% O2.

NR 440.26(6)(a)6.b. b. The performance evaluations for this reduced sulfur (and O2) monitor under s. NR 440.13 (3) shall use Performance Specification 5 (and Performance Specification 3 for the O2 analyzer) of 40 CFR part 60, Appendix B, incorporated by reference in s. NR 440.17 (1). Methods 15 or 15A and Method 3 of 40 CFR part 60, Appendix A, incorporated by reference in s. NR 440.17 (1), shall be used for conducting the relative accuracy evaluations. If Method 3 yields O2 concentrations below 0.25% during the performance specification test, the O2 concentration may be assumed to be zero and the reduced sulfur CEMS need not include an O2 monitor.

NR 440.26(6)(a)7. 7. In place of the reduced sulfur monitor under subd. 6., an instrument using an air or O2 dilution and oxidation system to convert the reduced sulfur to SO2 for continuously monitoring and recording the concentration (dry basis, zero percent excess air) of the resultant SO2. The monitor shall include an oxygen monitor for correcting the data for excess oxygen.

NR 440.26(6)(a)7.a. a. The span values for this monitor are 375 ppm SO2 and 25% O2.

NR 440.26(6)(a)7.b. b. For reporting purposes, the SO2 exceedance level for this monitor is 250 ppm (dry basis, zero percent excess air).

NR 440.26(6)(a)7.c. c. The performance evaluations for the SO2 (and O2) monitor under s. NR 440.13 (3) shall use Performance Specification 5. Methods 15 or 15A and Method 3 shall be used for conducting the relative accuracy evaluations.

NR 440.26(6)(a)8. 8. An instrument for continuously monitoring and recording concentrations of sulfur dioxide in the gases at both the inlet and outlet of the sulfur dioxide control device from any fluid catalytic cracking unit catalyst regenerator for which the owner or operator seeks to comply with sub. (5) (b) 1.

NR 440.26(6)(a)8.a. a. The span value of the inlet monitor shall be set at 125% of the maximum estimated hourly potential sulfur dioxide emission concentration entering the control device, and the span value of the outlet monitor shall be set at 50% of the maximum estimated hourly potential sulfur dioxide emission concentration entering the control device.

NR 440.26(6)(a)8.b. b. The performance evaluations for these sulfur dioxide monitors under s. NR 440.13 (3) shall use Performance Specification 2 of 40 CFR part 60, Appendix B, incorporated by reference in s. NR 440.17 (1). Methods 6 or 6C and 3 or 3A of 40 CFR part 60, Appendix A, incorporated by reference in s. NR 440.17 (1), shall be used for conducting the relative accuracy evaluations.

NR 440.26(6)(a)9. 9. An instrument for continuously monitoring and recording concentrations of sulfur dioxide in the gases discharged into the atmosphere from any fluid catalytic cracking unit catalyst regenerator for which the owner or operator seeks to comply specifically with the 50 ppmv emission limit under sub. (5) (b) 1.

NR 440.26(6)(a)9.a. a. The span value of the monitor shall be set at 50% of the maximum hourly potential sulfur dioxide emission concentration of the control device.

NR 440.26(6)(a)9.b. b. The performance evaluation for this sulfur dioxide monitor under s. NR 440.13 (3) shall use Performance Specification 2 of 40 CFR part 60, Appendix B, incorporated by reference in s. NR 440.17 (1). Methods 6 or 6C and 3 or 3A of 40 CFR part 60, Appendix A, incorporated by reference in s. NR 440.17 (1), shall be used for conducting the relative accuracy evaluations.

NR 440.26(6)(a)10. 10. An instrument for continuously monitoring and recording concentrations of oxygen (O2) in the gases at both the inlet and outlet of the sulfur dioxide control device (or the outlet only if specifically complying with the 50 ppmv standard) from any fluid catalytic cracking unit catalyst regenerator for which the owner or operator has elected to comply with sub. (5) (b) 1. The span of the continuous monitoring system shall be set at 10%.

NR 440.26(6)(a)11. 11. The continuous monitoring systems under par. (a) 8., 9. and 10. are operated and data recorded during all periods of operation of the affected facility including periods of startup, shutdown or malfunction, except for continuous monitoring system breakdowns, repairs, calibration checks, and zero and span adjustments.

NR 440.26(6)(a)12. 12. The owner or operator shall use the following procedures to evaluate the continuous monitoring systems under subds. 8., 9. and 10.:

NR 440.26(6)(a)12.a. a. Method 3 or 3A and Method 6 or 6C of 40 CFR part 60, Appendix A, incorporated by reference in s. NR 440.17 (1), for the relative accuracy evaluations under the s. NR 440.13 (5) performance evaluation.

NR 440.26(6)(a)12.b. b. Procedure 1 of 40 CFR part 60, Appendix F, incorporated by reference in s. NR 440.17 (1), including quarterly accuracy determinations and daily calibration drift tests.

NR 440.26(6)(a)13. 13. When seeking to comply with sub. (5) (b) 1., when 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 one of the following methods to provide emission data for a minimum of 18 hours per day in at least 22 out of 30 following successive calendar days:

NR 440.26(6)(a)13.a. a. The test methods as described in 40 CFR 60.106 (k);

NR 440.26(6)(a)13.b. b. A spare continuous monitoring system; or

NR 440.26(6)(a)13.c. c. Other monitoring systems as approved by the administrator.

NR 440.26(6)(c) (c) The average coke burn-off rate (Mg (tons) per hour) and hours of operation shall be recorded daily for any fluid catalytic cracking unit catalyst regenerator subject to sub. (3), (4) or (5) (b) 2.

NR 440.26(6)(d) (d) For any fluid catalytic cracking unit catalyst regenerator under sub. (3) that uses an incinerator-waste heat boiler to combust the exhaust gases from the catalyst regenerator, the owner or operator shall record daily the rate of combustion of liquid or solid fossil-fuels and the hours of operation during which liquid or solid fossil-fuels are combusted in the incinerator-waste heater boiler.

NR 440.26(6)(e) (e) For the purpose of reports under s. NR 440.07 (3), periods of excess emissions that shall be determined and reported are defined as follows:

NR 440.26 Note Note: All averages, except for opacity, shall be determined as the arithmetic average of the applicable 1-hour averages, e.g., the rolling 3-hour average shall be determined as the arithmetic average of 3 contiguous 1-hour averages.

NR 440.26(6)(e)1. 1. Opacity. All 1-hour periods that contain 2 or more 6-minute periods during which the average opacity as measured by the continuous monitoring system under par. (a) 1. exceeds 30%.

NR 440.26(6)(e)2. 2. Carbon monoxide. All 1-hour periods during which the average CO concentration as measured by the CO continuous monitoring system under par. (a) 2. exceeds 500 ppm.

NR 440.26(6)(e)3. 3. Sulfur dioxide from fuel gas combustion.

NR 440.26(6)(e)3.a. a. All rolling 3-hour periods during which the average concentration of SO2 as measured by the SO2 continuous monitoring system under par. (a) 3. exceeds 20 ppm (dry basis, zero percent excess air); or

NR 440.26(6)(e)3.b. b. All rolling 3-hour periods during which the average concentration of H2S as measured by the H2S continuous monitoring system under par. (a) 4. exceeds 230 mg/dscm (0.10 gr/dscf).

NR 440.26(6)(e)4. 4. Sulfur dioxide from Claus sulfur recovery plants.

NR 440.26(6)(e)4.a. a. All 12-hour periods during which the average concentration of SO2 as measured by the SO2 continuous monitoring system under par. (a) 5. exceeds 250 ppm (dry basis, zero percent excess air); or

NR 440.26(6)(e)4.b. b. All 12-hour periods during which the average concentration of reduced sulfur (as SO2) as measured by the reduced sulfur continuous monitoring system under par. (a) 6. exceeds 300 ppm; or

NR 440.26(6)(e)4.c. c. All 12-hour periods during which the average concentration of SO2 as measured by the SO2 continuous monitoring system under par. (a) 7. exceeds 250 ppm (dry basis, zero percent excess air).

NR 440.26(7) (7) Test methods and procedures.

NR 440.26(7)(a) (a) In conducting the performance tests required in s. NR 440.08, the owner or operator shall use as reference methods and procedures the test methods in Appendix A of 40 CFR part 60, incorporated by reference in s. NR 440.17, or other methods and procedures as specified in this subsection, except as provided in s. NR 440.08 (2).

NR 440.26(7)(b) (b)

NR 440.26(7)(b)1. 1. The emission rate (E) of PM shall be computed for each run using the following equation:

- See PDF for diagram

where:

E is the emission rate of PM, kg/Mg (lb/ton) of coke burn-off

cs is the concentration of PM, g/dscm (gr/dscf)

Qsd is the volumetric flow rate of exhaust gas, dscm/hr (dscf/hr)

Rc is the coke burn-off rate, Mg/hr (ton/hr) coke

K is a conversion factor, 1,000 g/kg (7000 gr/lb)

NR 440.26(7)(b)2. 2. Method 5B or 5F shall be used to determine particulate matter emissions and associated moisture content from affected facilities without wet FGD systems; only Method 5B shall be used after wet FGD systems. The sampling time for each run shall be at least 60 minutes and the sampling time for each run shall be at least 0.015 dscm/min (0.53 dscf/min) except that shorter sampling times may be approved by the department when process variables or other factors preclude sampling for at least 60 minutes.

NR 440.26(7)(b)3. 3. The coke burn-off rate (Rc) shall be computed for each run using the following equation:

- See PDF for diagram

where:

Rc is the coke burn-off rate, Mg/hr (ton/hr)

Qr is the volumetric flow rate of exhaust gas from catalyst regenerator before entering the emission control system, dscm/min (dscf/min)

Qa is the volumetric flow rate of air to FCCU regenerator, as determined from the fluid catalytic cracking unit control room instrumentation, dscm/min (dscf/min)

%CO2 is the carbon dioxide concentration, percent by volume (dry basis)

%CO is the carbon monoxide concentration, percent by volume (dry basis)

%O2 is the oxygen concentration, percent by volume (dry basis)

K1 is the material balance and conversion factor, 2.982 x 10-4 (Mg-min)/hr-dscm-%) [9.31 x 10 -6 (ton-min)/(hr-dscf-%)]

K2 is the material balance and conversion factor, 2.088 x 10-3 (Mg-min)/(hr-dscm-%) [6.52 x 10 -5 (ton-min)/(hr-dscf-%)]

K3 is the material balance and conversion factor, 9.94 x 10-5 (Mg-min)/(hr-dscm-%) [3.1 x 10-6 (ton-min)/(hr-dscf-%)]

NR 440.26(7)(b)3.a. a. Method 2 of 40 CFR part 60, Appendix A, incorporated by reference in s. NR 440.17 (1), shall be used to determine the volumetric flow rate (Qr).

NR 440.26(7)(b)3.b. b. The emission correction factor, integrated sampling and analysis procedure of Method 3B of 40 CFR part 60, Appendix A, incorporated by reference in s. NR 440.17 (1), shall be used to determine CO2, CO and O2 concentrations.

NR 440.26(7)(b)4. 4. Method 9 of 40 CFR part 60, Appendix A, incorporated by reference in s. NR 440.17 (1), and the procedures of s. NR 440.11 shall be used to determine opacity.

NR 440.26(7)(c) (c) If auxiliary liquid or solid fossil fuels are burned in an incinerator-waste heat boiler, the owner or operator shall determine the emission rate of PM permitted in sub. (3) (b) as follows:

NR 440.26(7)(c)1. 1. The allowable emission rate (Es) of PM shall be computed for each run using the following equation:

- See PDF for diagram

where:

Es is the emission rate of PM allowed, kg/Mg (lb/ton) of coke burn-off in catalyst regenerator

F is the emission standard, 1.0 kg/Mg (2.0 lb/ton) of coke burn-off in catalyst regenerator

A is the allowable incremental rate of PM emission, 7.5 x 10-4 kg/million J (0.10 lb/million Btu)

H is the heat input rate from solid or liquid fossil fuel, million J/hr (million Btu/hr)

Rc is the coke burn-off rate, Mg coke/hr (ton coke/hr)

NR 440.26(7)(c)2. 2. Procedures subject to the approval of the department shall be used to determine the heat input rate.

NR 440.26(7)(c)3. 3. The procedure in par. (b) 3. shall be used to determine the coke burn- off rate (Rc).

NR 440.26(7)(d) (d) The owner or operator shall determine compliance with the CO standard in sub. (4) (a) by using the integrated sampling technique of Method 10 to determine the CO concentration (dry basis). The sampling time for each run shall be 60 minutes.

NR 440.26(7)(e) (e)

NR 440.26(7)(e)1. 1. The owner or operator shall determine compliance with the H2S standard in sub. (5) (a) 1. as follows: Method 11, 15, 15A or 16 of 40 CFR part 60, Appendix A, incorporated by reference in s. NR 440.17 (1), shall be used to determine the H2S concentration. The gases entering the sampling train should be at about atmospheric pressure. If the pressure in the refinery fuel gas lines is relatively high, a flow control valve may be used to reduce the pressure. If the line pressure is high enough to operate the sampling train without a vacuum pump, the pump may be eliminated from the sampling train. The sample shall be drawn from a point near the centroid of the fuel gas line.

NR 440.26(7)(e)1.a. a. For Method 11, the sampling time and sample volume shall be at least 10 minutes and 0.010 dscm (0.35 dscf). Two samples of equal sampling time shall be taken at about 1-hour intervals. The arithmetic average of these 2 samples shall constitute a run.

NR 440.26 Note Note: For most fuel gas, sampling time exceeding 20 minutes may result in depletion of the collection solution, although fuel gases containing low concentrations of H2S may necessitate sampling for longer periods of time.

NR 440.26(7)(e)1.b. b. For Method 15 or 16, at least 3 injects over a 1-hour period shall constitute a run.

NR 440.26(7)(e)1.c. c. For Method 15A, a 1-hour sample shall constitute a run.

NR 440.26(7)(e)2. 2. Where emissions are monitored by sub. (6) (a) 3., compliance with sub. (6) (a) 1. shall be determined using Method 6 or 6C and Method 3 or 3A of 40 CFR part 60, Appendix A, incorporated by reference in s. NR 440.17 (1). A 1-hour sample shall constitute a run. Method 6 samples shall be taken at a rate of approximately 2 liters/min. The ppm correction factor (Method 6) and the sampling location in par. (f) 1. apply. Method 4 of 40 CFR part 60, Appendix A, incorporated by reference in s. NR 440.17 (1), shall be used to determine the moisture content of the gases. The sampling point for Method 4 shall be adjacent to the sampling point for Method 6 or 6C.

NR 440.26(7)(f) (f) The owner or operator shall determine compliance with the SO2 and the H2S and reduced sulfur standards in sub. (5) (a) 2. as follows:

NR 440.26(7)(f)1. 1. Method 6 of 40 CFR part 60, Appendix A, incorporated by reference in s. NR 440.17 (1), shall be used to determine the SO2 concentration. The concentration in mg/dscm obtained by Method 6 or 6C is multiplied by 0.3754 to obtain the concentration in ppm. The sampling point in the duct shall be the centroid of the cross section if the cross-sectional area is less than 5.00 m2 (53.8 ft2) or at a point no closer to the walls than 1.00 m (39.4 in.) if the cross-sectional area is 5.00 m2 or more and the centroid is more than 1 m from the wall. The sampling time and sample volume shall be at least 10 minutes and 0.010 dscm (0.35 dscf) for each sample. Eight samples of equal sampling times shall be taken at about 30-minute intervals. The arithmetic average of these 8 samples shall constitute a run. For Method 6C, a run shall consist of the arithmetic average of 4 1-hour samples. Method 4 of 40 CFR part 60, Appendix A, incorporated by reference in s. NR 440.17 (1), shall be used to determine the moisture content of the gases. The sampling point for Method 4 shall be adjacent to the sampling point for Method 6 or 6C. The sampling time for each sample shall be equal to the time it takes for 2 Method 6 samples. The moisture content from this sample shall be used to correct the corresponding Method 6 samples for moisture. For documenting the oxidation efficiency of the control device for reduced sulfur compounds, Method 15 of 40 CFR part 60, Appendix A, incorporated by reference in s. NR 440.17 (1), shall be used following the procedures of subd. 2.