DEPARTMENT OF ENVIRONMENTAL QUALITY  
AIR QUALITY DIVISION  
AIR POLLUTION CONTROL  
(By authority conferred on the director of the department of environmental quality by  
sections 5503 and 5512 of the natural resources and environmental protection act, 1994  
PA 451, MCL 324.5503 and 324.5512)  
PART 4. EMISSION LIMITATIONS AND PROHIBITIONSSULFUR  
BEARING COMPOUNDS  
R 336.1401 Emission of sulfur dioxide from power plants.  
Rule 401. (1) In a power plant, it is unlawful for a person to burn fuel that does not  
comply with the sulfur content limitation of table 41 or which, when burned, results in  
sulfur dioxide (SO2) emissions exceeding an equivalent emission rate as shown in table  
41. In a power plant located in Wayne county, it is unlawful for a person to burn fuel that  
does not comply with the sulfur content limitation of table 42 and unlawful to cause or  
permit a discharge into the atmosphere from fuel-burning equipment SO2 in excess of the  
SO2 concentration limit shown in table 42.  
(2) Tables 41 and 42 read as follows:  
TABLE 41  
Fuel and SO2 Emission Limitations for Power Plants  
Maximum  
Average  
Sulfur  
Equivalent Emission Rates  
Parts per Million by Volume Pounds of SO2 per  
Plant Capacity(a)  
(ppmv) Corrected to 50%  
Million Btu of Heat Input  
(e)  
Excess Air(e)  
Content in  
Fuel(b, e)  
Solid Fuel(c) Liquid Fuel(d) Solid  
Liquid  
Fuel(d)  
(18,000  
Btu/lb)  
(Percent  
by weight)  
(12,000  
Btu/lb)  
(18,000  
Btu/lb)  
Fuel(c)  
(12,000  
Btu/lb)  
0-500,000 lbs  
Steam per Hour Plant  
Capacity  
1.5  
1.0  
890  
630  
2.5  
1.67  
Greater than  
590  
420  
1.67  
1.11  
500,000 lbs Steam per  
Hour Plant Capacity  
(a) The total steam production capacity of all coal- and oil-burning equipment in a power  
plant as of August 17, 1971.  
(b) "Maximum average sulfur content in fuel" means the average sulfur content in all fuels  
burned at any 1 time in a power plant. The sulfur content shall be calculated on the basis of  
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12,000 Btu per pound for solid fuels and 18,000 Btu per pound for liquid fuels.  
(c) Solid fuels include both pulverized coal and all other coal.  
(d) Liquid fuels include distillate oil (No. 1 and No. 2), heavy oil (No. 4, No. 5, and No. 6),  
and crude oil.  
(e) A person shall sample, analyze, calculate, and record for each day of operation for each  
unit at the power plant, the sulfur content of the fuel combusted or the fuel’s equivalent SO2  
emission rate in accordance with as-fired fuel sampling and analysis procedures found in  
appendix A of 40 CFR part 60; in particular the “Standard Test Methods for Sulfur in Petroleum  
Products:” ASTM D129, D1266, or D1552 and the “Standard Test Methods for Total Sulfur in  
the Analysis of Coal and Coke:” ASTM D3177 or D4239; as referenced in 40 CFR 60.17,  
adopted by reference in R 336.1902. Records must be kept, including the identification of the  
power plant, days of operation, and maximum sulfur content of fuel combusted for each day of  
operation. Records must be maintained on site for 5 years and submitted to the department upon  
written request.  
TABLE 42  
Fuel and SO2 Concentration Limitations for Power Plants Located in Wayne County  
Maximum Weight Percent  
SO2 ppmv Emission Rates  
Fuel Type  
Sulfur Content in Fuel(a & b)  
Corrected to 50% Excess Air (b)  
Limitations for Fuel-Burning  
Equipment  
1.00  
Pulverized Coal  
Other Coal  
Distillate Oil Nos. 1 & 2  
Used Oil  
Crude and Heavy Oil  
Nos. 4, 5, & 6  
550  
420  
120  
300  
400  
0.75  
0.30  
1.00  
1.00  
(a) “Maximum weight percent sulfur content in fuel" means the maximum weight percent  
sulfur content in all fuels burned at any 1 time in a power plant.  
(b) A person shall sample, analyze, calculate, and record for each day of operation for  
each unit at the power plant, the sulfur content of the fuel combusted and the fuel’s equivalent  
SO2 emission rate in accordance with as-fired fuel sampling and analysis procedures found in  
appendix A of 40 CFR part 60; in particular the “Standard Test Methods for Sulfur in  
Petroleum Products:” ASTM D129, D1266, or D1552 and the “Standard Test Methods for  
Total Sulfur in the Analysis of Coal and Coke:” ASTM D3177 or D4239; as referenced in 40  
CFR 60.17, adopted by reference in R 336.1902. Records must be kept, including the  
identification of the power plant, days of operation, and maximum sulfur content of fuel  
combusted for each day of operation. Records must be maintained on site for 5 years and  
submitted to the department upon written request.  
(3) The following provisions apply to persons in Wayne county:  
(a) The maximum weight percent sulfur content in fuel limitations for fuel-burning  
equipment provisions of table 42 of this rule do not apply to any person who uses a  
combination of fuels in such ratios as to meet the SO2 concentration limitations specified  
in table 42 and has obtained written approval from the department for this exemption.  
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The allowable concentration limit will be based on the value in the table for the fuel  
having the higher allowable concentration limit.  
(b) The maximum weight percent sulfur content in fuel limitations for fuel-burning  
equipment provisions of table 42 of this rule do not apply to any person who has received  
an installation permit from the department for a control device to desulfurize the stack  
gases if the control device is installed and operating properly.  
(4) Instead of conducting daily as-fired fuel sampling and analysis pursuant to subrule  
(2) of this rule, a person at any power plant equipped with a SO2 continuous emissions  
monitoring system (CEMS) may compute and record the daily equivalent emission rates  
as determined by the SO2 CEMS. The SO2 CEMS must be calibrated, maintained, and  
operated in accordance with the procedures in 40 CFR 60.13(d), (e), (f), and (h) and in  
performance specification 2, appendix B of 40 CFR part 60 or 40 CFR part 75 excluding  
the data substitution outlined in subpart D, adopted by reference in R 336.1902. Records  
must be maintained on site for 5 years and submitted to the department upon written  
request.  
History: 1980 AACS; 2002 AACS; 2008 AACS 2013 AACS; 2019 AACS.  
R 336.1401a Definitions.  
Rule 401a. As used in this part:  
(a) "Power plant" means a single structure devoted to steam or electric generation, or  
both, and may contain multiple boilers.  
(b) “Sulfur recovery plant” means any plant that recovers elemental sulfur from any  
gas stream.  
History: 2008 AACS 2013 AACS; 2019 AACS.  
R 336.1402 Emission of SO2 from fuel-burning equipment at a stationary source  
other than power plants.  
Rule 402. (1) For fuel burning equipment at a stationary source other than a power  
plant it is unlawful for a person to cause or allow the emission of SO2 from the  
combustion of any coal or oil fuel in excess of 1.7 pounds per million Btu of heat input  
for oil fuel or in excess of 2.4 pounds per million Btu of heat input for coal fuel.  
(2) The provisions of subrule (1) of this rule do not apply to fuel-burning equipment  
at a stationary source that is unable to comply with the specified emission limits because  
of SO2 emissions caused by the presence of sulfur in other raw materials charged to the  
fuel-burning equipment. This exception applies if at any time the actual SO2 emission  
rate exceeds the expected theoretical SO2 emission rate from fuel burning. The expected  
theoretical SO2 emission rate must be based on the quantity of fuel burned and the  
average sulfur content of the fuel.  
(3) For fuel burning equipment at a stationary source located in Wayne county other  
than a power plant, it is unlawful for a person to burn fuel that does not comply with the  
sulfur content limitation of table 43 and unlawful to cause or allow a discharge into the  
atmosphere from fuel burning equipment SO2 in excess of the SO2 concentration limit  
shown in table 43.  
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(4) Table 43 reads as follows:  
Table 43  
Fuel and SO2 Concentration Limitations for Fuel Burning Equipment(c) at a Stationary  
Source Located in Wayne County Other than a Power Plant  
Maximum Weight Percent SO2 ppmv Emission Rates  
Fuel Type  
Sulfur Content in Fuel(a, b) Corrected to 50%  
Limitations for Fuel-  
Burning Equipment  
0.75  
ExcessAirb  
Coal  
420  
120  
Distillate Oil Nos. 1  
& 2  
0.30  
Used Oil  
Crude and Heavy Oil  
Nos. 4, 5, & 6  
1.0  
1.00  
300  
400  
(a) The determination of sulfur content (percent by weight) of fuel shall be  
carried out in accordance with the “Standard Test Methods for Sulfur in Petroleum  
Products:” ASTM D129, D1266, or D1552 and the “Standard Test Methods for Total  
Sulfur in the Analysis of Coal and Coke:” ASTM D3177 or D4239; as referenced in  
40 C.F.R. 60.17, adopted by reference in R 336.1902.  
(b) Records must be kept, including the identification of the fuel burning  
equipment, days of operation, and maximum sulfur content of fuel combusted for  
each day of operation. Records must be maintained on site for 5 years and submitted  
to the department upon written request.  
(c) For table 43, fuel burning equipment includes residential and commercial  
space and water heating. The maximum weight percent sulfur content in fuel and  
SO2 ppmv emission rate limitations for distillate, crude, and heavy oils listed above  
also apply to these units.  
(5) The following provisions apply to persons in Wayne county:  
(a) The maximum weight percent sulfur content in fuel limitations for fuel-burning  
equipment provisions of table 43 of this rule do not apply to a person who uses a  
combination of fuels in such ratios as to meet the SO2 concentration limitations specified  
in table 43 and has obtained written approval from the department for this exemption.  
The allowable concentration limit will be based on the value in the table for the fuel  
having the higher allowable concentration limit.  
(b) The maximum weight percent sulfur content in fuel limitations for fuel-burning  
equipment provisions of table 43 of this rule do not apply to a person who has received  
an installation permit from the department for a control device to desulfurize the stack  
gases if the control device is installed and operating properly.  
History: 1980 AACS; 2008 AACS 2013 AACS; 2019 AACS.  
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R 336.1403 Oil- and natural gas-producing or transporting facilities and natural  
gas-processing facilities; emissions; operation.  
Rule 403. (1) Except as provided in subrule (3) of this rule, it is unlawful for a  
person to cause or allow the emission of sour gas from an oil- or natural gas-producing or  
transporting facility or a natural gas- processing facility without burning or equivalent  
control of hydrogen sulfide and mercaptans.  
(2) Except as provided in subrule (3) of this rule, sour gas that is burned at an oil- or  
natural gas-producing or transporting facility or at a natural gas-processing facility shall  
be burned in a properly engineered flare, incinerator, or other combustion system with  
elevated discharge to the atmosphere. If the flare, incinerator, or other combustion  
system burns sour gas in such volume and with such hydrogen sulfide concentration that  
the daily quantity of hydrogen sulfide in the gas is less than 28 pounds, then it shall be  
equipped with either a pilot flame which will burn continuously when gas flows to the  
flare, incinerator, or other combustion system or with an automatic ignition system,  
unless otherwise authorized by the department. If the flare, incinerator, or other  
combustion system burns sour gas in such volume and with such hydrogen sulfide  
concentration that the daily quantity of hydrogen sulfide in the gas is 28 pounds or more,  
then it shall be equipped with a continuously burning pilot flame and a mechanism which  
will operate, upon failure of the pilot flame, to shut off the flow of gas, unless otherwise  
authorized by the department.  
(3) The provisions of subrules (1) and (2) of this rule do not apply to either of the  
following:  
(a) Crude oil-producing facilities that serve a well or group of wells which attained  
an average production level of 10 or less barrels per day per well before January 1, 1978,  
unless the department has received 1 complaint of odors regarding the facility, and the  
owner or operator is unable to or fails to demonstrate, to the satisfaction of the  
department, that the uncontrolled hydrogen sulfide and mercaptan emissions do not cause  
an odor nuisance or health hazard.  
(b) A vessel or a battery of vessels that releases a total daily volume of vapors of less  
than 5,000 standard cubic feet, if the owner or operator demonstrates both of the  
following:  
(i) Combustion of the vapors is not economically reasonable.  
(ii) The uncontrolled release of the vapors will not cause a violation of the provisions  
of R 336.1901.  
(4) A person shall not cause or allow the emission of sulfur dioxide from a new  
sweetening facility, unless such emissions are controlled using the best available control  
technology.  
(5) The operator of a sour gas-, crude-, or condensate-sweetening facility-ty shall do  
all of the following:  
(a) Monitor the mass flow rate of hydrogen sulfide either entering the plant or going  
to the waste gas flare or flares on a periodic schedule specified by the department. The  
monitoring program shall include a determination of the hydrogen sulfide concentration  
using colorimetric detector tubes or their equivalent and a determination of the  
volumetric gas flow rate. The monitoring data shall be submitted to the department in an  
acceptable format within 30 days following the end of the month in which the data were  
collected.  
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(b) Provide fencing, warning signs, or other measures as necessary to warn or deter  
unauthorized individuals from entering the plant property or buildings. Signs shall read:  
"Danger--Poison Gas," with at least 1 sign on each side of the plant property.  
(c) Provide control of malodorous emissions from any pressure relief valve or valves,  
storage tanks, and dehydrator vent or vents by burning or equivalent control.  
(d) Conduct a program of continuous monitoring of concentrations of hydrogen  
sulfide in any building enclosing a sweetening process. The sensor shall be placed as  
close to process equipment as practicable. The system shall be designed, installed, and  
maintained to provide a visual alarm when the hydrogen sulfide concentration is more  
than 50 ppm.  
(e) Automatically begin a safe and orderly shutdown of all process inflow streams to  
the facility if the concentration of hydrogen sulfide is more than 100 ppm in any building  
enclosing a sweetening process. Full operation may be resumed only after successful  
corrective measures have been applied.  
(f) Automatically commence shut-in of the facility within 1 second after  
extinguishment of the flare flame, unless otherwise authorized by the department.  
Operation of the facility shall not continue unless corrective measures taken to reignite  
the flame are successful.  
(6) A new sweetening facility shall not be installed at a distance of less than 1,300  
feet from an existing residence, unless otherwise authorized by the department. Such  
authorization shall depend upon a satisfactory showing by a permit applicant that an odor  
nuisance shall not result from a lesser setback distance.  
History: 1980 AACS; 1989 AACS; 2002 AACS.  
R 336.1404 Emission of SO2 and sulfuric acid mist from sulfuric acid plants.  
Rule 404. (1) It is unlawful for a person to cause or allow the emission of sulfuric acid  
mist from any sulfuric acid plant in excess of 0.50 pounds per ton of acid produced, the  
production being expressed as 100% sulfuric acid.  
(2) It is unlawful for a person in Wayne county to cause or allow SO2 emissions into the  
atmosphere from any sulfuric acid plant to exceed 6.5 pounds per ton of acid produced.  
(3) Compliance with this rule must be demonstrated using 40 CFR part 60, appendix A,  
reference test method no. 8, adopted by reference in R 336.1902.  
History: 1980 AACS; 2008 AACS 2013 AACS; 2019 AACS.  
R 336.1405 Emissions from sulfur recovery plants located within Wayne county.  
Rule 405. At sulfur recovery plants located in Wayne county, a person shall not  
cause or allow the emission into the atmosphere of sulfur dioxide, sulfur trioxide, or  
sulfuric acid from any such sulfur recovery plant to exceed 0.01 pounds per pound of  
sulfur produced.  
History: 2008 AACS.  
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R 336.1406 Hydrogen sulfide emissions from facilities located within Wayne  
county.  
Rule 406. (1) A person in Wayne county shall not cause or allow the combustion of  
any refinery process gas stream that contains hydrogen sulfide in a concentration of  
greater than 100 grains per 100 cubic feet of gas without removal of the hydrogen sulfide  
in excess of this concentration.  
(2) When the odor of hydrogen sulfide is found to exist beyond the property line of a  
source, a person in Wayne county shall not cause or allow the concentration of hydrogen  
sulfide to exceed 0.005 parts per million by volume for a maximum period of 2 minutes.  
History: 2008 AACS.  
R 336.1407. Sulfur compound emissions from sources located within Wayne  
county and not previously specified.  
Rule 407. Both of the following apply to process and fuel burning equipment at a  
stationary source located within Wayne county to which the provisions of R 336.1401 to  
R 336.1406 do not apply.  
(a) A person shall not cause or allow the emission into the atmosphere gases with a  
concentration of SO2 greater than 300 parts per million by volume, which shall be  
corrected to 50% excess air.  
(b) A person shall not cause or allow the emission into the atmosphere gases with a  
concentration of sulfuric acid or sulfur trioxide or a combination thereof greater than 15  
milligrams per cubic meter, which shall be corrected to 50% excess air.  
History: 2008 AACS; 2013 AACS.  
R 336.1420 Rescinded.  
History: 2008 AACS; 2013 AACS; 2019 AACS.  
R 336.1430 Emission of SO2 from United States Steel, Great Lakes Works.  
Rule 430. (1) The provisions in this rule supersede the requirements of R 336.1407 that  
apply to United States Steel, Great Lakes Works reheat furnaces and Zug Island boilers  
as referenced in subrules (2) and (3) of this rule.  
(2) All of the following apply to United States Steel, Great Lakes Works, 80” hot strip  
mill reheat furnaces:  
On and after December 31, 2016, the combined SO2 emission rate from the 5 reheat  
furnaces shall not exceed 148 pounds per hour, based on a 1-hour average starting on the  
hour for each clock-hour.  
On and after December 31, 2016, the company shall install, calibrate, maintain, and  
operate in a manner approved by the department devices to separately monitor and record  
the coke oven gas and natural gas usage rates, in cubic feet per hour, for the 5 reheat  
furnaces combined for each hour of operation. The 5 furnaces shall be equipped with a  
common coke oven gas usage meter and a common natural gas usage meter. The  
Page 7  
company shall keep the usage rate records on file at the facility for a period of 5 years, in  
a format acceptable to the department, and make them available to the department upon  
request.  
On and after December 31, 2016, the company shall compile hourly SO2 emission rate  
calculations for the 5 reheat furnaces combined in pounds per hour, for each hour of  
operation. Emission rates shall be determined using the method specified in subrule  
(3)(g) of this rule. The company shall keep the records of the calculations on file at the  
facility for a period of 5 years, in a format acceptable to the department, and make them  
available to the department upon request.  
(d) Not later than June 30, 2017, the company shall conduct SO2 emission stack  
tests of the reheat furnaces, based on testing of a representative furnace. Not less than 30  
days before testing, a complete stack test protocol shall be submitted to the department  
for approval. The final plan must be approved by the department before testing.  
Verification of emission rates includes the submittal of a complete report of the test  
results to the department within 60 days following the last date of the test. The company  
shall keep the records of the test on file at the facility for a period of 5 years, in a format  
acceptable to the department, and make them available to the department upon request.  
(e) On and after September 15, 2017, the company shall submit an excess  
emission report in an acceptable format to the department semiannually. The report shall  
be submitted by September 15 for the January 1 to June 30 reporting period, and by  
March 15 for the July 1 to December 31 reporting period. The excess emission report  
shall include the following information:  
(A) A report of each exceedance above the SO2 limitation including the date, time,  
magnitude, cause, and corrective actions for all occurrences during the reporting period.  
(B) A report of all periods of fuel gas usage rate monitoring system downtime and  
corrective action.  
(C) If no SO2 limitation exceedance and no fuel gas usage rate monitoring system  
downtime occurred during the reporting period, the company shall report that fact.  
(3) All of the following apply to United States Steel, Great Lakes Works, Zug Island  
boiler houses number 1 and 2:  
The following limits shall be met on and after December 31, 2016:  
The combined SO2 emission rate from the number 1 boiler house boilers 1 to 5 shall not  
exceed 15 pounds per hour, based on a 1-hour average starting on the hour for each  
clock-hour.  
(ii) The combined SO2 emission rate from the number 2 boiler house boilers 1 to 5 shall  
not exceed 21 pounds per hour, based on a 1-hour average starting on the hour for each  
clock-hour.  
(iii) The maximum hydrogen sulfide content of the blast furnace gas fired in the boilers  
shall not exceed .0274 grains per dry standard cubic foot, based on a 1-hour average  
starting on the hour for each clock-hour.  
The type of fuels burned in the boilers shall be restricted to blast furnace gas, coke oven  
gas, and natural gas.  
On and after December 31, 2016, the company shall install, calibrate, maintain, and  
operate in a manner approved by the department devices to separately monitor and record  
the coke oven gas, blast furnace gas, and natural gas usage rates in cubic feet per hour for  
the combined number 1 boiler house boilers and for the combined number 2 boiler house  
Page 8  
boilers for each hour of operation. The company shall keep the usage rate records on file  
at the facility for a period of 5 years, in a format acceptable to the department, and make  
them available to the department upon request.  
(d) On and after December 31, 2016, the company shall install, calibrate, maintain, and  
operate in a manner approved by the department devices to monitor and record the blast  
furnace gas hydrogen sulfide content in grains per cubic foot for the blast furnace gas  
fired in the number 1 boiler house boilers 1 to 5 and in the number 2 boiler house boilers  
1 to 5 on a continuous basis to determine the 1-hour average hydrogen sulfide  
concentration in the blast furnace gas for each hour of operation. The company shall  
keep the records of the hydrogen sulfide content on file at the facility for a period of 5  
years, in a format acceptable to the department, and make them available to the  
department upon request.  
(e) On and after December 31, 2016, the company shall compile hourly SO2 emission  
rate calculations separately for the combined number 1 boiler house boilers 1 to 5 and for  
the combined number 2 boiler house boilers 1 to 5 for each hour of operation. Emission  
rates shall be determined using the method specified in subdivision (g) of the subrule.  
The company shall keep the calculation records on file at the facility, for a period of 5  
years, in a format acceptable to the department, and make them available to the  
department upon request.  
(f) On and after September 15, 2017, the company shall submit an excess  
emission report in an acceptable format to the department semiannually. The report shall  
be submitted by September 15 for the January 1 to June 30 reporting period, and by  
March  
15  
for  
the  
July 1 to December 31 reporting period. The excess emission report shall include the  
following information:  
(i) A report of each exceedance above the SO2 and/or hydrogen sulfide limitations  
including the date, time, magnitude, cause, and corrective actions for all occurrences  
during the reporting period.  
(ii) A report of all periods of fuel gas usage rate monitoring system and/or fuel gas  
hydrogen sulfide monitoring system downtime and corrective action.  
(iii) If no SO2 and/or hydrogen sulfide limitation exceedances, no fuel gas usage rate  
monitoring system downtime, or no fuel gas hydrogen sulfide monitoring system  
downtime occurred during the reporting period, the company shall report that fact.  
g) The company shall determine the average hourly SO2 emission rate for the  
group of 5 furnaces or boilers grouped as number 1 boiler house or number 2 boiler house  
boilers subject to subrule (2) or (3) of this rule as specified below or by a method  
approved by the department as required in subrule (4) of this rule:  
HOURLY RATE (lbs SO2/hour) = [COG (1000 ft3/hour) * (0.702 lbs SO2 / 1000 ft3) +  
BFG (ft3/hr) * H2S (gr/ft3 BFG) * (1 lb H2S / 7,000 gr H2S) * (1.88 lb SO2 /lb H2S) + NG  
(1,000,000 ft3/hr)* (0.6 lb SO2 / 1,000,000 ft3)]  
Where:  
HOURLY RATE = boiler house group or furnace group emission rate (lbs SO2/hour).  
Page 9  
COG = actual volume of coke oven gas consumed (1000 ft3 per clock-hour) in a furnace  
group or boiler house group.  
BFG = actual volume of blast furnace gas consumed (ft3 per clock-hour) in a furnace  
group or boiler house group.  
NG = actual volume of natural gas consumed (1,000,000 ft3 per clock-hour) in a furnace  
group or boiler house group.  
H2S = actual concentration of hydrogen sulfide in BFG (gr/ft3) determined on a 1-hour  
average basis for each clock-hour of operation.  
(h) Not later than June 30, 2017, the company shall conduct SO2 emission stack  
tests of a representative boiler in number 1 boiler house and of a representative boiler in  
number 2 boiler house. Not less than 30 days before to testing, a complete stack test  
protocol must be submitted to the department for approval. The final plan must be  
approved by the department before testing. Verification of emission rates includes the  
submittal of a complete report of the test results to the department within 60 days  
following the last date of the test. The company shall keep the records of the test on file  
at the facility for a period of 5 years, in a format acceptable to the department, and make  
them available to the department upon request.  
(4) The emission rate limits in subrules (2)(a) and (3)(a) of this rule, or equivalent limits  
as determined by dispersion modeled SO2 impacts, may be met with several different  
control methods including sulfur dioxide flue gas emission controls, blending of alternate  
lower sulfur content fuels with currently used fuels, application of fuel desulfurization  
control to the currently used coke oven gas and blast furnace gas, use of improved  
dispersion techniques such as use of taller exhaust stacks, or a combination of these  
and/or other control measures. By August 31, 2016, the company shall submit to the  
MDEQ for approval the control methods, control efficiencies as appropriate, and  
associated testing, recordkeeping and reporting methods that the company will use to  
comply with this rule.  
History: 2016 AACS.  
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