Section R. 336.1801 - Emission of oxides of nitrogen (NOx) from non-SIP call stationary sourcesRule 801
(1) As used in this rule:(a) "Btu" means a British thermal unit(b) "Capacity factor" means either of the following:(i) The ratio of a unit's actual annual electric output, expressed in megawatt hour, to the unit's nameplate capacity times 8,760 hours.(ii) The ratio of a unit's annual heat input, expressed in million Btu or equivalent units of measure, to the unit's maximum design heat input, expressed in million Btus per hour or equivalent units of measure, times 8,760 hours.(c) "Electricity-generating utility unit" means a unit that produces electricity for sale.(d) "Fossil fuel-fired" means the actual combustion of fossil fuel, which includes coke oven gas, alone or in combination with any other fuel, where either of the following quantities are greater than 50% on an annual basis:(i) Sum of the mass of fossil fuels combusted divided by the total mass of all fuels combusted.(ii) Sum of the annual heat inputs for fossil fuels combusted divided by the total heat input for all fuels combusted. Annual heat inputs are on a Btu basis.(e) "Low-NOx burners" means 1 of several developing combustion technologies used to minimize the formation of emissions of nitrogen oxides. As applicable to cement kilns, low-NOx burners means a type of cement kiln burner system designed to minimize (NOx) formation by controlling flame turbulence, delaying fuel/air mixing, and establishing fuel-rich zones for initial combusting, that for firing of solid fuel in the burning end zone of a kiln's main burner includes an indirect firing system or comparable technique for the main burner in the burning end zone of the kiln to minimize the amount of primary air supplied through the burner. In an indirect firing system, 1 air stream is used to convey pulverized fuel from the grinding equipment and at least 1 or more other air streams are used to supply primary air to the burning end zone kiln burner of the kiln with the pulverized fuel, with intermediate storage of the fuel, and necessary safety and explosion prevention systems associated with the intermediate storage of fuel.(f) "Mid-kiln system firing" means the secondary firing in a kiln system by injecting solid fuel at an intermediate point in the kiln system using a specially designed heat injection mechanism for the purpose of decreasing NOx emissions through coal burning part of the fuel at lower temperatures and reducing conditions at the fuel injection point that may destroy some of the NOx.(g) "Non-SIP call source" means any stationary source of NOx emissions that is not a NOx budget source subject to R 336.1802.(h) "NOx" means oxides of nitrogen.(i) "Ozone control period" means the period of May 1 through September 30.(j) "Peaking unit" means an electricity-generating utility unit that has an average capacity factor of not more than 10% during the previous 3 calendar years and a capacity factor of not more than 20% in each of those calendar years.(k) "Process heater" means any combustion equipment which is fired by a liquid fuel or a gaseous fuel, or both, and which is used to transfer heat from the combustion gases to a process fluid, superheated steam, or water.(l) "SIP" means state implementation plan.(m) "Unit" means a fossil fuel-fired combustion device.(2) Except as provided in subrule (11) of this rule, any fossil fuel fired unit that meets both of the following requirements is subject to this rule: (a) A unit that has the potential to emit more than 25 tons of NOx each ozone control period.(b) A unit that has a maximum rated heat input capacity of more than 250 million Btu, per hour.(3) An owner or operator of an emission unit subject to this rule shall comply with the following provisions, as applicable: (a) An owner or operator of a fossil fuel-fired, electricity-generating utility unit that serves a generator that has a nameplate capacity of less than 25 megawatts shall comply with the appropriate NOx emission limit in table 81 of this rule.(b) An owner or operator of a fossil fuel-fired boiler or process heater shall meet the emission limits contained in table 81 of this rule.(c) An owner or operator of a gas-fired boiler or process heater that fires gaseous fuel that contains more than 50% hydrogen by volume shall comply with an NOx emission limit of 0.25 pounds per million Btu heat input.(d) An owner or operator of a stationary internal combustion engine that is subject to the provisions of this rule and has a maximum rated heat input capacity that is the heat input at 80 degrees Fahrenheit at sea level and takes into account inlet and exhaust losses shall comply with the following NOx emission limits, as applicable: (i) For a natural gas-fired stationary internal combustion engine - 14 grams of NOx per brake horsepower hour at rated output.(ii) For a diesel-fired stationary internal combustion engine - 10 grams of NOx per brake horsepower hour at rated output.(e) An owner or operator of a cement kiln that is subject to the provisions of this rule shall reduce kiln NOx emissions by any of the following methods:(ii) Mid-kiln system firing.(iii) A 25% rate-based reduction of NOx from 1995 levels. Compliance with this paragraph is based on calculations showing that the emission rate, on a pounds of NOx per ton of clinker produced basis, during each compliance ozone control period, has been reduced below the 1995 ozone control period emission rate by 25%.(f) An owner or operator of a stationary gas turbine that is subject to the provisions of this rule and which has a maximum rated heat input capacity that is the heat input at 80 degrees Fahrenheit at sea level and takes into account inlet and exhaust losses shall comply with an emission limit of 75 parts per million, dry volume, corrected to 15% oxygen, at rated capacity.(4) The method for determining compliance with the emission limits in subrule (3) of this rule is as follows: (a) If the emission limit is in the form of pounds of NOx per million Btu, then the unit is in compliance if the sum of the mass emissions from the unit that occurred during the ozone control period, divided by the sum of the heat input from the unit that occurred during the ozone control period, is less than or equal to the limit in subrule (3) of this rule.(b) For an emission unit not subject to subdivision (a) of this subrule, the method for determining compliance shall be a method acceptable to the department.(5) The owner or operator of a boiler, process heater, stationary internal combustion engine, stationary gas turbine, cement kiln, or any other stationary emission unit that is subject to the provisions of subrule (3) of this rule shall measure NOx emissions by any of the following:(a) Performance tests described in subrule (6) of this rule.(b) Through the use of a continuous emission monitor in accordance with the provisions of subrule (8) of this rule.(c) According to a schedule and using a method acceptable to the department.(6) An owner or operator of an emission unit that measures NOx emissions by performance tests as specified in subrule (5) of this rule shall do all of the following:(a) Conduct an initial performance test not later than 90 days after the compliance deadline. For an emission unit that is not in service on or after the compliance deadline, the owner or operator shall contact the department and schedule an alternate initial performance test as agreed to by the department.(b) After the initial performance test, conduct a compliance performance test each ozone control period or according to the following schedule: (i) After 2 consecutive ozone control periods in which the emission unit demonstrates compliance, an owner or operator shall conduct performance tests at least once every 2 years during the ozone control period.(ii) After a total of 4 consecutive ozone control periods in which the emission unit has remained in compliance, an owner or operator shall conduct performance tests at least once every 5 years during the ozone control period.(c) If an emission unit is not in compliance at the end of an ozone control period, then the owner or operator shall conduct a compliance performance test each ozone control period, but may elect to use the alternative schedule specified in subdivision (b) of this subrule.(d) An owner or operator shall submit 2 copies of each compliance performance test to the department within 60 days after completing the testing. The test results must be presented and include data as requested in the department format for submittal of source emission test plans and reports. All performance test reports must be kept on file at the plant and made available to the department upon request.(7) An owner or operator of an emission unit that is required to conduct performance testing under subrule (5) of this rule shall submit a test plan to the department, not less than 30 days before the scheduled test date. To ensure proper testing, the plan must supply the information in the department format for submittal of source emission test plans and reports. The owner or operator shall give the department a reasonable opportunity to witness the tests.(8) An owner or operator of an emission unit that measures NOx emissions by a continuous emission monitoring system or an alternate method, as specified in subrule (5) of this rule, shall do either of the following:(a) Use the procedures set forth in 40 CFR part 60, subpart A and appendix B, adopted by reference in R 336.1902 and comply with the quality assurance procedures in part 60, appendix F, adopted by reference in R 336.1902 or 40 CFR part 75, adopted by reference in R 336.1902 and associated appendices, as applicable and acceptable to the department.(b) Use a previously installed continuous emission monitoring system to demonstrate compliance with this rule as long as the previously installed continuous emission monitoring system monitors NOx pursuant to other applicable federal, state, or local rules, meets the installation, testing, operation, calibration, and reporting requirements specified by those federal, state, or local rules, and is acceptable to the department.(9) The owner or operator of an emission unit that is subject to this rule shall submit a summary report, in an acceptable format, to the department within 60 days after the end of each ozone control period. The report must include all of the following information: (a) The date, time, magnitude of emissions, and emission rates where applicable, of the specified emission unit.(b) If emissions or emission rates exceed the emissions or rates allowed for in the ozone control period by the applicable emission limit, the cause, if known, and any corrective action taken.(c) The total operating time of the emission unit during the ozone control period.(d) For continuous emission monitoring systems, system performance information shall include the date and time of each period during which the continuous monitoring system was inoperative, except for zero and span checks, and the nature of the system repairs or adjustments. When the continuous monitoring system has not been inoperative, repaired, or adjusted, the information must be stated in the report.(10) Table 81 reads as follows: Table 81
Boilers and process heaters with heat input capacity of 250 million Btu or more NOx emission limitations (pounds NOx per million Btu of heat input averaged over the ozone control period) |
Fuel type | Emission limit |
Natural gas | 0.20 |
Distillate oil | 0.30 |
Residual oil | 0.40 |
Coal (1) Coal spreader stoker (2) Pulverized coal fired | 0.40 0.40 |
Gas (other than natural gas)1 | 0.25 |
For units operating with a combination of gas, oil, or coal, a variable emission limit calculated as the heat input weighted average of the applicable emission limits must be used. The emission limit is determined as follows: Emission limit = a(0.20) + b(applicable oil limit) + c(applicable coal limit) + d(0.25) Where: a = Is the percentage of total heat input from natural gas b = Is the percentage of total heat input from oil c = Is the percentage of total heat input from coal d = Is the percentage of total heat input from gas (other than natural gas) |
1 This may include a mixture of gases. In this case, natural gas may be part of the mixture.
(11) The provisions of this rule do not apply to the following emission unit or units:(a) A unit that is subject to NOx standards or a NOx federal trading programs that have been promulgated in a federal implementation plan under section 110(c) of the clean air act, 42 USC 7410, required under section 126 of the clean air act, 42 USC 7426, or promulgated in a federal regulation under 40 CFR part 51, part 60, or part 97.(b) A unit that is subject to any other rule included in this part.(c) A peaking unit. The owner or operator shall retain records of capacity for a period of 5 years demonstrating that the unit meets the definition of a peaking unit. The unit becomes subject to the provisions of this rule on January 1 of the year following failure to meet the peaking unit definition.(d) A stationary gas turbine that is subject to a new source performance standard contained in 40 CFR part 60, subpart GG or KKKK, adopted by reference in R 336.1902.Mich. Admin. Code R. 336.1801
1998-2000 AACS; 2002 AACS; 2009 AACS; 2022 MR 9, Eff. 5/13/2022