Section 462.05. Testing, fuel analyses and initial compliance requirements.

 

(1)   What are my initial compliance requirements and deadlines?

(a) For affected sources that elect to demonstrate compliance with any of the emission limits of this chapter through performance testing, your initial compliance requirements include conducting performance tests according to sub. (3) and Table 5 of this chapter, conducting a fuel analysis for each type of fuel burned in your boiler or process heater according to sub. (4) and Table 6 of this chapter, establishing operating limits according to sub. (7) and Table 7 of this chapter, and conducting CMS performance evaluations according to sub. (6) .

(b) For affected sources that elect to demonstrate compliance with the emission limits for HCl, mercury or TSM through fuel analysis, your initial compliance requirement is to conduct a fuel analysis for each type of fuel burned in your boiler or process heater according to sub. (4) and Table 6 of this chapter and establish operating limits according to sub. (7) and Table 8 of this chapter.

(c) For affected sources that have an applicable work practice standard, your initial compliance requirements depend on the subcategory and rated capacity of your boiler or process heater. If your boiler or process heater is in any of the limited use subcategories or has a heat input capacity less than 100 mmBtu per hour, your initial compliance demonstration is conducting a performance test for carbon monoxide according to Table 5 of this chapter. If your boiler or process heater is in any of the large subcategories and has a heat input capacity of 100 mmBtu per hour or greater, your initial compliance demonstration is conducting a performance evaluation of your continuous emission monitoring system for carbon monoxide according to sub. (6) (a) .

(d) For existing affected sources, you shall demonstrate initial compliance no later than 180 days after the compliance date that is specified for your source in s. NR 462.01 (5) and according to the applicable provisions in s. NR 460.06 (1) (b) as cited in Appendix DDDDD in ch. NR 460 .

(e) If your new or reconstructed affected source commenced construction or reconstruction between January 13, 2003 and November 12, 2004, you shall demonstrate initial compliance with either the proposed emission limits and work practice standards or the promulgated emission limits and work practice standards no later than 180 days after November 12, 2004 or within 180 days after startup of the source, whichever is later, according to s. NR 460.06 (1) (b) .

(f) If your new or reconstructed affected source commenced construction or reconstruction between January 13, 2003 and November 12, 2004, and you chose to comply with the proposed emission limits and work practice standards when demonstrating initial compliance, you shall conduct a second compliance demonstration for the promulgated emission limits and work practice standards within 3 years after November 12, 2004 or within 3 years after startup of the affected source, whichever is later.

(g) If your new or reconstructed affected source commences construction or reconstruction after November 12, 2004, you shall demonstrate initial compliance with the promulgated emission limits and work practice standards no later than 180 days after startup of the source.

(2)   When must I conduct subsequent performance tests or fuel analyses?

(a) You shall conduct all applicable performance tests according to sub. (3) on an annual basis, unless you follow the requirements listed in pars. (b) to (d) . Annual performance tests shall be completed between 10 and 12 months after the previous performance test, unless you follow the requirements listed in pars. (b) to (d) .

(b) You may conduct performance tests less often for a given pollutant if your performance tests for the pollutant - particulate matter, HCl, mercury or TSM - for at least 3 consecutive years show that you comply with the emission limit. In this case, you do not have to conduct a performance test for that pollutant for the next 2 years. You shall conduct a performance test during the third year and no more than 36 months after the previous performance test.

(c) If your boiler or process heater continues to meet the emission limit for particulate matter, HCl, mercury or TSM, you may choose to conduct performance tests for these pollutants every third year, but each performance test shall be conducted no more than 36 months after the previous performance test.

(d) If a performance test shows noncompliance with an emission limit for particulate matter, HCl, mercury or TSM, you shall conduct annual performance tests for that pollutant until all performance tests over a consecutive 3-year period show compliance.

(e) If you have an applicable work practice standard for carbon monoxide and your boiler or process heater is in any of the limited use subcategories or has a heat input capacity less than 100 mmBtu per hour, you shall conduct annual performance tests for carbon monoxide according to sub. (3) . Each annual performance test shall be conducted between 10 and 12 months after the previous performance test.

(f) You shall conduct a fuel analysis according to sub. (4) for each type of fuel burned no later than 5 years after the previous fuel analysis for each fuel type. If you burn a new type of fuel, you shall conduct a fuel analysis before burning the new type of fuel in your boiler or process heater. You shall still meet all applicable continuous compliance requirements in s. NR 462.06 (2) .

(g) You shall report the results of performance tests and fuel analyses to the department within 60 days after the completion of the performance tests or fuel analyses. This report shall also verify that the operating limits for your affected source have not changed or provide documentation of revised operating parameters established according to sub. (7) and Table 7 of this chapter, as applicable. The reports for all subsequent performance tests and fuel analyses shall include all applicable information required in s. NR 462.07 (2) .

(3)   What performance tests and procedures must I use?

(a) You shall conduct all performance tests according to s. NR 460.06 (2) , (3) , (5) and (7) . You shall also develop a site-specific test plan according to the requirements in s. NR 460.06 (2) if you elect to demonstrate compliance through performance testing.

(b) You shall conduct each performance test according to the requirements in Table 5 of this chapter.

(c) New or reconstructed boilers or process heaters in one of the liquid fuel subcategories that burn only fossil fuels and other gases and do not burn any residual oil shall demonstrate compliance according to s. NR 462.04 (2) (a) .

(d) You shall conduct each performance test under the specific conditions listed in Tables 5 and 7 of this chapter. You shall conduct performance tests at the maximum normal operating load while burning the type of fuel or mixture of fuels that have the highest content of chlorine, mercury and total selected metals, and you shall demonstrate initial compliance and establish your operating limits based on these tests. These requirements may result in the need to conduct more than one performance test.

(e) You may not conduct performance tests during periods of startup, shutdown or malfunction.

(f) You shall conduct 3 separate test runs for each performance test required in this subsection, as specified in s. NR 460.06 (4) (c) . Each test run shall last at least one hour.

(g) To determine compliance with the emission limits, you shall use the F-factor methodology and equations in sections 12.2 and 12.3 of EPA Method 19 of Appendix A to 40 CFR part 60 , incorporated by reference in s. NR 484.04 (13) , to convert the measured particulate matter concentrations, the measured HCl concentrations, the measured TSM concentrations and the measured mercury concentrations that result from the initial performance test to pounds per million Btu heat input emission rates.

(4)   What fuel analyses and procedures must I use?

(a) You shall conduct fuel analyses according to the procedures in pars. (b) to (e) and Table 6 of this chapter, as applicable.

(b) You shall develop and submit a site-specific fuel analysis plan to the department for review and approval according to the procedures and requirements in subds. 1. and 2.

1. You shall submit the fuel analysis plan no later than 60 days before the date that you intend to demonstrate compliance.

2. You shall include the information contained in subd. 2. a. to f. in your fuel analysis plan.

a. The identification of all fuel types anticipated to be burned in each boiler or process heater.

b. For each fuel type, notification of whether you or a fuel supplier will be conducting the fuel analysis.

c. For each fuel type, a detailed description of the sample location and specific procedures to be used for collecting and preparing the composite samples if your procedures are different from those in par. (c) or (d) . Where possible, samples should be collected at a location that most accurately represent the fuel type. Samples shall be collected at a point prior to mixing with other dissimilar fuel types.

d. For each fuel type, the analytical methods, with the expected minimum detection levels, to be used for the measurement of selected total metals, chlorine or mercury.

e. If you request to use an alternative analytical method other than those required by Table 6 of this chapter, a detailed description of the methods and procedures that will be used.

f. If you will be using fuel analysis from a fuel supplier in lieu of site-specific sampling and analysis, assurance that the fuel supplier will use the analytical methods required by Table 6 of this chapter.

(c) At a minimum, you shall obtain 3 composite fuel samples for each fuel type according to the procedures in subd. 1. or 2.

1. If sampling from a belt or screw feeder, collect fuel samples according to subd. 1. a. and b.

a. Stop the belt and withdraw a 6-inch wide sample from the full cross-section of the stopped belt to obtain a minimum 2 pounds of sample. Collect all the material, including fine and coarse material, in the full cross-section. Transfer the sample to a clean plastic bag.

b. Each composite sample shall consist of a minimum of 3 samples collected at approximately equal intervals during the testing period.

2. If sampling from a fuel pile or truck, collect fuel samples according to subd. 2. a. to c.

a. For each composite sample, select a minimum of 5 sampling locations uniformly spaced over the surface of the pile.

b. At each sampling site, dig into the pile to a depth of 18 inches. Insert a clean flat square shovel into the hole and withdraw a sample, making sure that large pieces do not fall off during sampling.

c. Transfer all samples to a clean plastic bag for further processing.

(d) Prepare each composite sample according to the procedures in subds. 1. to 7.

1. Thoroughly mix and pour the entire composite sample over a clean plastic sheet.

2. Break sample pieces larger than 3 inches into smaller sizes.

3. Make a pie shape with the entire composite sample and subdivide it into 4 equal parts.

4. Separate one of the quarter samples as the first subset.

5. If this subset is too large for grinding, repeat the procedure in subd. 3. with the quarter sample and obtain a one-quarter subset from this sample.

6. Grind the sample in a mill.

7. Use the procedure in subd. 3. to obtain a one-quarter subsample for analysis. If the quarter sample is too large, subdivide it further using the same procedure.

(e) Determine the concentration of pollutants (mercury, chlorine, and total selected metals) in the fuel in units of pounds per million Btu of each composite sample for each fuel type according to the procedures in Table 6 of this chapter.

(5)   Can I use emission averaging to comply with this chapter?

(a) As an alternative to meeting the requirements of s. NR 462.03 (2) , if you have more than one existing large solid fuel boiler located at your facility, you may demonstrate compliance by emission averaging according to the procedures in this subsection.

(b) For each existing large solid fuel boiler in the averaging group, the emission rate achieved during the initial compliance test for the HAP being averaged may not exceed the emission level that was being achieved on November 12, 2004, or the control technology employed during the initial compliance test may not be less effective for the HAP being averaged than the control technology employed on November 12, 2004.

(c) You may average particulate matter or TSM, HCl and mercury emissions from existing large solid fuel boilers to demonstrate compliance with the limits in Table 1 of this chapter if you satisfy the requirements in pars. (d) , (e) and (f) .

(d) The weighted average emissions from the existing large solid fuel boilers participating in the emissions averaging option shall be in compliance with the limits in Table 1 of this chapter at all times following the compliance date specified in s. NR 462.01 (5) .

(e) You shall demonstrate initial compliance according to subd. 1. or 2.

1. You shall use Equation 1 to demonstrate that the particulate matter or TSM, HCl and mercury emissions from all existing large solid fuel boilers participating in the emissions averaging option do not exceed the emission limits in Table 1 of this chapter.

- See PDF for diagram   (Equation 1)

where:

AWER is the average weighted emission rate for particulate matter or TSM, HCl or mercury, in units of pounds per million Btu of heat input

Er is the emission rate, as calculated according to Table 5 of this chapter, or fuel analysis as calculated by the applicable equation in sub. (7) (d) for boiler, i, for particulate matter or TSM, HCl or mercury, in units of pounds per million Btu of heat input

Hm is the maximum rated heat input capacity of boiler, i, in units of million Btu per hour

n is the number of large solid fuel boilers participating in the emissions averaging option

2. If you are not capable of monitoring heat input, you may use Equation 2 as an alternative to using Equation 1 to demonstrate that the particulate matter or TSM, HCl and mercury emissions from all existing large solid fuel boilers participating in the emissions averaging option do not exceed the emission limits in Table 1 of this chapter.

- See PDF for diagram
  (Equation 2)

where:

AWER is the average weighted emission rate for particulate matter or TSM, HCl or mercury, in units of pounds per million Btu of heat input

Er is the emission rate, as calculated according to Table 5 of this chapter, or fuel analysis as calculated by the applicable equation in sub. (7) (d) for boiler, i, for particulate matter or TSM, HCl or mercury, in units of pounds per million Btu of heat input

Sm is the maximum steam generation by boiler, i, in units of pounds.

Cf is the conversion factor, calculated from the most recent compliance test, in units of million Btu of heat input per pounds of steam generated

n is the number of large solid fuel boilers participating in the emissions averaging option

(f) You shall demonstrate continuous compliance on a 12-month rolling average basis determined at the end of every month (12 times per year) according to subds. 1. and 2. The first 12-month rolling-average period begins on the compliance date specified in s. NR 462.01 (5) .

1. For each calendar month, you shall use Equation 3 to calculate the 12-month rolling average weighted emission rate using the actual heat capacity for each existing large solid fuel boiler participating in the emissions averaging option.

- See PDF for diagram   (Equation 3)

where:

AWER is the 12-month rolling average weighted emission rate for particulate matter or TSM, HCl or mercury, in units of pounds per million Btu of heat input

Er is the emission rate, as calculated during the most recent compliance test according to Table 5 of this chapter, or fuel analysis as calculated by the applicable equation in sub. (7) (d) for boiler, i, for particulate matter or TSM, HCl or mercury, in units of pounds per million Btu of heat input

Hb is the average heat input for each calendar month of boiler, i, in units of million Btu

n is the number of large solid fuel boilers participating in the emissions averaging option

2. If you are not capable of monitoring heat input, you may use Equation 4 as an alternative to using Equation 3 to calculate the 12-month rolling average weighted emission rate using the actual steam generation from the large solid fuel boilers participating in the emissions averaging option.

- See PDF for diagram
  (Equation 4)

where:

AWER is the 12-month rolling average weighted emission rate for particulate matter or TSM, HCl or mercury, in units of pounds per million Btu of heat input

Er is the emission rate, as calculated during the most recent compliance test according to Table 5 of this chapter, or fuel analysis as calculated by the applicable equation in sub. (7) (d) for boiler, i, for particulate matter or TSM, HCl or mercury, in units of pounds per million Btu of heat input

Sa is the actual steam generation for each calendar month by boiler, i, in units of pounds

Cf is the conversion factor, as calculated during the most recent compliance test, in units of million Btu of heat input per pounds of steam generated

n is the number of large solid fuel boilers participating in the emissions averaging option

(g) You shall develop and submit an implementation plan for emission averaging to the department for review and approval according to the procedures and requirements in subds. 1. to 4.

1. You shall submit the implementation plan no later than 180 days before the date that the facility intends to demonstrate compliance using the emission averaging option.

2. You shall include the information required in subd. 2. a. to g. in your implementation plan for all emission sources included in an emission averaging group.

a. The identification of all existing large solid fuel boilers in the averaging group, including for each boiler either the applicable HAP emission level or the installed control technology.

b. The process parameter, either heat input or steam generated, that will be monitored for each averaging group of large solid fuel boilers.

c. The specific control technology or pollution prevention measure to be used for each emission source in the averaging group and the date of its installation or application. If the pollution prevention measure reduces or eliminates emissions from multiple sources, the owner or operator shall identify each source.

d. The test plan for the measurement of particulate matter or TSM, HCl or mercury emissions in accordance with the requirements in sub. (3) .

e. The operating parameters to be monitored for each control system or device and a description of how the operating limits will be determined.

f. If you request to monitor one or more alternative operating parameters pursuant to sub. (6) , a description of the parameter or parameters to be monitored, an explanation of the criteria used to select the parameter or parameters and a description of the methods and procedures that will be used to demonstrate that the parameter indicates proper operation of the control device. You shall also include the frequency and content of monitoring, reporting and recordkeeping requirements and a demonstration, to the satisfaction of the department, that the proposed monitoring frequency is sufficient to represent control device operating conditions.

g. A demonstration that compliance with each of the applicable emission limits will be achieved under representative operating conditions.

3. Upon receipt, the department shall review and approve or disapprove the plan according to both of the following criteria:

a. Whether the content of the plan includes all of the information specified in subd. 2.

b. Whether the plan presents sufficient information to determine that compliance will be achieved and maintained.

4. The department may not approve an emission averaging implementation plan containing any of the following provisions:

a. Any averaging between emissions of differing pollutants or between differing sources.

b. The inclusion of any emission source other than an existing large solid fuel boiler.

(6)   What are my monitoring, installation, operation and maintenance requirements?

(a) If you have an applicable work practice standard for carbon monoxide and your boiler or process heater is in any of the large subcategories and has a heat input capacity of 100 mmBtu per hour or greater, you shall install, operate and maintain a continuous emission monitoring system (CEMS) for carbon monoxide according to the procedures in subds. 1. to 6. by the compliance date specified in s. NR 462.01 (5) .

1. Each CEMS shall be installed, operated and maintained according to Performance Specification (PS) 4A of 40 CFR part 60 , Appendix B, incorporated by reference in s. NR 484.04 (21) , and according to the site-specific monitoring plan developed according to s. NR 462.04 (1) (d) .

2. You shall conduct a performance evaluation of each CEMS according to the requirements in s. NR 460.07 and according to PS 4A of 40 CFR part 60 , Appendix B, incorporated by reference in s. NR 484.04 (21) .

3. Each CEMS shall complete a minimum of one cycle of operation, which includes sampling, analyzing and data recording, for each successive 15-minute period.

4. The CEMS data shall be reduced as specified in s. NR 460.07 (7) (b) .

5. You shall calculate and record a 30-day rolling average emission rate on a daily basis. A new 30-day rolling average emission rate is calculated as the average of all of the hourly CO emission data for the preceding 30 operating days.

6. For purposes of calculating data averages, you may not use data recorded during periods of monitoring malfunctions, associated repairs, out-of-control periods, required quality assurance or control activities or when your boiler or process heater is operating at less than 50% of its rated capacity. You shall use all the data collected during all other periods in assessing compliance. Any period for which the monitoring system is out of control and data are not available for required calculations constitutes a deviation from the monitoring requirements.

(b) If you have an applicable opacity operating limit, you shall install, operate, certify and maintain each continuous opacity monitoring system (COMS) according to the procedures in subds. 1. to 7. by the compliance date specified in s. NR 462.01 (5) .

1. Each COMS shall be installed, operated and maintained according to PS 1 of 40 CFR part 60 , Appendix B, incorporated by reference in s. NR 484.04 (21) .

2. You shall conduct a performance evaluation of each COMS according to the requirements in s. NR 460.07 and according to PS 1 of 40 CFR part 60 , Appendix B, incorporated by reference in s. NR 484.04 (21) .

3. As specified in s. NR 460.07 (3) (d) 1. , each COMS shall complete a minimum of one cycle of sampling and analyzing for each successive 10-second period and one cycle of data recording for each successive 6-minute period.

4. The COMS data shall be reduced as specified in s. NR 460.07 (7) (b) .

5. You shall include in your site-specific monitoring plan procedures and acceptance criteria for operating and maintaining each COMS according to the requirements in s. NR 460.07 (4) . At a minimum, the monitoring plan shall include a daily calibration drift assessment, a quarterly performance audit and an annual zero alignment audit of each COMS.

6. You shall operate and maintain each COMS according to the requirements in the monitoring plan and the requirements of s. NR 460.07 (5) . Identify periods the COMS is out of control, including any periods that the COMS fails to pass a daily calibration drift assessment, a quarterly performance audit or an annual zero alignment audit.

7. You shall determine and record all the 6-minute averages, and one-hour block averages, as applicable, collected for periods during which the COMS is not out of control.

(c) If you have an operating limit that requires the use of a CMS, you shall install, operate and maintain each continuous parameter monitoring system (CPMS) according to the procedures in subds. 1. to 5. by the compliance date specified in s. NR 462.01 (5) .

1. The CPMS shall complete a minimum of one cycle of operation for each successive 15-minute period. You shall have a minimum of 4 successive cycles of operation to have a valid hour of data.

2. Except for monitoring malfunctions, associated repairs and required quality assurance or control activities, including, as applicable, calibration checks and required zero and span adjustments, you shall conduct all monitoring in continuous operation at all times that the unit is operating. A monitoring malfunction is any sudden, infrequent, not reasonably preventable failure of the monitoring to provide valid data. Monitoring failures that are caused in part by poor maintenance or careless operation are not malfunctions.

3. For purposes of calculating data averages, you may not use data recorded during monitoring malfunctions, associated repairs, out of control periods or required quality assurance or control activities. You shall use all the data collected during all other periods in assessing compliance. Any period for which the monitoring system is out-of-control and data are not available for required calculations constitutes a deviation from the monitoring requirements.

4. Determine the 3-hour block average of all recorded readings, except as provided in subd. 3.

5. Record the results of each inspection, calibration and validation check.

(d) If you have an operating limit that requires the use of a flow measurement device, you shall meet the requirements in par. (c) and subds. 1. to 4.

1. Locate the flow sensor and other necessary equipment in a position that provides a representative measurement of the flow.

2. Use a flow sensor with a measurement sensitivity of 2% of the flow rate.

3. Reduce swirling flow or abnormal velocity distributions due to upstream and downstream disturbances.

4. Conduct a flow sensor calibration check at least semiannually.

(e) If you have an operating limit that requires the use of a pressure measurement device, you shall meet the requirements in par. (c) and subds. 1. to 6.

1. Locate the pressure sensor in a position that provides a representative measurement of the pressure.

2. Minimize or eliminate pulsating pressure, vibration and internal and external corrosion.

3. Use a gauge with a minimum tolerance of 1.27 centimeters of water or a transducer with a minimum tolerance of one percent of the pressure range.

4. Check pressure tap for blockages or plugging daily.

5. Using a manometer, check gauge calibration quarterly and transducer calibration monthly.

6. Conduct calibration checks any time the sensor exceeds the manufacturer's specified maximum operating pressure range or install a new pressure sensor.

(f) If you have an operating limit that requires the use of a pH measurement device, you shall meet the requirements in par. (c) and subds. 1. to 3.

1. Locate the pH sensor in a position that provides a representative measurement of scrubber effluent pH.

2. Ensure that the sample is properly mixed and representative of the fluid to be measured.

3. Check the pH meter's calibration on at least 2 points every 8 hours of process operation.

(g) If you have an operating limit that requires the use of equipment to monitor voltage and secondary current, or total power input, of an electrostatic precipitator (ESP), you shall use voltage and secondary current monitoring equipment to measure voltage and secondary current to the ESP.

(h) If you have an operating limit that requires the use of equipment to monitor sorbent injection rate, such as a weigh belt, weigh hopper or hopper flow measurement device, you shall meet the requirements in par. (c) and subds. 1. to 3.

1. Locate the device in a position that provides a representative measurement of the total sorbent injection rate.

2. Install and calibrate the device in accordance with manufacturer's procedures and specifications.

3. At least annually, calibrate the device in accordance with the manufacturer's procedures and specifications.

(i) If you elect to use a fabric filter bag leak detection system to comply with the requirements of this chapter, you shall install, calibrate, maintain and continuously operate a bag leak detection system as specified in subds. 1. to 8.

1. You shall install and operate a bag leak detection system for each exhaust stack of the fabric filter.

2. Each bag leak detection system shall be installed, operated, calibrated and maintained in a manner consistent with the manufacturer's written specifications and recommendations and in accordance with the guidance provided in EPA-454/R-98-015, September 1997, incorporated by reference in s. NR 484.06 (4) (c) .

3. The bag leak detection system shall be certified by the manufacturer to be capable of detecting particulate matter emissions at concentrations of 10 milligrams per actual cubic meter or less.

4. The bag leak detection system sensor shall provide output of relative or absolute particulate matter loadings.

5. The bag leak detection system shall be equipped with a device to continuously record the output signal from the sensor.

6. The bag leak detection system shall be equipped with an alarm system that will sound automatically when an increase in relative particulate matter emissions over a preset level is detected. The alarm shall be located where it is easily heard by plant operating personnel.

7. For positive pressure fabric filter systems that do not duct all compartments or cells to a common stack, a bag leak detection system shall be installed in each baghouse compartment or cell.

8. Where multiple bag leak detectors are required, the system's instrumentation and alarm may be shared among detectors.

(7)   How do I demonstrate initial compliance with the emission limits and work practice standards?

(a) You shall demonstrate initial compliance with each emission limit and work practice standard that applies to you by either conducting initial performance tests and establishing operating limits, as applicable, according to sub. (3) (c) and Tables 5 and 7 of this chapter OR conducting initial fuel analyses to determine emission rates and establishing operating limits, as applicable, according to sub. (4) (d) and Tables 6 and 8 of this chapter.

(b) New or reconstructed boilers or process heaters in one of the liquid fuel subcategories that burn only fossil fuels and other gases and do not burn any residual oil shall demonstrate compliance according to s. NR 462.04 (2) (a) .

(c) If you demonstrate compliance through performance testing, you shall establish each site-specific operating limit in Tables 2 to 4 of this chapter that applies to you according to the requirements in sub. (3) , Table 7 of this chapter, and subd. 4. , as applicable. You shall also conduct fuel analyses according to sub. (4) and establish maximum fuel pollutant input levels according to subds. 1. to 3. , as applicable.

1. You shall establish the maximum chlorine fuel input (C input ) during the initial performance testing according to the procedures in subd. 1. a. to c.

a. You shall determine the fuel type or fuel mixture that you could burn in your boiler or process heater that has the highest content of chlorine.

b. During the performance testing for HCl, you shall determine the fraction of the total heat input for each fuel type burned (Q i ) based on the fuel mixture that has the highest content of chlorine and the average chlorine concentration of each fuel type burned (C i ).

c. You shall establish a maximum chlorine input level using Equation 5.

- See PDF for diagram   (Equation 5)

where:

C input is the maximum amount of chlorine entering the boiler or process heater through fuels burned in units of pounds per million Btu

C i is the arithmetic average concentration of chlorine in fuel type, i, analyzed according to sub. (4) , in units of pounds per million Btu

Q i is the fraction of total heat input from fuel type, i, based on the fuel mixture that has the highest content of chlorine. If you do not burn multiple fuel types during the performance testing, it is not necessary to determine the value of this term. Insert a value of "1" for Q i .

n is the number of different fuel types burned in your boiler or process heater for the mixture that has the highest content of chlorine

2. If you choose to comply with the alternative TSM emission limit instead of the particulate matter emission limit, you shall establish the maximum TSM fuel input level (TSM input ) during the initial performance testing according to the procedures in subd. 2. a. to c.

a. You shall determine the fuel type or fuel mixture that you could burn in your boiler or process heater that has the highest content of TSM.

b. During the performance testing for TSM, you shall determine the fraction of total heat input from each fuel burned (Q i ) based on the fuel mixture that has the highest content of total selected metals and the average TSM concentration of each fuel type burned (M i ).

c. You shall establish a baseline TSM input level using Equation 6.

- See PDF for diagram (Equation 6)

where:

TSM input is the maximum amount of TSM entering the boiler or process heater through fuels burned, in units of pounds per million Btu

M i is the arithmetic average concentration of TSM in fuel type, i, analyzed according to sub. (4) , in units of pounds per million Btu

Q i is the fraction of total heat input from fuel type, i, based on the fuel mixture that has the highest content of TSM. If you do not burn multiple fuel types during the performance test, it is not necessary to determine the value of this term. Insert a value of "1" for Q i .

n is the number of different fuel types burned in your boiler or process heater for the mixture that has the highest content of TSM

3. You shall establish the maximum mercury fuel input level (Mercury input ) during the initial performance testing using the procedures in subd. 3. a. to c.

a. You shall determine the fuel type or fuel mixture that you could burn in your boiler or process heater that has the highest content of mercury.

b. During the compliance demonstration for mercury, you shall determine the fraction of total heat input for each fuel burned (Q i ) based on the fuel mixture that has the highest content of mercury, and you shall determine the average mercury concentration of each fuel type burned (HGi).

c. You shall establish a maximum mercury input level using Equation 7.

- See PDF for diagram   (Equation 7)

where:

Mercury input is the maximum amount of mercury entering the boiler or process heater through fuels burned, in units of pounds per million Btu

HG i is the arithmetic average concentration of mercury in fuel type, i, analyzed according to sub. (4) , in units of pounds per million Btu

Q i is the fraction of total heat input from fuel type, i, based on the fuel mixture that has the highest mercury content. If you do not burn multiple fuel types during the performance test, it is not necessary to determine the value of this term. Insert a value of "1" for Q i .

n is the number of different fuel types burned in your boiler or process heater for the mixture that has the highest content of mercury

4. You shall establish parameter operating limits according to subd. 4. a. to d.

a. For a wet scrubber, you shall establish the minimum scrubber effluent pH, liquid flow rate and pressure drop, as defined in s. NR 462.02 (32) to (34) , as your operating limits during the 3-run performance test. If you use a wet scrubber and you conduct separate performance tests for particulate matter, HCl and mercury emissions, you shall establish one set of minimum scrubber effluent pH, liquid flow rate and pressure drop operating limits. The minimum scrubber effluent pH operating limit shall be established during the HCl performance test. If you conduct multiple performance tests, you shall set the minimum liquid flow rate and pressure drop operating limits at the highest minimum values established during the performance tests.

b. For an electrostatic precipitator, you shall establish the minimum voltage and the minimum secondary current or the minimum total power input, as defined in s. NR 462.02 (36) , as your operating limits during the 3-run performance test.

c. For a dry scrubber, you shall establish the minimum sorbent injection rate, as defined in s. NR 462.02 (35) , as your operating limit during the 3-run performance test.

d. The operating limit for boilers or process heaters with fabric filters for which you choose to demonstrate continuous compliance through bag leak detection systems is that a bag leak detection system be installed according to the requirements in sub. (6) , and that each fabric filter shall be operated such that the bag leak detection system alarm does not sound more than 5% of the operating time during a 6-month period.

(d) If you elect to demonstrate compliance with an applicable emission limit through fuel analysis, you shall conduct fuel analyses according to sub. (4) and follow the procedures in subds. 1. to 5.

1. If you burn more than one fuel type, you shall determine the fuel mixture you could burn in your boiler or process heater that would result in the maximum emission rates of the pollutants for which you elect to demonstrate compliance through fuel analysis.

2. You shall determine the 90th percentile confidence level fuel pollutant concentration of the composite samples analyzed for each fuel type using the one-sided z-statistic test described in Equation 8.

P 90 = mean + (SD x t)   (Equation 8)

where:

P 90 is the 90th percentile confidence level pollutant concentration, in pounds per million Btu

mean is the arithmetic average of the fuel pollutant concentration in the fuel samples analyzed according to sub. (4) , in units of pounds per million Btu

SD is the standard deviation of the pollutant concentration in the fuel samples analyzed according to sub. (4) , in units of pounds per million Btu

t is the t distribution critical value for 90th percentile (0.1) probability for the appropriate degrees of freedom (number of samples minus one) as obtained from a Distribution Critical Value Table

3. To demonstrate compliance with the applicable emission limit for HCl, the HCl emission rate that you calculate for your boiler or process heater using Equation 9 shall be less than the applicable emission limit for HCl.

- See PDF for diagram   (Equation 9)

where:

HCl is the HCl emission rate from the boiler or process heater in units of pounds per million Btu

C i90 is the 90th percentile confidence level concentration of chlorine in fuel type, i, in units of pounds per million Btu as calculated according to Equation 8

Q i is the fraction of total heat input from fuel type, i, based on the fuel mixture that has the highest content of chlorine. If you do not burn multiple fuel types, it is not necessary to determine the value of this term. Insert a value of "1" for Q i .

n is the number of different fuel types burned in your boiler or process heater for the mixture that has the highest content of chlorine

1.028 is the molecular weight ratio of HCl to chlorine

4. To demonstrate compliance with the applicable emission limit for TSM, the TSM emission rate that you calculate for your boiler or process heater using Equation 10 shall be less than the applicable emission limit for TSM.

- See PDF for diagram   (Equation 10)

where:

TSM is the TSM emission rate from the boiler or process heater in units of pounds per million Btu

M i90 is the 90th percentile confidence level concentration of TSM in fuel, i, in units of pounds per million Btu as calculated according to Equation 8

Q i is the fraction of total heat input from fuel type, i, based on the fuel mixture that has the highest content of total selected metals. If you do not burn multiple fuel types, it is not necessary to determine the value of this term. Insert a value of "1" for Q i .

n is the number of different fuel types burned in your boiler or process heater for the mixture that has the highest content of TSM

5. To demonstrate compliance with the applicable emission limit for mercury, the mercury emission rate that you calculate for your boiler or process heater using Equation 11 shall be less than the applicable emission limit for mercury.

- See PDF for diagram   (Equation 11)

where:

Mercury is the mercury emission rate from the boiler or process heater in units of pounds per million Btu

HG i90 is the 90th percentile confidence level concentration of mercury in fuel, i, in units of pounds per million Btu as calculated according to Equation 8

Q i is the fraction of total heat input from fuel type, i, based on the fuel mixture that has the highest mercury content. If you do not burn multiple fuel types, it is not necessary to determine the value of this term. Insert a value of "1" for Q i.

n is the number of different fuel types burned in your boiler or process heater for the mixture that has the highest mercury content

(e) You shall submit the Notification of Compliance Status containing the results of the initial compliance demonstration according to the requirements in s. NR 462.07 (1) (e) .

History: CR 05-116 : cr. Register November 2006 No. 611 , eff. 12-1-06.