40 CFR Appendix F to Part 75 - Conversion Procedures

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TITLE 40 - PROTECTION OF ENVIRONMENT

CHAPTER I - ENVIRONMENTAL PROTECTION AGENCY

SUBCHAPTER C - AIR PROGRAMS

PART 75 - CONTINUOUS EMISSION MONITORING

subpart i - HG MASS EMISSION PROVISIONS

Appendix F to Part 75 - Conversion Procedures

1.Applicability Use the procedures in this appendix to convert measured data from a monitor or continuous emission monitoring system into the appropriate units of the standard.

2.Procedures for SO2 Emissions Use the following procedures to compute hourly SO2 mass emission rate (in lb/hr) and quarterly and annual SO2 total mass emissions (in tons).

Use the procedures in Method 19 in appendix A to part 60 of this chapter to compute hourly SO2 emission rates (in lb/mmBtu) for qualifying Phase I technologies. When computing hourly SO2 emission rate in lb/mmBtu, a minimum concentration of 5.0 percent CO2 and a maximum concentration of 14.0 percent O2 may be substituted for measured diluent gas concentration values at boilers during hours when the hourly average concentration of CO2 is less than 5.0 percent CO2 or the hourly average concentration of O2 is greater than 14.0 percent O2.

2.1When measurements of SO2 concentration and flow rate are on a wet basis, use the following equation to compute hourly SO2 mass emission rate (in lb/hr): (image) View or download PDF Where: Eh = Hourly SO2 mass emission rate during unit operation, lb/hr.

K = 1.660 107 for SO2, (lb/scf)/ppm.

Ch = Hourly average SO2 concentration during unit operation, stack moisture basis, ppm.

Qh = Hourly average volumetric flow rate during unit operation, stack moisture basis, scfh.

2.2When measurements by the SO2 pollutant concentration monitor are on a dry basis and the flow rate monitor measurements are on a wet basis, use the following equation to compute hourly SO2 mass emission rate (in lb/hr): (image) View or download PDF where: Eh = Hourly SO2 mass emission rate during unit operation, lb/hr.

K = 1.660107 for SO2, (lb/scf)/ppm.

Chp = Hourly average SO2 concentration during unit operation, ppm (dry).

Qhs = Hourly average volumetric flow rate during unit operation, scfh as measured (wet).

%H2O = Hourly average stack moisture content during unit operation, percent by volume.

2.3Use the following equations to calculate total SO2 mass emissions for each calendar quarter (Equation F3) and for each calendar year (Equation F4), in tons: (image) (Eq. F3) Where: Eq = Quarterly total SO2 mass emissions, tons.

Eh = Hourly SO2 mass emission rate, lb/hr.

th = Unit operating time, hour or fraction of an hour (in equal increments that can range from one hundredth to one quarter of an hour, at the option of the owner or operator).

n = Number of hourly SO2 emissions values during calendar quarter.

2000 = Conversion of 2000 lb per ton. (image) View or download PDF Where: Ea = Annual total SO2 mass emissions, tons.

Eq = Quarterly SO2 mass emissions, tons.

q = Quarters for which Eq are available during calendar year.

2.4Round all SO2 mass emission rates and totals to the nearest tenth.

3.Procedures for NOX Emission Rate Use the following procedures to convert continuous emission monitoring system measurements of NOX concentration (ppm) and diluent concentration (percentage) into NOX emission rates (in lb/mmBtu). Perform measurements of NOX and diluent (O2 or CO2) concentrations on the same moisture (wet or dry) basis.

3.1When the NOX continuous emission monitoring system uses O2 as the diluent, and measurements are performed on a dry basis, use the following conversion procedure: (image) (Eq. F5) where, K, E, Ch, F, and %O2 are defined in section 3.3 of this appendix. When measurements are performed on a wet basis, use the equations in method 19 in appendix A of part 60 of this chapter.

3.2When the NOX continuous emission monitoring system uses CO2 as the diluent, use the following conversion procedure: (image) (Eq. F6) where: K, E, Ch, Fc, and %CO2 are defined in section 3.3 of this appendix.

When CO2 and NOX measurements are performed on a different moisture basis, use the equations in method 19 in appendix A of part 60 of this chapter.

3.3Use the definitions listed below to derive values for the parameters in equations F5 and F6 of this appendix.

3.3.1K=1.194107 (lb/dscf)/ppm NOX.

3.3.2E = Pollutant emissions during unit operation, lb/mmBtu.

3.3.3Ch = Hourly average pollutant concentration during unit operation, ppm.

3.3.4%O2, %CO2 = Oxygen or carbon dioxide volume during unit operation (expressed as percent O2 or CO2). A minimum concentration of 5.0 percent CO2 and a maximum concentration of 14.0 percent O2 may be substituted for measured diluent gas concentration values at boilers during hours when the hourly average concentration of CO2 is < 5.0 percent CO2 or the hourly average concentration of O2 is > 14.0 percent O2. A minimum concentration of 1.0 percent CO2 and a maximum concentration of 19.0 percent O2 may be substituted for measured diluent gas concentration values at stationary gas turbines during hours when the hourly average concentration of CO2 is < 1.0 percent CO2 or the hourly average concentration of O2 is > 19.0 percent O2.

3.3.5F, Fc=a factor representing a ratio of the volume of dry flue gases generated to the caloric value of the fuel combusted (F), and a factor representing a ratio of the volume of CO2 generated to the calorific value of the fuel combusted (Fc), respectively. Table 1 lists the values of F and Fc for different fuels.

Table 1_F- and Fc-Factors \1\ ------------------------------------------------------------------------ F-factor (dscf/ Fc-factor (scf Fuel mmBtu) CO2/mmBtu) ------------------------------------------------------------------------ Coal (as defined by ASTM D388-92): Anthracite............................ 10,100 1,970 Bituminous and subbituminous.......... 9,780 1,800 Lignite............................... 9,860 1,910 Oil..................................... 9,190 1,420 Gas: Natural gas........................... 8,710 1,040 Propane............................... 8,710 1,190 Butane................................ 8,710 1,250 Wood: Bark.................................. 9,600 1,920 Wood residue.......................... 9,240 1,830 ------------------------------------------------------------------------ \1\ Determined at standard conditions: 20 C (68 F) and 29.92 inches of mercury.

3.3.6Equations F7a and F7b may be used in lieu of the F or Fc factors specified in section 3.3.5 of this appendix to calculate an F factor (dscf/mmBtu) on a dry basis or an Fc factor (scf CO2/mmBtu) on either a dry or wet basis.

(Calculate all F- and Fc factors at standard conditions of 20 C (68 F) and 29.92 inches of mercury.) (image) (Eq. F7a) (image) (Eq. F7b) 3.3.6.1H, C, S, N, and O are content by weight of hydrogen, carbon, sulfur, nitrogen, and oxygen (expressed as percent), respectively, as determined on the same basis as the gross calorific value (GCV) by ultimate analysis of the fuel combusted using ASTM D317689, Standard Practice for Ultimate Analysis of Coal and Coke (solid fuels), ASTM D529192, Standard Test Methods for Instrumental Determination of Carbon, Hydrogen, and Nitrogen in Petroleum Products and Lubricants (liquid fuels) or computed from results using ASTM D194591, Standard Test Method for Analysis of Natural Gas by Gas Chromatography or ASTM D194690, Standard Practice for Analysis of Reformed Gas by Gas Chromatography (gaseous fuels) as applicable. (These methods are incorporated by reference under 75.6 of this part.) 3.3.6.2GCV is the gross calorific value (Btu/lb) of the fuel combusted determined by ASTM D201591, Standard Test Method for Gross Calorific Value of Coal and Coke by the Adiabatic Bomb Calorimeter, ASTM D198992 Standard Test Method for Gross Calorific Value of Coal and Coke by Microprocessor Controlled Isoperibol Calorimeters, or ASTM D328691a Standard Test Method for Gross Calorific Value of Coal and Coke by the Isoperibol Bomb Calorimeter for solid and liquid fuels, and ASTM D24087 (Reapproved 1991) Standard Test Method for Heat of Combustion of Liquid Hydrocarbon Fuels by Bomb Calorimeter, or ASTM D238288 Standard Test Method for Heat of Combustion of Hydrocarbon Fuels by Bomb Calorimeter (High-Precision Method) for oil; and ASTM D358891 Standard Practice for Calculating Heat Value, Compressibility Factor, and Relative Density (Specific Gravity) of Gaseous Fuels, ASTM D489189 Standard Test Method for Heating Value of Gases in Natural Gas Range by Stoichiometric Combustion, GPA Standard 2172 86 Calculation of Gross Heating Value, Relative Density and Compressibility Factor for Natural Gas Mixtures from Compositional Analysis, GPA Standard 226190 Analysis for Natural Gas and Similar Gaseous Mixtures by Gas Chromatography, or ASTM D182688, Standard Test Method for Calorific (Heating) Value of Gases in Natural Gas Range by Continuous Recording Calorimeter for gaseous fuels, as applicable. (These methods are incorporated by reference under 75.6).

3.3.6.3For affected units that combust a combination of fossil (coal, oil and gas) and nonfossil (e.g., bark, wood, residue, or refuse) fuels, the F or Fc value is subject to the Administrator's approval.

3.3.6.4For affected units that combust combinations of fossil fuels or fossil fuels and wood residue, prorate the F or Fc factors determined by section 3.3.5 of this appendix in accordance with the applicable formula as follows: (image) (Eq. F8) where, Xi = Fraction of total heat input derived from each type of fuel (e.g., natural gas, bituminous coal, wood).

Fi or (Fc)i = Applicable F or Fc factor for each fuel type determined in accordance with section 3.3.5 of this appendix.

n = Number of fuels being combusted in combination.

3.4Use the following equations to calculate the average NOX emission rate for each calendar quarter (Equation F9) and the average emission rate for the calendar year (Equation F10), in lb/mmBtu: (image) View or download PDF Where: Eq = Quarterly average NOX emission rate, lb/mmBtu.

Ei = Hourly average NOX emission rate during unit operation, lb/mmBtu.

n = Number of hourly rates during calendar quarter. (image) View or download PDF Where: Ea = Average NOX emission rate for the calendar year, lb/mmBtu.

Ei = Hourly average NOX emission rate during unit operation, lb/mmBtu.

m = Number of hourly rates for which Ei is available in the calendar year.

3.5Round all NOX emission rates to the nearest 0.001 lb/mmBtu.

4.Procedures for CO2 Mass Emissions Use the following procedures to convert continuous emission monitoring system measurements of CO2 concentration (percentage) and volumetric flow rate (scfh) into CO2 mass emissions (in tons/day) when the owner or operator uses a CO2 continuous emission monitoring system (consisting of a CO2 or O2 pollutant monitor) and a flow monitoring system to monitor CO2 emissions from an affected unit.

4.1When CO2 concentration is measured on a wet basis, use the following equation to calculate hourly CO2 mass emissions rates (in tons/hr): (image) View or download PDF Where: Eh = Hourly CO2 mass emission rate during unit operation, tons/hr.

K = 5.7107 for CO2, (tons/scf) /%CO2.

Ch = Hourly average CO2 concentration during unit operation, wet basis, percent CO2. For boilers, a minimum concentration of 5.0 percent CO2 may be substituted for the measured concentration when the hourly average concentration of CO2 is < 5.0 percent CO2, provided that this minimum concentration of 5.0 percent CO2 is also used in the calculation of heat input for that hour. For stationary gas turbines, a minimum concentration of 1.0 percent CO2 may be substituted for measured diluent gas concentration values during hours when the hourly average concentration of CO2 is < 1.0 percent CO2, provided that this minimum concentration of 1.0 percent CO2 is also used in the calculation of heat input for that hour.

Qh = Hourly average volumetric flow rate during unit operation, wet basis, scfh.

4.2When CO2 concentration is measured on a dry basis, use Equation F2 to calculate the hourly CO2 mass emission rate (in tons/hr) with a K-value of 5.7107 (tons/scf) percent CO2, where Eh = hourly CO2 mass emission rate, tons/hr and Chp = hourly average CO2 concentration in flue, dry basis, percent CO2.

4.3Use the following equations to calculate total CO2 mass emissions for each calendar quarter (Equation F12) and for each calendar year (Equation F13): (image) View or download PDF Where: ECO2q = Quarterly total CO2 mass emissions, tons.

Eh = Hourly CO2 mass emission rate, tons/hr.

th=Unit operating time, in hours or fraction of an hour (in equal increments that can range from one hundredth to one quarter of an hour, at the option of the owner or operator).

HR = Number of hourly CO2 mass emission rates available during calendar quarter. (image) View or download PDF Where: ECO2a = Annual total CO2 mass emissions, tons.

ECO2q = Quarterly total CO2 mass emissions, tons.

q = Quarters for which ECO2q are available during calendar year.

4.4For an affected unit, when the owner or operator is continuously monitoring O2 concentration (in percent by volume) of flue gases using an O2 monitor, use the equations and procedures in section 4.4.1 and 4.4.2 of this appendix to determine hourly CO2 mass emissions (in tons).

4.4.1Use appropriate F and Fc factors from section 3.3.5 of this appendix in one of the following equations (as applicable) to determine hourly average CO2 concentration of flue gases (in percent by volume): (image) View or download PDF Where: CO2d = Hourly average CO2 concentration during unit operation, percent by volume, dry basis.

F, Fc = F-factor or carbon-based Fc-factor from section 3.3.5 of this appendix.

20.9 = Percentage of O2 in ambient air.

O2d = Hourly average O2 concentration during unit operation, percent by volume, dry basis. For boilers, a maximum concentration of 14.0 percent O2 may be substituted for the measured concentration when the hourly average concentration of O2 is > 14.0 percent O2, provided that this maximum concentration of 14.0 percent O2 is also used in the calculation of heat input for that hour. For stationary gas turbines, a maximum concentration of 19.0 percent O2 may be substituted for measured diluent gas concentration values during hours when the hourly average concentration of O2 is > 19.0 percent O2, provided that this maximum concentration of 19.0 percent O2 is also used in the calculation of heat input for that hour. (image) View or download PDF Where: CO2w = Hourly average CO2 concentration during unit operation, percent by volume, wet basis.

O2w = Hourly average O2 concentration during unit operation, percent by volume, wet basis. For boilers, a maximum concentration of 14.0 percent O2 may be substituted for the measured concentration when the hourly average concentration of O2 is > 14.0 percent O2, provided that this maximum concentration of 14.0 percent O2 is also used in the calculation of heat input for that hour. For stationary gas turbines, a maximum concentration of 19.0 percent O2 may be substituted for measured diluent gas concentration values during hours when the hourly average concentration of O2 is > 19.0 percent O2, provided that this maximum concentration of 19.0 percent O2 is also used in the calculation of heat input for that hour.

F, Fc = F-factor or carbon-based Fc-factor from section 3.3.5 of this appendix.

20.9 = Percentage of O2 in ambient air.

%H2O = Moisture content of gas in the stack, percent.

4.4.2Determine CO2 mass emissions (in tons) from hourly average CO2 concentration (percent by volume) using equation F11 and the procedure in section 4.1, where O2 measurements are on a wet basis, or using the procedures in section 4.2 of this appendix, where O2 measurements are on a dry basis.

5.Procedures for Heat Input Use the following procedures to compute heat input rate to an affected unit (in mmBtu/hr or mmBtu/day): 5.1Calculate and record heat input rate to an affected unit on an hourly basis, except as provided in sections 5.5 through 5.5.7. The owner or operator may choose to use the provisions specified in 75.16(e) or in section 2.1.2 of appendix D to this part in conjunction with the procedures provided in sections 5.6 through 5.6.2 to apportion heat input among each unit using the common stack or common pipe header.

5.2For an affected unit that has a flow monitor (or approved alternate monitoring system under subpart E of this part for measuring volumetric flow rate) and a diluent gas (O2 or CO2) monitor, use the recorded data from these monitors and one of the following equations to calculate hourly heat input rate (in mmBtu/hr).

5.2.1When measurements of CO2 concentration are on a wet basis, use the following equation: (image) View or download PDF Where: HI = Hourly heat input rate during unit operation, mmBtu/hr.

Qw = Hourly average volumetric flow rate during unit operation, wet basis, scfh.

Fc = Carbon-based F-factor, listed in section 3.3.5 of this appendix for each fuel, scf/mmBtu.

%CO2w = Hourly concentration of CO2 during unit operation, percent CO2 wet basis. For boilers, a minimum concentration of 5.0 percent CO2 may be substituted for the measured concentration when the hourly average concentration of CO2 is < 5.0 percent CO2, provided that this minimum concentration of 5.0 percent CO2 is also used in the calculation of CO2 mass emissions for that hour. For stationary gas turbines, a minimum concentration of 1.0 percent CO2 may be substituted for measured diluent gas concentration values during hours when the hourly average concentration of CO2 is < 1.0 percent CO2, provided that this minimum concentration of 1.0 percent CO2 is also used in the calculation of CO2 mass emissions for that hour.

5.2.2When measurements of CO2 concentration are on a dry basis, use the following equation: (image) View or download PDF Where: HI = Hourly heat input rate during unit operation, mmBtu/hr.

Qh = Hourly average volumetric flow rate during unit operation, wet basis, scfh.

Fc = Carbon-based F-Factor, listed in section 3.3.5 of this appendix for each fuel, scf/mmBtu.

%CO2d = Hourly concentration of CO2 during unit operation, percent CO2 dry basis. For boilers, a minimum concentration of 5.0 percent CO2 may be substituted for the measured concentration when the hourly average concentration of CO2 is < 5.0 percent CO2, provided that this minimum concentration of 5.0 percent CO2 is also used in the calculation of CO2 mass emissions for that hour. For stationary gas turbines, a minimum concentration of 1.0 percent CO2 may be substituted for measured diluent gas concentration values during hours when the hourly average concentration of CO2 is < 1.0 percent CO2, provided that this minimum concentration of 1.0 percent CO2 is also used in the calculation of CO2 mass emissions for that hour.

%H2O = Moisture content of gas in the stack, percent.

5.2.3When measurements of O2 concentration are on a wet basis, use the following equation: (image) View or download PDF Where: HI = Hourly heat input rate during unit operation, mmBtu/hr.

Qw = Hourly average volumetric flow rate during unit operation, wet basis, scfh.

F = Dry basis F-factor, listed in section 3.3.5 of this appendix for each fuel, dscf/mmBtu.

%O2w = Hourly concentration of O2 during unit operation, percent O2 wet basis. For boilers, a maximum concentration of 14.0 percent O2 may be substituted for the measured concentration when the hourly average concentration of O2 is > 14.0 percent O2, provided that this maximum concentration of 14.0 percent O2 is also used in the calculation of CO2 mass emissions for that hour. For stationary gas turbines, a maximum concentration of 19.0 percent O2 may be substituted for measured diluent gas concentration values during hours when the hourly average concentration of O2 is > 19.0 percent O2, provided that this maximum concentration of 19.0 percent O2 is also used in the calculation of CO2 mass emissions for that hour.

%H2O = Hourly average stack moisture content, percent by volume.

5.2.4When measurements of O2 concentration are on a dry basis, use the following equation: (image) View or download PDF Where: HI = Hourly heat input rate during unit operation, mmBtu/hr.

Qw = Hourly average volumetric flow during unit operation, wet basis, scfh.

F = Dry basis F-factor, listed in section 3.3.5 of this appendix for each fuel, dscf/mmBtu.

%H2O = Moisture content of the stack gas, percent.

%O2d = Hourly concentration of O2 during unit operation, percent O2 dry basis. For boilers, a maximum concentration of 14.0 percent O2 may be substituted for the measured concentration when the hourly average concentration of O2 is > 14.0 percent O2, provided that this maximum concentration of 14.0 percent O2 is also used in the calculation of CO2 mass emissions for that hour. For stationary gas turbines, a maximum concentration of 19.0 percent O2 may be substituted for measured diluent gas concentration values during hours when the hourly average concentration of O2 is > 19.0 percent O2, provided that this maximum concentration of 19.0 percent O2 is also used in the calculation of CO2 mass emissions for that hour.

5.3Heat Input Summation (for Heat Input Determined Using a Flow Monitor and Diluent Monitor) 5.3.1 Calculate total quarterly heat input for a unit or common stack using a flow monitor and diluent monitor to calculate heat input, using the following equation: (image) View or download PDF Where: HIq = Total heat input for the quarter, mmBtu.

HIi = Hourly heat input rate during unit operation, using Equation F15, F16, F17, or F18, mmBtu/hr.

ti = Hourly operating time for the unit or common stack, hour or fraction of an hour (in equal increments that can range from one hundredth to one quarter of an hour, at the option of the owner or operator).

5.3.2Calculate total cumulative heat input for a unit or common stack using a flow monitor and diluent monitor to calculate heat input, using the following equation: (image) View or download PDF Where: HIc = Total heat input for the year to date, mmBtu.

HIq = Total heat input for the quarter, mmBtu.

5.4 [Reserved] 5.5For a gas-fired or oil-fired unit that does not have a flow monitor and is using the procedures specified in appendix D to this part to monitor SO2 emissions or for any unit using a common stack for which the owner or operator chooses to determine heat input by fuel sampling and analysis, use the following procedures to calculate hourly heat input rate in mmBtu/hr. The procedures of section 5.5.3 of this appendix shall not be used to determine heat input from a coal unit that is required to comply with the provisions of this part for monitoring, recording, and reporting NOX mass emissions under a State or federal NOX mass emission reduction program.

5.5.1(a) When the unit is combusting oil, use the following equation to calculate hourly heat input rate: (image) View or download PDF Where: HIo = Hourly heat input rate from oil, mmBtu/hr.

Mo = Mass rate of oil consumed per hour, as determined using procedures in appendix D to this part, in lb/hr, tons/hr, or kg/hr.

GCVo = Gross calorific value of oil, as measured by ASTM D24087 (Reapproved 1991), ASTM D201591, or ASTM D238288 for each oil sample under section 2.2 of appendix D to this part, Btu/unit mass (incorporated by reference under 75.6).

106 = Conversion of Btu to mmBtu.

  (b) When performing oil sampling and analysis solely for the purpose of the missing data procedures in 75.36, oil samples for measuring GCV may be taken weekly, and the procedures specified in appendix D to this part for determining the mass rate of oil consumed per hour are optional.

5.5.2When the unit is combusting gaseous fuels, use the following equation to calculate heat input rate from gaseous fuels for each hour: (image) View or download PDF Where: HIg = Hourly heat input rate from gaseous fuel, mmBtu/hour.

Qg = Metered flow rate of gaseous fuel combusted during unit operation, hundred standard cubic feet per hour.

GCVg = Gross calorific value of gaseous fuel, as determined by sampling (for each delivery for gaseous fuel in lots, for each daily gas sample for gaseous fuel delivered by pipeline, for each hourly average for gas measured hourly with a gas chromatograph, or for each monthly sample of pipeline natural gas, or as verified by the contractual supplier at least once every month pipeline natural gas is combusted, as specified in section 2.3 of appendix D to this part) using ASTM D182688, ASTM D358891, ASTM D489189, GPA Standard 217286 Calculation of Gross Heating Value, Relative Density and Compressibility Factor for Natural Gas Mixtures from Compositional Analysis, or GPA Standard 226190 Analysis for Natural Gas and Similar Gaseous Mixtures by Gas Chromatography, Btu/100 scf (incorporated by reference under 75.6).

106 = Conversion of Btu to mmBtu.

5.5.3When the unit is combusting coal, use the procedures, methods, and equations in sections 5.5.3.15.5.3.3 of this appendix to determine the heat input from coal for each 24-hour period. (All ASTM methods are incorporated by reference under 75.6 of this part.) 5.5.3.1Perform coal sampling daily according to section 5.3.2.2 in Method 19 in appendix A to part 60 of this chapter and use ASTM Method D223489, Standard Test Methods for Collection of a Gross Sample of Coal, (incorporated by reference under 75.6) Type I, Conditions A, B, or C and systematic spacing for sampling. (When performing coal sampling solely for the purposes of the missing data procedures in 75.36, use of ASTM D223489 is optional, and coal samples may be taken weekly.) 5.5.3.2Use ASTM D201386, Standard Method of Preparing Coal Samples for Analysis, for preparation of a daily coal sample and analyze each daily coal sample for gross calorific value using ASTM D201591, Standard Test Method for Gross Calorific Value of Coal and Coke by the Adiabatic Bomb Calorimeter, ASTM 198992 Standard Test Method for Gross Calorific Value of Coal and Coke by Microprocessor Controlled Isoperibol Calorimeters, or ASTM 328691a Standard Test Method for Gross Calorific Value of Coal and Coke by the Isoperibol Bomb Calorimeter. (All ASTM methods are incorporated by reference under 75.6 of this part.) On-line coal analysis may also be used if the on-line analytical instrument has been demonstrated to be equivalent to the applicable ASTM methods under 75.23 and 75.66.

5.5.3.3Calculate the heat input from coal using the following equation: (image) (Eq. F21) where: HIc = Daily heat input from coal, mmBtu/day.

Mc = Mass of coal consumed per day, as measured and recorded in company records, tons.

GCVc = Gross calorific value of coal sample, as measured by ASTM D317689, D198992, D328691a, or D201591, Btu/lb.

500 = Conversion of Btu/lb to mmBtu/ton.

5.5.4For units obtaining heat input values daily instead of hourly, apportion the daily heat input using the fraction of the daily steam load or daily unit operating load used each hour in order to obtain HIi for use in the above equations. Alternatively, use the hourly mass of coal consumed in equation F21.

5.5.5If a daily fuel sampling value for gross calorific value is not available, substitute the maximum gross calorific value measured from the previous 30 daily samples. If a monthly fuel sampling value for gross calorific value is not available, substitute the maximum gross calorific value measured from the previous 3 monthly samples.

5.5.6If a fuel flow value is not available, use the fuel flowmeter missing data procedures in section 2.4 of appendix D of this part. If a daily coal consumption value is not available, substitute the maximum fuel feed rate during the previous thirty days when the unit burned coal.

5.5.7Results for samples must be available no later than thirty calendar days after the sample is composited or taken. However, during an audit, the Administrator may require that the results be available in five business days, or sooner if practicable.

5.6Heat Input Rate Apportionment for Units Sharing a Common Stack or Pipe 5.6.1Where applicable, the owner or operator of an affected unit that determines heat input rate at the unit level by apportioning the heat input monitored at a common stack or common pipe using megawatts shall apportion the heat input rate using the following equation: (image) View or download PDF Where: HIi = Heat input rate for a unit, mmBtu/hr.

HIcs = Heat input rate at the common stack or pipe, mmBtu/hr.

MWi = Gross electrical output, MWe.

ti = Unit operating time, hour or fraction of an hour (in equal increments that can range from one hundredth to one quarter of an hour, at the option of the owner or operator).

tCS = Common stack or common pipe operating time, hour or fraction of an hour (in equal increments that can range from one hundredth to one quarter of an hour, at the option of the owner or operator).

n = Total number of units using the common stack or pipe.

i = Designation of a particular unit.

5.6.2Where applicable, the owner or operator of an affected unit that determines the heat input rate at the unit level by apportioning the heat input rate monitored at a common stack or common pipe using steam load shall apportion the heat input rate using the following equation: (image) View or download PDF Where: HIi = Heat input rate for a unit, mmBtu/hr.

HICS = Heat input rate at the common stack or pipe, mmBtu/hr.

SF = Gross steam load, lb/hr.

ti = Unit operating time, hour or fraction of an hour (in equal increments that can range from one hundredth to one quarter of an hour, at the option of the owner or operator).

tCS = Common stack or common pipe operating time, hour or fraction of an hour (in equal increments that can range from one hundredth to one quarter of an hour, at the option of the owner or operator).

n = Total number of units using the common stack or pipe.

i = Designation of a particular unit.

5.7Heat Input Rate Summation for Units with Multiple Stacks or Pipes The owner or operator of an affected unit that determines the heat input rate at the unit level by summing the heat input rates monitored at multiple stacks or multiple pipes shall sum the heat input rates using the following equation: (image) View or download PDF Where: HIUnit = Heat input rate for a unit, mmBtu/hr.

HIs = Heat input rate for the individual stack, duct, or pipe, mmBtu/hr.

tUnit = Unit operating time, hour or fraction of the hour (in equal increments that can range from one hundredth to one quarter of an hour, at the option of the owner or operator).

ts = Operating time for the individual stack or pipe, hour or fraction of the hour (in equal increments that can range from one hundredth to one quarter of an hour, at the option of the owner or operator).

s = Designation for a particular stack, duct, or pipe.

5.8Alternate Heat Input Apportionment for Common Pipes As an alternative to using Equation F21a or F21b in section 5.6 of this appendix, the owner or operator may apportion the heat input rate at a common pipe to the individual units served by the common pipe based on the fuel flow rate to the individual units, as measured by uncertified fuel flowmeters. This option may only be used if a fuel flowmeter system that meets the requirements of appendix D to this part is installed on the common pipe. If this option is used, determine the unit heat input rates using the following equation: (image) Where: HIi = Heat input rate for a unit, mmBtu/hr.

HICP = Heat input rate at the common pipe, mmBtu/hr.

FFi = Fuel flow rate to a unit, gal/min, 100 scfh, or other appropriate units.

ti = Unit operating time, hour or fraction of an hour (in equal increments that can range from one hundredth to one quarter of an hour, at the option of the owner or operator).

tCP = Common pipe operating time, hour or fraction of an hour (in equal increments that can range from one hundredth to one quarter of an hour, at the option of the owner or operator).

n = Total number of units using the common pipe.

i = Designation of a particular unit.

6.Procedure for Converting Volumetric Flow to STP Use the following equation to convert volumetric flow at actual temperature and pressure to standard temperature and pressure.

FSTP = FActual(TStd/TStack)(PStack/PStd) where: FSTP = Flue gas volumetric flow rate at standard temperature and pressure, scfh.

FActual = Flue gas volumetric flow rate at actual temperature and pressure, acfh.

TStd = Standard temperature=528 R.

TStack = Flue gas temperature at flow monitor location, R, where R=460+ F.

PStack = The absolute flue gas pressure=barometric pressure at the flow monitor location + flue gas static pressure, inches of mercury.

PStd = Standard pressure = 29.92 inches of mercury.

7.Procedures for SO2 Mass Emissions at Units With SO2 Continuous Emission Monitoring Systems During the Combustion of Pipeline Natural Gas or Natural Gas The owner or operator shall use the following equation to calculate hourly SO2 mass emissions as allowed for units with SO2 continuous emission monitoring systems if, during the combustion of gaseous fuel that meets the definition of pipeline natural gas or natural gas in 72.2 of this chapter, SO2 emissions are determined in accordance with 75.11(e)(1). (image) View or download PDF Where: Eh = Hourly SO2 mass emission rate, lb/hr.

ER = Applicable SO2 default emission rate from section 2.3.1.1 or 2.3.2.1.1 of appendix D to this part, lb/mmBtu.

HI = Hourly heat input rate, as determined using the procedures of section 5.2 of this appendix, mmBtu/hr.

8.Procedures for NOX Mass Emissions The owner or operator of a unit that is required to monitor, record, and report NOX mass emissions under a State or federal NOX mass emission reduction program must use the procedures in section 8.1, 8.2, or 8.3, as applicable, to account for hourly NOX mass emissions, and the procedures in section 8.4 to account for quarterly, seasonal, and annual NOX mass emissions to the extent that the provisions of subpart H of this part are adopted as requirements under such a program.

8.1Use the following procedures to calculate hourly NOX mass emissions in lbs for the hour using hourly NOX emission rate and heat input.

8.1.1If both NOX emission rate and heat input rate are monitored at the same unit or stack level (e.g, the NOX emission rate value and heat input rate value both represent all of the units exhausting to the common stack), use the following equation: (image) where: M(NOx)h = NOX mass emissions in lbs for the hour.

E(NOx)h = Hourly average NOX emission rate for hour h, lb/mmBtu, from section 3 of this appendix, from method 19 of appendix A to part 60 of this chapter, or from section 3.3 of appendix E to this part. (Include bias-adjusted NOX emission rate values, where the bias-test procedures in appendix A to this part shows a bias-adjustment factor is necessary.) HIh = Hourly average heat input rate for hour h, mmBtu/hr. (Include bias-adjusted flow rate values, where the bias-test procedures in appendix A to this part shows a bias-adjustment factor is necessary.) th = Monitoring location operating time for hour h, in hours or fraction of an hour (in equal increments that can range from one hundredth to one quarter of an hour, at the option of the owner or operator). If the combined NOX emission rate and heat input are monitored for all of the units in a common stack, the monitoring location operating time is equal to the total time when any of those units was exhausting through the common stack.

8.1.2If NOX emission rate is measured at a common stack and heat input is measured at the unit level, sum the hourly heat inputs at the unit level according to the following formula: (image) where: HICS = Hourly average heat input rate for hour h for the units at the common stack, mmBtu/hr.

tCS = Common stack operating time for hour h, in hours or fraction of an hour (in equal increments that can range from one hundredth to one quarter of an hour, at the option of the owner or operator). (For each hour, tcs is the total time during which one or more of the units which exhaust through the common stack operate.).

HIu = Hourly average heat input rate for hour h for the unit, mmBtu/hr.

tu = Unit operating time for hour h, in hours or fraction of an hour (in equal increments that can range from one hundredth to one quarter of an hour, at the option of the owner or operator).

p = Number of units that exhaust through the common stack.

u = Designation of a particular unit.

Use the hourly heat input rate at the common stack level and the hourly average NOX emission rate at the common stack level and the procedures in section 8.1.1 of this appendix to determine the hourly NOX mass emissions at the common stack.

8.1.3If a unit has multiple ducts and NOX emission rate is only measured at one duct, use the NOX emission rate measured at the duct, the heat input measured for the unit, and the procedures in section 8.1.1 of this appendix to determine NOX mass emissions.

8.1.4If a unit has multiple ducts and NOX emission rate is measured in each duct, heat input shall also be measured in each duct and the procedures in section 8.1.1 of this appendix shall be used to determine NOX mass emissions.

8.2If a unit calculates NOX mass emissions using a NOX concentration monitoring system and a flow monitoring system, calculate hourly NOX mass rate during unit (or stack) operation, in lb/hr, using Equation F1 or F2 in this appendix (as applicable to the moisture basis of the monitors). When using Equation F1 or F2, replace SO2 with NOX and replace the value of K with 1.194107 (lb NOX /scf)/ppm. (Include bias-adjusted flow rate or NOX concentration values, where the bias-test procedures in appendix A to this part shows a bias-adjustment factor is necessary.) 8.3If a unit calculates NOX mass emissions using a NOX concentration monitoring system and a flow monitoring system, calculate NOX mass emissions for the hour (lb) by multiplying the hourly NOX mass emission rate during unit operation (lb/hr) by the unit operating time during the hour, as follows: (image) Where: M(NOx)h = NOX mass emissions in lbs for the hour.

Eh = Hourly NOX mass emission rate during unit (or stack) operation, lb/hr, from section 8.2 of this appendix.

th = Monitoring location operating time for hour h, in hours or fraction of an hour (in equal increments that can range from one hundredth to one quarter of an hour, at the option of the owner or operator). If the NOX mass emission rate is monitored for all of the units in a common stack, the monitoring location operating time is equal to the total time when any of those units was exhausting through the common stack.

8.4Use the following procedures to calculate quarterly, cumulative ozone season, and cumulative yearly NOX mass emissions, in tons: (image) Where: M(NOx) time period = NOX mass emissions in tons for the given time period (quarter, cumulative ozone season, cumulative year-to-date).

M(NOx)h = NOX mass emissions in lbs for the hour. p = The number of hours in the given time period (quarter, cumulative ozone season, cumulative year-to-date).

8.5Specific provisions for monitoring NOX mass emissions from common stacks. The owner or operator of a unit utilizing a common stack may account for NOX mass emissions using either of the following methodologies, if the provisions of subpart H are adopted as requirements of a State or federal NOX mass reduction program: 8.5.1The owner or operator may determine both NOX emission rate and heat input at the common stack and use the procedures in section 8.1.1 of this appendix to determine hourly NOX mass emissions at the common stack.

8.5.2The owner or operator may determine the NOX emission rate at the common stack and the heat input at each of the units and use the procedures in section 8.1.2 of this appendix to determine the hourly NOX mass emissions at each unit.

9. Procedures for Hg Mass Emissions.

9.1Use the procedures in this section to calculate the hourly Hg mass emissions (in ounces) at each monitored location, for the affected unit or group of units that discharge through a common stack.

9.1.1To determine the hourly Hg mass emissions when using a Hg concentration monitoring system that measures on a wet basis and a flow monitor, use the following equation: (image) Where: Mh = Hg mass emissions for the hour, rounded off to three decimal places, (ounces).

K = Units conversion constant, 9.978 x 1010 oz-scm/g-scf Ch = Hourly Hg concentration, wet basis, adjusted for bias if the bias-test procedures in appendix A to this part show that a bias-adjustment factor is necessary, (g/wscm).

Qh = Hourly stack gas volumetric flow rate, adjusted for bias, where the bias-test procedures in appendix A to this part shows a bias-adjustment factor is necessary, (scfh) th = Unit or stack operating time, as defined in 72.2, (hr) 9.1.2To determine the hourly Hg mass emissions when using a Hg concentration monitoring system that measures on a dry basis or a sorbent trap monitoring system and a flow monitor, use the following equation: (image) Where: Mh = Hg mass emissions for the hour, rounded off to three decimal places, (ounces).

K = Units conversion constant, 9.978 x 1010 oz-scm/g-scf Ch = Hourly Hg concentration, dry basis, adjusted for bias if the bias-test procedures in appendix A to this part show that a bias-adjustment factor is necessary, (g/dscm). For sorbent trap systems, a single value of Ch (i.e., a flow-proportional average concentration for the data collection period), is applied to each hour in the data collection period, for a particular pair of traps.

Qh = Hourly stack gas volumetric flow rate, adjusted for bias, where the bias-test procedures in appendix A to this part shows a bias-adjustment factor is necessary, (scfh) Bws = Moisture fraction of the stack gas, expressed as a decimal (equal to % H2O 100) th = Unit or stack operating time, as defined in 72.2, (hr) 9.1.3For units that are demonstrated under 75.81(d) to emit less than 464 ounces of Hg per year, and for which the owner or operator elects not to continuously monitor the Hg concentration, calculate the hourly Hg mass emissions using Equation F28 in section 9.1.1 of this appendix, except that Ch shall be the applicable default Hg concentration from 75.81(c), (d), or (e), expressed in g/scm. Correction for the stack gas moisture content is not required when this methodology is used.

9.2Use the following equation to calculate quarterly and year-to-date Hg mass emissions in ounces: (image) Where: Mtime period = Hg mass emissions for the given time period i.e., quarter or year-to-date, rounded to the nearest thousandth, (ounces).

Mh = Hg mass emissions for the hour, rounded to three decimal places, (ounces).

n = The number of hours in the given time period (quarter or year-to-date).

9.3If heat input rate monitoring is required, follow the applicable procedures for heat input apportionment and summation in sections 5.3, 5.6 and 5.7 of this appendix.

[58 FR 3701, Jan. 11, 1993; Redesignated and amended at 60 FR 26553-26556, 26571, May 17, 1995; 61 FR 25585, May 22, 1996; 61 FR 59166, Nov. 20, 1996; 63 FR 57513, Oct. 27, 1998; 64 FR 28666 28671, May 26, 1999; 64 FR 37582, July 12, 1999; 67 FR 40474, 40475, June 12, 2002; 67 FR 53505, Aug. 16, 2002; 70 FR 28695, May 18, 2005]

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