SCAQMD RULE 2012-3 LARGE SOURCES CONTINOUS PROCESSING MONITORING SYSTEM
LAST REVISED 07/12/96

(Amended July 12, 1996)

C H A P T E R 3



L A R G E S O U R C E S - C O N T I N U O U S
P R O C E S S M O N I T O R I N G S Y S T E M
( C P M S )

TABLE OF CONTENTS

CHAPTER 3 - LARGE SOURCES - CONTINUOUS PROCESS MONITORING SYSTEM (CPMS)

A. General Requirements .........................................................................A2012-3-1

B. Monitoring Systems ............................................................................A2012-3-3

C. Concentration Limit Calculations .........................................................A2012-3-4

D. Emission Calculations for Reported Data .............................................A2012-3-5

E. Total Monthly Mass Emissions Calculation ..........................................A2012-3-9

F. Flow Determination Test Methods ......................................................A2012-3-10

G. Reporting Procedures ........................................................................A2012-3-10

H. Alternative Procedures ......................................................................A2012-3-11

I. Missing and Invalid Data Procedures ..................................................A2012-3-12

J. Fuel Meter Sharing ............................................................................A2012-3-13

K. Missing Data Procedures for Large Sources Monitored by CEMS ....A2012-3-13

This chapter describes the methodologies for measuring and reporting emissions from large sources. For this category, the Facility Permit holder shall use Continuous Emissions Monitoring System (CEMS) or elect to use CPMS to measure NOx emissions. The focal point shall be the emission factor (during the interim period only, January 1, 1994 to December 31, 1994 for Cycle 1 facilities and July 1, 1994 to July 1, 1995 for Cycle 2 facilities), concentration limit, or equipment-specific emission rate. Mass emissions shall be estimated by using the emission factor (e.g. lb/mm Btu), or concentration limit (e.g. ppmv converted to lb/mm Btu) and a throughput rate (typically fuel consumption adjusted for heating value).

Measurement and reporting requirements apply to variables used to calculate the NOx emissions. These measured and process variables are found in Table 3-A. The reporting variables are found in Table 3-B.

In accordance with Rule 2012, the Facility Permit will specify either a concentration limit or an emission rate. One or more measured variables necessary to substantiate the equipment-specific emission rate shall be monitored and recorded. These measured variables are listed in Table 3-A. For sources subject to a concentration limit, only fuel usage or throughput is required to be measured by dedicated fuel meters or by any devices approved by the Executive Officer to be equivalent in accuracy, reliability, reproducibility, and timeliness.

Tables 3-C through 3-F list the rule-specific concentration limits, the emission fee billing factors, the unregulated default control efficiencies, and the standard oxygen concentrations.

The criteria for determining large source category is found in Table 1-B.

Starting January 1, 1994 (Cycle 1 facilities) and starting July 1, 1994 (Cycle 2 facilities), large-source NOx emissions shall be allowed to use an interim reporting procedure to calculate and record on a monthly basis according to the requirements specified in Chapter 3, Subdivision D, Paragraph 1, and Chapter 3, Subdivision G, Paragraph 2 "Large Sources - Continuous Process Monitoring System (CPMS)" . On and after January 1, 1995 (Cycle 1 facilities) and July 1, 1995 (Cycle 2 facilities), the Facility Permit holder of each large source shall report consistent with all other applicable requirements specified in this chapter.

A. - GENERAL REQUIREMENTS

  1. The Facility Permit holder of a large NOx source who has elected to use a concentration limit shall comply with any one of the following, in ppmv and over any continuous 60 minutes:
  2. a. The Facility Permit holder shall be allowed to use the emission factors and/or control efficiencies listed in Tables 3-D, and 3-E or Table 1 of Rule 2002 and apply methodology presented in Subdivision 3, Paragraph C to derive a corresponding concentration limit; or

    b. If there is no applicable concentration limit and/or control efficiency, then the Facility Permit holder shall be allowed to request a manufacturer's guaranteed emission factors and/or control efficiency or a manufacturer's guaranteed concentration limit as part of the Facility Permit application; or

    c. The Facility Permit holder shall be allowed to use applicable rule-specific concentration limit found in Table 3-C; or

    d. The Facility Permit holder shall be allowed to use any other concentration limit as approved by the Executive Officer according to guidelines set forth in this chapter.

  3. The Facility Permit holder of a large NOx source who has elected to use a concentration limit shall calculate the mass emissions according to the methodology specified in Chapter 3, Subdivision D, Paragraph 2, Subparagraph a.
  4. The Facility Permit holder of a large NOx source who has elected to use an emission rate shall apply the methodology specified in Chapter 5 to derive an acceptable emission rate.
  5. The Facility Permit holder of a large NOx source who has elected to use an emission rate shall calculate the emissions according to the methodology specified in Chapter 3, Subdivision D, Paragraph 2, Subparagraph b.
  6. The Facility Permit holder of each equipment shall measure and record fuel usage and one or more parametric variables in Table 3-A in order to substantiate the equipment-specific emission rate. As part of the Facility Permit application review, the Executive Officer shall modify the list of Facility Permit holder-selected variables.
  7. Fuel flow measuring devices used for obtaining stack flow in conjunction with F-factors shall be tested as installed for relative accuracy using reference methods to determine stack flow.
  8. If the flow device manufacturer has a method or device that permits the fuel flow measuring device to be tested as installed for relative accuracy, the Facility Permit holder shall request approval from the Executive Officer. Approval will be granted in cases where the Facility Permit holder can demonstrate to the satisfaction of the Executive Officer that no suitable testing location exists in the exhaust stacks or ducts and that it would be an inordinate cost burden to modify the exhaust stack configuration to provide a suitable testing location. The method or device used for relative accuracy testing shall be traceable to NIST standards. This method shall be used only if the Facility Permit holder can prove to the Executive Officer that the natural gas, fuel oil, or other fuels have stable F-factors and gross heating values, or if the Facility Permit holder measures the F-factor and gross heating value of the fuel. A stable F-factor is defined as not varying by more than + or - 2.5% from the constant value used for F-factor. For the fuels listed in 40 CFR 60, Appendix A, Method 19, Table 19-1, the F-factors are assumed to be stable at the value cited in Table 19-1. Any F-factor cited in Regulation XX shall supersede the F-factor in Table 19-1. For fuels not listed in the citations above, but which the Facility Permit holder can demonstrate that the source-specific F-factor meets the same stability criteria, periodic reporting of F-factor may be accepted and the adequacy of the frequency of analyses shall be demonstrated by the Facility Permit operator such that the probability that any given analysis will differ from the previous analysis by more than 5% (relative to the previous analysis) or less than 5%. Analysis records shall be maintained, including all charts and laboratory notes.

  9. Fuel meters or any devices approved by the Executive Officer to be equivalent in accuracy, reliability, reproducibility, and timeliness, shall be non-resettable and tamper proof. The seals installed by the manufacturer shall be intact to prove the integrity of the measuring device.
  10. Meters which are unsealed for maintenance or repairs shall be resealed by an authorized manufacturers representative.

  11. The Facility Permit holder of each large NOx source shall monitor, report, and maintain the records on a monthly basis the type and quantity of fuel burned, in units of millions of standard cubic feet per month (mmscf per month) for gaseous fuels or thousand gallons per month (mgal per month) for liquid fuels, expressed to at least three significant figures.
  12. Monthly NOx mass emissions shall be reported to the District's NOx Central Station Computer according to the requirements specified in Chapter 3, Subdivision G.

B. - MONITORING SYSTEMS

  1. Operational Requirements
  2. The CPMS shall be operated and data recorded during all periods of operation of the equipment including periods of start-up, shutdown, malfunction or emergency conditions, except for CPMS breakdowns and repairs.

  3. Performance Standard
  4. All CPMS at each equipment shall, at a minimum, be able to measure the fuel usage once every fifteen minutes. Such measured data shall be accumulated and recorded to represent the monthly fuel usage as specified in Paragraphs B.3.

  5. Information Required for Each Monthly Interval
  6. All CPMS at each equipment shall, at a minimum, measure and totalize the following data points for each successive monthly period, expressed to at least three significant figures, and at equally spaced intervals thereafter, except where noted:

    a. Fuel usage in units of million standard cubic feet per month (mmscf/mo) for gaseous fuels, or thousand gallons per month (mgal/mo) for liquid fuels. Alternatively, the fuel usage may be calculated from stack gas volumetric flow rates totalized over a month and oxygen concentration, in which case the Facility Permit holder shall measure:

    i. Oxygen concentration in the stack in units of percent if required for calculation of the stack gas flow rate.

    ii. Volumetric flow rate of stack gases in units of dry standard cubic feet per month. Standard gas conditions are defined as a temperature at 68°F and one atmosphere of pressure.

    b. One or more process variables specified in Table 3-A, if the Facility Permit holder elects for an equipment-specific emission rate.

C. - CONCENTRATION LIMIT CALCULATION

Pursuant to the election condition requirements in Rule 2012 (f), the Facility Permit holder shall use the equation provided in this section to calculate the concentration limit. Equation 15 applies to the Facility Permit holder requesting that the Emission Fee Billing factor in Table 3-D, the emission factor specified in Table 1, Rule 2002 - Baselines and Rates of Reduction for NOx/SOx and/or the control efficiency in Table 3-E be converted into a concentration limit.

                                      r
PPMVc = 0.8368x107 x (20.9-b/20.9) x  EFj(1-EFFj)/(Fdj x Vj)
                                     j=1
Note: unable to provide graphic, please contact the District for a copy.
                                                         (Eq.15)


where:

PPMVc = The equipment-specific concentration limit corrected at applicable standard oxygen concentration found in Table 3-F or rule-specific concentration limit found in Table 3-C.

EFj = The equipment-specific EFB emission factor (lb/mmscf or lb/mgal) found in Table 3-D or emission factor found in Table 1 of Rule 2002 or reported value of emission factor. The emission factor found in Table 1 of Rule 2002 may or may not include the appropriate control efficiency.

EFFj = The equipment-specific control efficiency (%), found in Table 3-E or proposed by the Facility Permit holder.

b = The standard oxygen concentration (%) found in Table 3-F.

Fdj = The fuel-specific dry F factor, the ratio of the dry gas volume of the products of combustion to the heat content of the fuel(dscf/mmBtu) specified in 40 CFR Part 60, Appendix A, Method 19.

V = The higher heating value for each type of fuel (mmBtu/mmscf or mmBtu/mgal) found in Table 3-D.

j = Each type of equipment in a large NOx source sharing a fuel meter and identical concentration limit at standard oxygen concentration.

r = The total number of equipment in a large NOx source sharing a fuel meter and identical concentration limit at standard oxygen concentration.

Example Calculation: Natural-Gas Fired Boiler with Lo-Nox Burner

EF = 130 lb/mmsf
V = 1,050 mmBtu/mmscf
EFF = 35%
b = 3%
Fd = 8,710 dscf/mmBtu
PPMVc = 130 (1 - 35/100) x [(20.9 - 3)/20.9] x 0.8368 x 107/(8,710 x 1,050)
= 70 ppmv

D. EMISSION CALCULATION FOR REPORTED DATA

  1. Monthly Mass Emissions for Interim Periods
  2. Pursuant to Rule 2012 (f) (1), between January 1, 1994 and December 31, 1994 for Cycle 1 facilities, and between July 1, 1994 and June 30, 1995 for Cycle 2 facilities, the monthly emission of each large source shall be calculated and recorded according to:

           r
    Eip  =    EFsj x dj  
          j=1
    Note: unable to provide graphic, please contact the District for a copy.
                                (Eq.16)
            
    
    

    where:

    Eip = The monthly mass emission of nitrogen oxides for interim period (lb/month).

    EFsj = The starting emission factor used to calculate source emissions in the initial allocation, as specified in Table 1 of Rule 2002 - Allocations for NOx/SOx (lb/mmscf, lb/mgal).

    dj = The monthly metered fuel usage for each type of fuel recorded as mmscf/ month or mgal/month.

    j = Each type of fuel used, or material processed or produced by a large NOx source

    r = The total number of fuel types used, or materials processed or produced by a large NOx source

    Example calculation: Boiler burning natural gas, rated 40 mmBtu/hr, in compliance with Rule 1146. Applicable starting year emission factor
    =49.18 lb/mmscf
    Monthly fuel usage = 20 mmscf per month

    Eip = (49.18) x (20)
    = 983.6 lb/month

  3. Monthly Mass Emissions for Normal Operating Hours
  4. a. When the Facility Permit holder elects to use the concentration limit, the monthly mass emission shall be calculated and recorded according to the following equation:

     
                                                     r
    Ek = PPMVc x [20.9/(20.9 - b)] x 1.195 x 10-7 x  (Fdj x dj x Vj)
                                                    j=1  
                                                             (Eq.17)
    Note: unable to provide graphic, please contact the District for a copy.

    where:

    Ek = The monthly mass emission of nitrogen oxides (lb/month).

    PPMVc = The equipment-specific compliance concentration limit measured over any continuous 60 minutes and requested by the Facility Permit holder, or calculated by Eq. 14 in Chapter 3, Subdivision C. (ppmv).

    b = The standard concentrations of oxygen as requested by the Facility Permit holder, or as found in Table 3-F. (%).

    r = The number of different types of fuel.

    j = Each type of fuel.

    Fdj = The dry F factor for each type of fuel, the ratio of the dry gas volume of the products of combustion to the heat content of the fuel (dscf/mmBtu) specified in 40 CFR Part 60, Appendix A, Method 19.

    dj = The monthly fuel usage for each type of fuel recorded by the fuel totalizer (mmscf per month or mgal per month).

    Vj = The higher heating value of the fuel for each type of fuel found in Table 3-D (mmBtu/mmscf or mmBtu/mgal)

    The product (dj x Vj) shall have units of mmBtu per month (mmBtu/month).

    Equation 16 shall not be used in cases where enriched oxygen is used, non-fuel sources of carbon dioxide are present (e.g., lime kilns and calciners), and the oxygen content of the stack gas is 19 percent or greater.

    b. When the Facility Permit holder elects to use the emission rate, the monthly emission shall be calculated and recorded according to:

           r
    Ek =   dj   x   Vj   x ERj     
          j=1                                   (Eq.18)
     Note: unable to provide graphic, please contact the District for a copy.                     
    

    where:

    Ek = The monthly mass emission of nitrogen oxides (lb/month).

    dj = The monthly fuel usage for each type of fuel recorded by the fuel totalizer (mmscf/month or mgal/month) or the monthly amount of materials produced or processed, depending to the units of the equipment specific emission rate.

    ERj = The equipment-specific emission rate proposed by the Facility Permit holder and determined according to Chapter 5, Subdivision E (lb/mmBtu).

    Vj = The higher heating value of each type of fuel (mmBtu/mmscf or mmBtu/mgal). This equals 1 if ERj is not dependent on fuel combustion.

    Example Calculation:
    y = Each type of fuel.
    r = The number of type of fuel consumed per month

    Boiler
    ERc = 200 lb/mmscf requested for uncontrolled, natural gas fired boiler
    d = 1 mmscf per month
    Ek = ERc x d = 200 x 1
    Ek = 200 lb/month
    ICE
    ERc = 500 lb/1000 gal requested for uncontrolled, natural gas fired ICE
    d = 600 gal/month
    Ek = ERc x d
    = 500 lb/1000 x 600 gal/month
    = 300 lb/month
    Total Ek = 200 + 300 lb/month
    = 500 lb/month

  5. Monthly Mass Emissions during Startup or Shutdown Periods
  6. The Facility Permit holder of a large source with startup or shutdown periods at least 6 hours in duration shall apply the following methodology to determine the emissions during startup and shutdown periods:

    a. During equipment startup or shutdown the Facility Permit holder shall apply the EFB emission factor specified in Table 3-D; or

    b. If the emission factors in Table 3-D do not reflect the emission factors during startup and shutdown periods, the Facility Permit holder shall propose emission factors for the approval of the Executive Officer and shall submit source test data to substantiate the proposed emission factors. The monthly emissions during startup and shutdown periods shall be calculated and reported according to:

          r
    Est =  Dstj   x   EFstj 
         j=1
                                         (Eq.19)
    Note: unable to provide equation graphics, please contact the District for a copy.
           r  
    Esh =   Dsh   x   EFsh
          j=1
                                          (Eq.20)
    

    where:

    Est = The monthly mass emission of nitrogen oxides during startup period (lb/month).

    Dstj = The monthly fuel usage for each type of fuel during startup period (mmscf/month or mgal/month) ), or the amount of materials produced or processed per month depending on the units or proposed emission factors or emission rates..

    EFstj = The EFB or Facility Permit holder-specified emission factor or emission rate during startup period (lb/mmscf or lb/mgal

    where:

    Esh = The monthly mass emission of nitrogen oxides during shutdown period (lb/month).

    Dshj = The monthly fuel usage for each type of fuel during shutdown period (mmscf/month or mgal/month) or the amount of materials produced or processed per month, depending on the units of proposed emission factors or emission rates.

    EFshj = The EFB or Facility Permit holder-specified emission factor or emission rate during shutdown period (lb/mmscf or lb/mgal).

    j = Each type of fuel or material processed or produced

    r = The number of each type of fuel consumed per month or the number of material processed or produced per month.

E. TOTAL MONTHLY MASS EMISSION CALCULATION

The total monthly mass emission shall be calculated and recorded for each equipment according to:

          E = Ek + Em + Est + Esh          (Eq. 21)

Where:

E = The monthly mass emission of nitrogen oxides (lb/month).

Ek = The monthly mass emission calculated using measured data during normal operation (lb/month).

Em = The monthly mass emission calculated using substitute data during normal operation (lb/month).

Est = The monthly mass emission calculated during startup period (lb/month).

Esh = The monthly mass emission calculated during shutdown period (lb/month).

Example Calculation:


Ek = 130 lb/106 scf x 420 scf/hr x 480 hr/mo = 26.2 lb/month
Em = 161 lb/106 scf x 300 scf/hr x 3hr/day = .1449 lb/month
Est = 130 lb/106 scf x 100 scf/hr x 3hr/day = .0390 lb/month
Esh = 130 lb/106 scf x 50 scf/hr x 2 hr/day = .0130 lb/month
E = Ek + Em + Est + Esh = 26.2 + .1449 + .0390 +.0130
= 26.4 lb/month

F. FLOW DETERMINATION TEST METHODS

  1. District Methods 2.1 and 2.3 shall be used to determine the stack gas volumetric flow rate.
  2. For District Method 2.1, District Method 1.1 shall be used to select the sampling site and the number of traverse points.
  3. District Method 3.1 shall be used for diluent gas (O2 or CO2) concentration and stack gas density determination.
  4. District Method 4.1 shall be used for moisture determination of stack gas.

G. REPORTING PROCEDURES

  1. The total fuel usage data for all large sources in any facility without a RTU or modem shall be reported in a format approved by the Executive Officer.
  2. For each equipment the following information shall be stored on-site in a format approved by the Executive Officer:
  3. a. Calendar dates covered in the reporting period;

    b. Monthly mass emissions for each equipment ;

    c. Identification of the equipment operating days for which a sufficient number of valid data points has not been taken; reasons for not taking sufficient data; and a description of corrective action taken;

    d. Identification of Fd or Fw factor for each type of fuel used for calculation and the type of fuel burned;

    e. Any changes made in type of fuel used and Fd factor, if applicable.

H. ALTERNATIVE PROCEDURES

The following requirements are applicable when the Facility Permit holder chooses to make alternative measurements other than fuel flow meter, such as exhaust flow rates and oxygen sensor:

  1. Emission Stack Flow Rate Determination
  2. In the event that more than one source vents to a common stack, the alternative reference method for determining individual source flow rates shall be EPA Method 19. The orifice plates used in every unit vented to a common stack shall meet the requirements in Chapter 3, Subdivision H, Paragraph 3.

  3. Quality Assurance Procedures for Volumetric Flow Measurement System
  4. a. Each volumetric flow measurement system shall be audited at least once each calendar year. Successive audits shall occur no closer than six months or after any modification to the process which would significantly alter the flow.

    b. If the volumetric flow measurement system is found to be out of calibration by 10 percent or greater, then recalculation of the flow measurement must be performed from the last audit date to the current audit date.

  5. Quality Assurance for Orifice Plate Measurements
  6. Each orifice plate used to measure the fuel gas flow rate shall be removed from the gas supply line for an inspection once every 12 months, if the orifice cannot be checked using Reference Methods or other methods that can show traceability to NIST standards. However, with the prior approval of the Executive Officer, orifice plates may be inspected not less than once every 36 months provided the Facility Permit holder demonstrates to the Executive Officer that orifice plates used for 36 months or longer meet the specifications set forth in this paragraph. This demonstration shall be completed by July 1, 1995 or within one year for facilities that enter RECLAIM on and after July 1, 1994. The following items shall be subject to inspection:

    a. Each orifice plate shall be visually inspected for any nicks, dents, corrosion, erosion, or any other signs of damage according to the orifice plate manufacturer's specifications.

    b. The diameter of each orifice shall be measured using the method recommended by the orifice plate manufacture.

    c. The flatness of the orifice plate shall be checked according to the orifice plate manufacturer's instructions. The departure from flatness of an orifice plate shall not exceed 0.010 inches per inch of dam height (D-d/2) along any diameter. Here D is the inside pipe diameter and d is the orifice diameter at its narrowest constriction.

    d. The pressure gauge or other device measuring pressure drop across the orifice shall be calibrated against a manometer, and shall be replaced if it deviates more than ±2 percent across the range.

    e. The surface roughness shall be measured using the method recommended by the orifice plate manufacturer. The surface roughness of an orifice plate shall not exceed 50 micro inches.

    f. The upstream edge of the measuring orifice shall be square and sharp so that it shall not show a beam of light when checked with an orifice gauge.

    g. In centering orifice plates, the orifice shall be concentric with the inside of the meter tube or fitting. The concentricity shall be maintained within 3 percent of the inside diameter of the tube or fitting along all diameters.

    h. Any other calibration tests specified by the orifice plate manufacturer shall be conducted at this time. If an orifice fails to meet any of the manufacturer's specifications, it shall be replaced within two weeks.

I. MISSING AND INVALID DATA PROCEDURES

  1. For each large source or large sources using a common fuel meter or equivalent monitoring device, the Facility Permit holder shall provide substitute data as described below whenever a valid month of fuel usage data or the amount of production or process feed has not been obtained and recorded. Alternative data is acceptable for substitution if the Facility Permit holder can demonstrate to the Executive Officer that the alternative system is fully operational during meter down time and within +or- 2% accuracy.
  2. Whenever data from the process monitor is not available or not recorded for the affected equipment or when the equipment is not operated within the parameter range specified in the Facility Permit, the Facility Permit holder shall calculate substitute data for each month according to the following procedures.
  3. a. For a missing data period less than or equal to one month, substitute data shall be calculated using the large source(s) average monthly fuel usage for the previous 12 months.

    b. For a missing data period greater than one month, substitute data shall be calculated using the large source(s) highest monthly fuel usage data for the previous 12 months.

    c. For a missing data period greater than two months, or if the facility has no records, substitute data shall be calculated using 100 percent uptime during the substitution period and the large source(s) maximum rated capacity and uncontrolled emission factor for each month of missing data.

J. FUEL METER SHARING

  1. A single totalizing fuel meter shall be allowed to measure the cumulative fuel usage for more than one equipment in a large NOx source provided that each equipment has the same concentration limit, emission rate, or emission factor as specified in the Facility Permit and that any equipment in a large NOx source does not use the annual heat input in order to be classified from a major source to a large source.
  2. One or more pieces of equipment in a large NOx source shall be allowed to share the fuel totalizing meter provided that each equipment elects for the same concentration limit, emission rate, or emission factor as specified in the Facility Permit.
  3. Fuel meter sharing for the interim period shall be allowed for those equipment in a large NOx source with the same emission factor, emission rate, or concentration limit.

K. PROCEDURES FOR LARGE SOURCES MONITORED BY CEMS

The following requirements are applicable when the Facility Permit holder chooses CEMS as a monitoring alternative for large sources.

  1. Calculate monthly mass emissions by summing daily mass emissions which are obtained using procedures set forth in Appendix A, Chapter 2, except that the missing data procedures set forth below shall be used whenever valid data is not obtained:
  2. Missing Data Procedures for Large Sources Monitored by CEMS
  3. a. Percentage of data availability shall be calculated according to procedures set forth in Appendix A, Chapter 2, Subdivision E, subparagraph 1a.

    b. Whenever concentration or flow data from the CEMS have been available and recorded for 95 percent or more of the total operating hours of the affected piece of equipment during the previous 365 days, the Facility Permit holder shall calculate substitute data for each hour, when valid data has not been obtained, according to the following procedures.

    i. For a cumulative missing data period less than or equal to 24 hours in a month, substitute data shall be calculated using the average hourly-recorded CEMS value from the previous month.

    ii. For a cumulative missing data period greater than 24 hours in a month, substitute data shall be calculated using the maximum hourly-recorded CEMS value from the previous month.

    c. Whenever concentration or flow data from the CEMS have been available for 90-percent or more but less than 95-percent of the total operating hours of the affected piece of equipment during the previous 365 days, the Facility Permit holder shall calculate substitute data for each hour, when valid data has not been obtained, according to the following procedures.

    i. For a cumulative missing data period less than or equal to 24 hours in a month, substitute data shall be calculated using the average hourly-recorded CEMS value from the previous month.

    ii. For a cumulative missing data period greater than 24 hours but less than or equal to 168 hours in a month, substitute data shall be calculated using the maximum hourly-recorded CEMS value from the previous month.

    iii. For a cumulative missing data period greater than 168 hours in a month, substitute data shall be calculated using the maximum hourly-recorded CEMS value from the previous 12 months or during the service of the monitoring system, whichever is shorter.

    d. Whenever concentration or flow data from the CEMS have been available for less than 90% of the total operating hours of the affected piece of equipment during the previous 365 days, the Facility Permit holder shall calculate substitute data for each hour using the maximum hourly-recorded CEMS value during the service of the monitoring system.

    e. Whenever prior CEMS data have not been available (0% availability), monthly mass emissions shall be calculated using Appendix A, Chapter 3, Subdivision D. For those sources operating without a fuel meter, process rate meter, or production rate meter, monthly mass emissions shall be calculated pursuant to Appendix A, Chapter 3, Subdivision I, Subparagraph 2c.

Table 3-A

MEASURED AND PROCESS VARIABLES FOR LARGE NOxSOURCES

EQUIPMENT TYPE : BOILERS

Equipment
Measured Variables
Boilers 1. Fuel flow rate;
2. Steam production rate;
Boilers with low NOx burners All variables identified for boilers.
Boilers with staged combustion All variables identified for boilers.
Boilers with FGR All variables identified for boilers; AND
3. Flue gas recirculation rate.
Boilers with SCR All variables identified for boilers; AND
3. Ammonia injection rate;
4. Temperature of the inlet gas stream to SCR;
Boilers with SNCR All variables identified for boilers; AND
3. Ammonia (or urea) injection rate;
4. Temperature of the inlet gas stream to SNCR;
Boilers with NSCR All variables identified for boilers; AND
3. Natural gas (or other HC) injection rate.

Table 3-A (CONTINUED)

MEASURED AND PROCESS VARIABLES FOR LARGE NOx SOURCES
EQUIPMENT TYPE : FURNACES

EQUIPMENT MEASURED VARIABLES
Furnaces 1. Fuel flow rate;
2. Production rate;
Furnaces with low NOx burners All variables identified for furnaces.
Furnaces with combustion modification All variables identified for furnaces.
Furnaces with SCR All variables identified for furnaces; AND
3. Ammonia injection rate;
4. Temperature of the inlet gas stream to SCR;
Furnaces with SNCR All variables identified for furnaces; AND
3. Ammonia (or urea) injection rate;
4. Temperature of the inlet gas stream to SNCR;

Table 3-A (CONTINUED)

MEASURED AND PROCESS VARIABLES FOR LARGE NOxSOURCES
EQUIPMENT TYPE : OVENS

EQUIPMENT MEASURED VARIABLES
Ovens 1. Fuel flow rate;
2. Production rate;
Ovens with low NOx burners All variables identified for ovens.
Ovens with combustion modification All variables identified for ovens.
Ovens with SCR All variables identified for ovens; AND
3. Ammonia injection rate;
4. Temperature of the inlet gas stream to SCR;
Ovens with SNCR All variables identified for ovens; AND
3.Ammonia (or urea) injection rate;
4.Temperature of the inlet gas stream to SNCR;

Table 3-A (CONTINUED)

MEASURED AND PROCESS VARIABLES FOR LARGE NOxSOURCES
EQUIPMENT TYPE : DRYERS

EQUIPMENT MEASURED VARIABLES
Dryers 1. Fuel flow rate;
2. Production rate;
Dryers with low NOx burners All variables identified for dryers.
Dryers with combustion modification All variables identified for dryers.
Dryers with FGR All variables identified for dryers; AND
3. Flue gas recirculation rate.
Dryers with SCR All variables identified for dryers; AND
3. Ammonia injection rate;
4. Temperature of the inlet gas stream to SCR;
Dryers with SNCR All variables identified for dryers; AND
3. Ammonia (or urea) injection rate;
4. Temperature of the inlet gas stream to SNCR;
Dryers with NSCR All variables identified for dryers; AND
3. Natural gas (or other HC) injection rate.

Table 3-A (CONTINUED)

MEASURED AND PROCESS VARIABLES FOR LARGE NOx SOURCES
EQUIPMENT TYPE : PROCESS HEATERS

EQUIPMENT MEASURED VARIABLES
Process heaters 1. Fuel flow rate;
2. Process rate;
Process heaters
with low NOx burners
All variables identified for process heaters.
Process heaters with combustion
modification
All variables identified for process heaters.
Process heaters with FGR All variables identified for process heaters; AND
3. Flue gas recirculation rate.
Process heaters with SCR All variables identified for process heaters; AND
3. Ammonia injection rate;
4. Temperature of the inlet gas stream to SCR;
Process heaters with SNCR All variables identified for process heaters; AND
3. Ammonia (or urea) injection rate;
4. Temperature of the inlet gas stream to SNCR;
Process heaters with NSCR All variables identified for process heaters; AND
3. Natural gas (or other HC) injection rate.
Process heaters
with water (or steam) injection
All variables identified for process heaters; AND 3. Water (or steam) injection rate.

Table 3-A (CONTINUED)

MEASURED AND PROCESS VARIABLES FOR LARGE NOx SOURCES
EQUIPMENT TYPE : INCINERATORS

EQUIPMENT MEASURED VARIABLES
Incinerators 1. Fuel flow rate;
2. Process rate;
Incinerators with SCR All variables identified for incinerators; AND
3. Ammonia injection rate;
4. Temperature of the inlet gas stream to SCR;
Incinerators with SNCR All variables identified for incinerators; AND
3 Ammonia (or urea) injection rate;
4. Temperature of the inlet gas stream to SNCR;

Table 3-A (CONTINUED)

MEASURED AND PROCESS VARIABLES FOR LARGE NOx SOURCES
EQUIPMENT TYPE : TEST CELLS

EQUIPMENT MEASURED VARIABLES
Test cells 1. Fuel flow rate;
2. Shaft horsepower output;
Test cells with SCR All variables identified for test cells; AND
3. Ammonia injection rate;
4. Ammonia slip.
Test cells with Packed Chemical
Scrubber
All variables identified for test cells; AND
3. Chemical injection rate.

Table 3-A (CONTINUED)

MEASURED AND PROCESS VARIABLES FOR LARGE NOx SOURCES
EQUIPMENT TYPE : INTERNAL COMBUSTION ENGINES

EQUIPMENT MEASURED VARIABLES
Internal combustion engines 1. Fuel flow rate;
2. Throttle setting
Internal combustion engines with combustion modification All variables identified for internal combustion engines.
Internal combustion engines with Injection Timing Retard 4 degree All variables identified for internal combustion engines.
Internal combustion engines with turbocharger, aftercooler, intercooler. All variables identified for internal combustion engines.
Internal combustion engines with SCR All variables identified for internal combustion engines;AND
3. Ammonia injection rate;
4. Temperature of the inlet gas stream to SCR;
Internal combustion engines NSCR All variables identified for internal combustion engines; with AND 3. Natural gas (or other HC) injection rate.

Table 3-A (CONTINUED)

MEASURED AND PROCESS VARIABLES FOR LARGE NOxSOURCES
EQUIPMENT TYPE : GAS TURBINES

EQUIPMENT MEASURED VARIABLES
Gas turbines 1. Fuel flow rate;
2. Shaft horsepower output;
Gas turbines with Water
or Steam Injection
All variables identified for gas turbines; AND
3. Water or steam injection rate;
Gas turbines with SCR
and Steam Injection
All variables identified for gas turbines; AND
3. Ammonia injection rate;
4. Steam injection rate
Gas turbines with SCR
and Water Injection
All variables identified for gas turbines; AND
3. Ammonia injection rate;
4. Water injection rate

Table 3-A (CONTINUED)

MEASURED AND PROCESS VARIABLES FOR LARGE NOx SOURCES
EQUIPMENT TYPE: KILNS AND CALCINERS

EQUIPMENT MEASURED VARIABLES
Kilns and calciners 1. Fuel flow rate;
2. Production rate;
Kilns and calciners
with low NOx burners
All variables identified for kilns and calciners.
Kilns and calciners
with combustion modifications
All variables identified for kilns and calciners.
Kilns and calciners with FGR All variables identified for kilns and calciners; AND
3. Flue gas recirculation rate.
Kilns and calciners with SCR All variables identified for kilns and calciners; AND
3. Ammonia injection rate;
Kilns and calciners with SNCR All variables identified for kilns and calciners; AND
3. Ammonia (or urea) injection rate;
Kilns and calciners with NSCR All variables identified for kilns and calciners; AND
3. Natural gas (or other HC) injection rate.

Table 3-A (CONTINUED)

MEASURED AND PROCESS VARIABLES FOR LARGE NOx SOURCES
EQUIPMENT TYPE : SULFURIC ACID PRODUCTION PLANTS

EQUIPMENT MEASURED VARIABLES
Sulfuric acid plants 1. Fuel flow rate;
2. Production rate;

Table 3-B

REPORTED VARIABLES FOR ALL LARGE NOx SOURCES

EQUIPMENT REPORTED VARIABLES
All large
NOx sources
1. Total Monthly mass emissions from each source;

TABLE 3-C

RULE-SPECIFIC CONCENTRATION LIMITS FOR LARGE NOx SOURCES
AND EMISSION FACTORS FOR NOx PROCESS UNITS

BASIC
EQUIPMENT
RULE CONCENTRATION
CATEGORY
LIMIT
Heaters,

Boilers,

Steam Generators

1109

1146

1146.1

> 40 mmBtu/hr in petroleum refineries


> 5 mmBtu/hr and < 40 mmBtu/hr

> 40 mmBtu/hr


> 2 mmBtu/hr
and < 5 mmBtu/hr

24 ppmv @3 % O2, dry*

40 ppmv @3 % O2, dry

30 ppmv @3 % O2, dry

30 ppmv @3 % O2, dry

Internal 1110.1
Combustion
Engines
1110.2 Rich Burn

Lean Burn

> 50 bhp
subject to Rule 1110.2(c)(2)(A)
> 100 bhp portable
subject to Rule 1110.2(c)(2)(A)
> 500 bhp
subject to Rule 1110.2(c)(2)(B)
50-500 bhp
subject to Rule 1110.2(c)(2)(B)

90 ppmv @15% O2, dry

150 ppmv @15% O2, dry

36 ppm @ 15% O2, dry
36 ppm @ 15% O2, dry
36 ppm @ 15% O2, dry
Reference limit
45 ppm @ 15% O2, dry
Reference limit

Nitric Acid
Production
1159 All Sizes 450 ppmv
Turbines 1134 > 0.3 MW and < 2.9 MW

Peaking Units and
Emergency Standby
Equipment

Emission factor or
concentration limit determined
as described in R. 1134(c)(1)

* Converted from Rule limit, which is 0.03 lb/mmBtu.

Table 3-D

EMISSION FEE BILLING FACTORS FOR LARGE NOx SOURCES AND NOx PROCESS UNITS

BASIC
EQUIPMENT
TYPE OF FUEL EMISSION FACTOR HIGHER HEATING
VALUE OF FUEL
Boilers,
Ovens,
Heaters,
Furnaces,
Kilns,
Calciners,
Dryers
Natural Gas
Refinery Gas
LPG, Propane, Butane
Diesel Light Dist. (0.05% S)
Fuel Oil (0.1% S)
Fuel Oil (0.25% S)
Fuel Oil (0.5% S)
130 lb/mmscf
161 lb/mmscf
12.8 lb/mgal
19 lb/mgal
20 lb/mgal
60 lb/mgal
55 lb/mgal
1050 mmBtu/mmscf
1150 mmBtu/mmscf
94 mmBtu/mgal
137 mmBtu/mgal
150 mmBtu/mgal
150 mmBtu/mgal
150 mmBtu/mgal
Internal
Combustion
Engines

Gas Turbines

Natural Gas
LPG, Propane, Butane
Gasoline
Diesel Oil
Natural Gas
Diesel Oil
3400 lb/mmscf
139 lb/mgal
102 lb/mgal
469 lb/mgal
413 lb/mmscf
67.8 lb/mgal
1050 mmBtu/mmscf
94 mmBtu/mgal
130 mmBtu/mgal
137 mmBtu/mgal
1050 mmBtu/mmscf
137 mmBtu/mgal

Table 3-E

UNREGULATED DEFAULT CONTROL EFFICIENCIES

BASIC EQUIPMENT FUEL CONTROL EQUIPMENT EFFICIENCY
Boilers,
Ovens,
Heaters,
Furnaces
Gas Fired


Oil Fired


(Distillate)
(Residual)

Selective Catalytic Reduction (SCR)
Thermal DeNOx (SNCR)
Low NOx Burner
Flue Gas Recirculation (FGR)


Wet Scrubber
Selective Catalytic Reduction (SCR)
Thermal DeNOx (SNCR)
Low NOx Burner
Flue Gas Recirculation (FGR)
Flue Gas Recirculation (FGR)
None

90
40
35
38


70
80
40
25
58
15
0

Internal
Combustion
Engines
Gas Fired
(Lean Burn)
(Rich Burn)


Oil Fired
(Diesel)
(Diesel)
(Diesel)

Combustion Modification
Selective Catalytic Reduction (SCR)
Non Select. Catalytic Reduction (NSCR)
Injection Timing Retard 4 Degree


Injection Timing Retard 4 Degree Selective Catalytic Reduction (SCR)
Injection Timing Retard 2 Degree
Injection Timing Retard 4 Degree
& Turbocharger & Aftercooler
None


55
68
86
15
20
80
18

40
0
Turbines Gas Fired


Oil Fired
(Diesel)
(Distillate)


Water or Steam Injection
SCR and Steam Injection
SCR and Water Injection


Water or Steam Injection
Water or Steam Injection
None


37
70
60


40
30
None 0

Table 3-F

STANDARD OXYGEN CONCENTRATIONS FOR LARGE NOx SOURCES
AND NOx PROCESS UNITS

BASIC EQUIPMENT FUEL CONTROL EQUIPMENT % O2, DRY

Boilers,
Ovens,
Heaters,
Furnaces
Gas Fired Oil Fired (Distillate) (Residual) Selective Catalytic Reduction (SCR) Thermal DeNOx (SNCR) Low NOx Burner Flue Gas Recirculation (FGR)
Wet Scrubber Selective Catalytic Reduction (SCR)
Thermal DeNOx (SNCR)
Low NOx Burner Flue Gas Recirculation (FGR) Flue Gas Recirculation (FGR)
3

3

3

3

3

3

3

3

3

3

Internal
Combustion Engines

Turbines

Gas Fired

(Lean Burn)

(Rich Burn)



Oil Fired
(Diesel)
(Diesel)
(Diesel)
Gas Fired


Oil Fired
(Diesel)
(Distillate)

Combustion Modification
Selective Catalytic Reduction (SCR)
Non Select. Catalytic Reduction (NSCR)
Injection Timing Retard 4 Degree

Injection Timing Retard 4 Degree
Selective Catalytic Reduction (SCR) Injection Timing Retard 2 Degree Injection Timing Retard 4 Degree
& Turbocharger & Aftercooler

Water or Steam Injection
SCR and Steam Injection
SCR and Water Injection


SCR and Water Injection
Water or Steam Injection
Water or Steam Injection

15

in every
category

15
15
15
15
15


SCAQMD RULE 2012-3 LG. SOURCES - CONT. PROC. MON. SYSTEM
LAST REVISED 11/11/11


             C H A P T E R   3



             L A R G E   S O U R C E S   -   C O N T I N U O U S

             P R O C E S S   M O N I T O R I N G   S Y S T E M

             ( C P M S )





                                  TABLE OF CONTENTS

          CHAPTER 3 - LARGE SOURCES - CONTINUOUS PROCESS MONITORING SYSTEM
          (CPMS)
          A. General Requirements...................................... 45
          B. Monitoring Systems........................................ 47
          C. Concentration Limit Calculations.......................... 48
          D. Emission Calculations for Reported Data................... 49
          E. Total Monthly Mass Emissions Calculation.................. 53
          F. Flow Determination Test Methods........................... 54
          G. Reporting Procedures...................................... 54
          H. Alternative Procedures.................................... 55
          I. Missing and Invalid Data Procedures....................... 56
          J. Fuel Meter Sharing........................................ 57



             PROTOCOL FOR RULE 2012


          This chapter describes the methodologies for measuring and
          reporting emissions from large sources.  For this category, the
          Facility Permit holder shall use Continuous Emissions Monitoring
          System (CEMS) or elect to use CPMS to measure NOx emissions.  The
          focal point shall be the emission factor (during the interim
          period only, January 1, 1994 to December 31, 1994 for Cycle 1
          facilities and July 1, 1994 to July 1, 1995 for Cycle 2
          facilities), concentration limit, or equipment-specific emission
          rate.  Mass emissions shall be estimated by using the emission
          factor (e.g. lb/mm Btu), or concentration limit (e.g. ppmv
          converted to lb/mm Btu) and a throughput rate (typically fuel
          consumption adjusted for heating value).

          Measurement and reporting requirements apply to variables used to
          calculate the NOx emissions.  These measured and process
          variables are found in Table 3-A.  The reporting variables are
          found in Table 3-B.
          In accordance with Rule 2012, the Facility Permit will specify
          either a concentration limit or an emission rate.  One or more
          measured variables necessary to substantiate the equipment-
          specific emission rate shall be monitored and recorded.  These
          measured variables are listed in Table 3-A.  For sources subject
          to a concentration limit, only fuel usage or throughput is
          required to be measured by dedicated fuel meters.

          Tables 3-C through 3-F list the rule-specific concentration
          limits, the emission fee billing factors, the unregulated default
          control efficiencies, and the standard oxygen concentrations.
          The criteria for determining large source category is found in
          Table 1-B.

          Starting  January  1, 1994 (Cycle 1 facilities) and starting July
          1, 1994 (Cycle 2 facilities), large-source NOx emissions shall be
          allowed to use an interim  reporting  procedure  to calculate and
          record on a monthly basis according to the requirements specified
          in  Chapter  3,  Subdivision  D,  Paragraph  1,  and  Chapter  3,
          Subdivision  G,  Paragraph 2 "Large Sources - Continuous  Process
          Monitoring System  (CPMS)" .  On and after January 1, 1995 (Cycle
          1 facilities) and July 1, 1995 (Cycle 2 facilities), the Facility
          Permit holder of each  large source shall  report consistent with
          all other applicable requirements specified in this chapter.
          A. GENERAL REQUIREMENTS
             1.   The Facility Permit holder of a large NOx source who has
                  elected to use a concentration limit shall comply with any 
                  one of the following, in ppmv and over any continuous 60 
                  minutes:
                  a.  The Facility Permit holder shall be allowed to use
                      the emission factors and/or control efficiencies listed 
                      in Tables 3-D, and 3-E or Table 1 of Rule 2002 and 
                      apply methodology presented in Subdivision 3, Paragraph 
                      C to derive a corresponding concentration limit; or
                   b. If there is no applicable concentration limit and/or 
                      control efficiency, thenthe Facility Permit holder 
                      shall be allowed to request a manufacturer's guaranteed 
                      emission factors and/or control efficiency or a 
                      manufacturer's guaranteed concentration limit as part 
                      of the Facility Permit application; or 
                   c. The Facility Permit holder shall be allowed to use 
                      applicable rule-specific concentration limit found in 
                      Table 3-C; or 
                   d. The Facility Permit holder shall be allowed to use any 
                      other concentration limit as approved by the Executive 
                      Officer according to guidelines set forth in this 
                      chapter.
          2.      The Facility Permit holder of a large NOx source who has
                  elected to use a concentration limit shall calculate the 
                  mass emissions according to the methodology specified in  
                  Chapter 3, Subdivision D, Paragraph 2, Subparagraph a.
          3.      The Facility Permit holder of a large NOx source who has
                  elected to use an emission rate shall apply the methodology
                  specified in Chapter 5 to derive an acceptable emission 
                  rate.
          4.      The Facility Permit holder of a large NOx source who has
                  elected to use an emission rate shall calculate the 
                  emissions according to the methodology specified in Chapter 
                  3, Subdivision D, Paragraph 2, Subparagraph b.
          5.      The Facility Permit holder of each equipment shall measure 
                  and record fuel usage and one or more parametric variables 
                  in Table 3-A in order to substantiate the equipment-
                  specific emission rate.  As part of the Facility Permit 
                  application review, the Executive Officer shall modify the 
                  list of Facility Permit holder-selected variables.
          6.      Fuel flow measuring devices used for obtaining stack flow 
                  in conjunction with F-factors shall be tested as installed  
                  for relative  accuracy using reference methods to determine 
                  stack flow.  If  the  flow  device  manufacturer has a 
                  method or  device  that permits the fuel flow measuring  
                  device to be tested as installed for relative accuracy, the 
                  Facility  Permit  holder shall request approval from the 
                  Executive Officer.  Approval will be granted in
                  cases  where  the Facility Permit holder can demonstrate
                  to  the satisfaction of  the  Executive  Officer that no
                  suitable testing location exists in the exhaust stacks  or
                  ducts and that it would be  an  inordinate  cost  burden
                  to  modify  the  exhaust  stack configuration to provide a
                  suitable testing location.  The method or device used for
                  relative accuracy testing shall  be  traceable to  NIST
                  standards.   This  method  shall  be  used  only if the
                  Facility  Permit  holder can prove to the Executive Officer
                  that the natural gas, fuel  oil,  or other fuels have stable
                  F-factors and  gross  heating  values, or if  the  Facility
                  Permit  holder measures the F-factor and gross heating value
                  of the fuel.
          7.      Fuel meters shall be  non-resettable  and  tamper  proof.
                  The seals  installed  by  the  meter  manufacturer shall be
                  intact to prove the integrity of the fuel flow measuring
                  device.
                  Meters which are unsealed for maintenance  or repairs shall
                  be resealed by an authorized manufacturers representative.
          8.      The  Facility Permit holder of each large NOx  source  shall
                  monitor, report,  and maintain the records on a monthly basis
                  the type  and quantity of  fuel  burned,  in  units  of
                  millions of standard cubic feet per month (mmscf per month)
                  for gaseous fuels or thousand  gallons per month (mgal per
                  month) for liquid fuels, expressed to at least three
                  significant figures.
          9.      Monthly  NOx   mass  emissions  shall  be  reported  to  the
                  District's  NOx  Central   Station   Computer  according  to  the
                  requirements specified in Chapter 3, Subdivision G.

      B. MONITORING SYSTEMS
          1.   Operational Requirements
              The CPMS shall be operated and data recorded  during  all periods
              of  operation  of  the  equipment  including periods of start-up,
              shutdown, malfunction or emergency conditions,  except  for  CPMS
              breakdowns and repairs.
          2.  Performance Standard
              All  CPMS  at  each  equipment  shall,  at  a minimum, be able to
              measure the fuel usage once every fifteen minutes.  Such measured
              data shall be accumulated and recorded to represent  the  monthly
              fuel usage as specified in Paragraphs B.3.
          3.   Information Required for Each Monthly Interval
              All  CPMS  at  each  equipment  shall,  at a minimum, measure and
              totalize  the following data points for each  successive  monthly
              period, expressed  to  at least three significant figures, and at
              equally spaced intervals thereafter, except where noted:
              a.  Fuel usage in units of  million  standard  cubic feet per
                 month (mmscf/mo)  for  gaseousfuels,  or  thousand  gallons
                 per  month (mgal/mo) for liquid fuels.  Alternatively, the
                 fuel  usage  may be calculated from stack gas volumetric flow
                 rates totalized over a month  and  oxygen  concentration,
                 in which case the Facility Permit holder shall measure:
                 i.  Oxygen concentration in the stack  in  units of percent
                     if required for calculation of the stack gas flow rate.
                 ii. Volumetric  flow  rate of stack gases in units  of  dry
                     standard  cubic  feet per month.   Standard  gas
                     conditions  are defined as a temperature at 68øF and one
                     atmosphere of pressure.
                b. One or more process variables specified in Table 3-A,
                   if the Facility Permit holder elects for an equipment-
                   specific emission rate.
    C. CONCENTRATION LIMIT CALCULATION
          Pursuant to the  election  condition requirements in Rule 2012
          (f), the Facility Permit holder  shall  use the equation provided
          in this section to calculate the concentration  limit.   Equation
          15  applies  to  the  Facility  Permit holder requesting that the
          Emission Fee Billing factor in Table  3-D,  the  emission  factor
          specified  in  Table  1,  Rule  2002  -  Baselines  and  Rates of
          Reduction  for NOx/SOx and/or the contol efficiency in Table  3-E
          be converted into a concentration limit.



                                                   r
          PPMVc   =   0.8368x107 x (20.9-b/20.9) x ä EFj(1-EFFj)/(FdjxVj)
                                                  j=1
                                                                  (Eq.15)



          where:

                  PPMVc  =    The equipment-specific concentration
                              limit corrected at applicable standard
                              oxygen concentration found in Table  3-F or
                              rule-specific concentration limit found in
                              Table 3-C.

                  EFj     =   The equipment-specific  EFB emission
                              factor (lb/mmscf or lb/mgal) found in Table
                              3-D or emission factor found in Table 1 of
                              Rule 2002 or reported value of emission
                              factor.  The emission factor found in Table
                              1 of Rule 2002 may or may not include the
                              appropriate control efficiency.

                  EFFj    =   The equipment-specific control
                              efficiency (%), found in Table 3-E or
                              proposed by the Facility Permit holder.

                  b       =   The standard oxygen concentration (%)
                              found in Table 3-F.

                  Fdj     =   The fuel-specific dry F factor, the
                              ratio of the dry gas volume of the products
                              of combustion to the heat content of the
                              fuel(dscf/mmBtu) specified in 40 CFR Part
                              60, Appendix A, Method 19.

                  V       =   The higher heating value for each type of
                              fuel (mmBtu/mmscf or mmBtu/mgal) found in
                              Table 3-D.

                  j       =   Each type of equipment in a large NOx
                              source sharing a fuel meter and identical
                              concentration limit at standard oxygen
                              concentration.

                   r      =   The total number of equipment in a large
                              NOx  source sharing a fuel meter and
                              identical concentration limit at standard
                              oxygen concentration.

  D.   EMISSION CALCULATION FOR REPORTED DATA
       1. Monthly Mass Emissions for Interim Periods
          Pursuant to Rule 2012 (f) (1), between January 1, 1994
          and December 31, 1994 for Cycle 1 facilities, and between July
          1, 1994 and June 30, 1995 for Cycle 2 facilties, the monthly
          emission of each large source shall be calculated and recorded
          according to:
                              r
                    Eip  =    ä    EFsj x dj                       (Eq.16)
                             j=1

                    where:

                    Eip  =    The monthly mass emission of nitrogen
                              oxides for interim period (lb/month).
                    EFsj =    The starting emission factor used to
                              calculate source emissions in the initial
                              allocation, as specified in Table 1 of
                              Rule 2002 - Allocations for NOx/SOx
                              (lb/mmscf, lb/mgal).
                    dj   =    The monthly metered fuel usage for each
                              type of fuel recorded as mmscf/ month or
                              mgal/month.


                    j    =    Each type of equipment in a large NOx source
                              sharing a fuel meter and identical emission
                              factor.
                    r    =    The total number of equipment in a large NOx
                              source sharing a fuel meter and identical
                              emission factor.


                      
       2.   Monthly Mass Emissions for Normal Operating Hours
            a.   When the Facility Permit holder elects to use the
                concentration limit, the monthly mass emission shall be
                calculated and recorded according to the following equation:
                                                             r
               Ek = PPMVc x [20.9/(20.9-b)] x 1.195 x 10-7 x ä (Fdj x dj x Vj)
                                                            j=1
                                                                         (Eq.17)
                     where:

                    Ek   =    The monthly mass emission of nitrogen
                              oxides (lb/month).
                    PPMVc =   The equipment-specific compliance
                              concentration limit measured over any continuous
                              60 minutes and requested by the Facility Permit
                              holder, or calculated by Eq. 14 in Chapter 3,
                              Subdivision C. (ppmv).

                    b    =    The standard concentrations of oxygen as
                              requested by the Facility Permit holder, or as
                              found in Table 3-F. (%).

                    r    =    The number of different types of fuel.

                    j    =    Each type of fuel.

                  Fdj    =    The dry F factor for each type of fuel,
                              the ratio of the dry gas volume of the products
                              of combustion to the heat content of the fuel
                              (dscf/mmBtu) specified in 40 CFR Part 60,
                              Appendix A, Method 19.
                     dj   =    The monthly  fuel usage for each type of
                              fuel recorded by the fuel totalizer
                              (mmscf per month or mgal per month).

                     Vj   =    The higher heating value of the fuel for
                              each type of fuel found in Table 3-D
                              (mmBtu/mmscf or mmBtu/mgal)

                            The product (dj x Vj) shall have units of
                            mmBtu per month (mmBtu/month).
                            Equation 16 shall not be used in cases where
                            enriched oxygen is used, non-fuel sources of
                            carbon dioxide are present (e.g., lime kilns
                            and calciners), and the oxygen content of the
                            stack gas is 19 percent or greater.

                       b.   When the Facility Permit holder elects to
                            use the emission rate, the monthly emission
                            shall be calculated and recorded according
                            to:
                                   r
                            Ek =   ä    dj   x   Vj   x ERj   (Eq.18)
                                  j=1

                            where:

                                 Ek=The monthly mass emission of nitrogen
                                 oxides (lb/month).

                                 dj=The monthly fuel usage for each type
                                 of fuelrecorded by the fuel totalizer
                                 (mmscf/month ormgal/month).

                                 ERj=The equipment-specific emission rate
                                 proposed bythe Facility Permit holder
                                 and determinedaccording to Chapter 5,
                                 Subdivision E
                                 (lb/mmBtu).

                                 Vj=The higher heating value of each type
                                 of fuel
                                 (mmBtu/mmscf or mmBtu/mgal).


          3.    Monthly Mass Emissions during Startup or Shutdown Periods
                The Facility  Permit  holder  of a large source with startup or
                shutdown periods at least 6 hours  in  duration shall apply the
                following methodology to determine the emissions during startup
                and shutdown periods:
              a. During  equipment  startup  or shutdown the  Facility  Permit
                 holder shall apply the EFB emission  factor  specified in
                 Table 3-D; or
              b. If  the  emission  factors  in Table 3-D do not  reflect  the
                 emission  factors  during startup  and  shutdown  periods,  the
                 Facility Permit holder  shall  propose emission factors for the
                 approval of the Executive Officer  and shall submit source test
                 data  to  substantiate  the  proposed  emission  factors.   The
                 monthly emissions during startup and shutdown  periods shall be
                 calculated and reported according to:

                          r
                  Est =   ä      Dstj   x   EFstj  (Eq.19)
                         j=1



                          r
                  Esh =   ä      Dsh   x   EFsh    (Eq.20)
                         j=1

          where:

          Est  = The  monthly  mass  emission  of  nitrogen  oxides  during
                 startup period (lb/month).

          Dstj  = The  monthly  fuel  usage  for  each  type of fuel  during
                  startup period (mmscf/month or mgal/month).

          EFstj = The   EFB   or   Facility  Permit  holder-specified
                  emission factor during startup period (lb/mmscf orlb/mgal).

          where:

          Esh   = The  monthly  mass  emission  of  nitrogen  oxides  during
                  shutdown period (lb/month).

          Dshj  = The  monthly fuel usage  for  each  type  of  fuel  during
                  shutdown period (mmscf/monthor mgal/month).

          EFshj = The  EFB  or  Facility  Permit holder-specified emission
                  factor during shutdown period(lb/mmscf or lb/mgal).

          j     =    Each type of fuel

          r    =    The number of each type of fuel consumed per month.


   E.   TOTAL MONTHLY MASS EMISSION CALCULATION
               The total monthly mass emission  shall  be  calculated and
          recorded for each equipment according to:

          E       = Ek+  Em+  Est+    Esh
          (Eq.21)

              Where:

                          E=The monthly mass emission of nitrogen oxides
                          (lb/month).

                          Ek=The monthly mass emission calculated using
                          measured data during normal operation
                          (lb/month).

                          Em=The monthly mass emission calculated using
                          substitute data during normal operation
                          (lb/month).

                          Est=The monthly mass emission calculated during
                          startup period (lb/month).

                          Esh=The monthly mass emission calculated during
                          shutdown period (lb/month).
    F. FLOW DETERMINATION TEST METHODS
       1.   District Methods 2.1 and 2.3 shall be used to determine
          the stack gasvolumetric flow rate.
       2.      For District Method 2.1, District Method 1.1 shall be
          used to select the sampling site and the number of traverse
          points.
       3.      District Method 3.1 shall be used for diluent gas (O2
          or CO2) concentration and stack gas density determination.
       4.      District Method 4.1 shall be used for moisture
          determination of stack gas.
    G. REPORTING PROCEDURES
       1.      The total fuel usage data for all large sources in any
          facility without a RTU or modem shall be reported in a format
          approved by the Executive Officer.
       2.      For each equipment the following information shall be
          stored on-site in a format approved by the Executive Officer:
          a. Calendar dates covered in the reporting period;
          b. Monthly mass emissions for each equipment ;
          c. Identification of the equipment operating days for
             which a sufficient number of valid data points has not been
             taken; reasons for not taking sufficient data; and a
             description of corrective action taken;
          d. Identification of Fd or Fw factor for each type of
             fuel used for calculation and the type of fuel burned;
          e. Any changes made in type of fuel used and Fd
             factor, if applicable.
   H. ALTERNATIVE PROCEDURES

          The following requirements are applicable when the Facility
          Permit holder chooses to make alternative measurements other
          than fuel flow meter, such as exhaust flow rates and oxygen
          sensor:
          1. Emission Stack Flow Rate Determination
             In the event that more than one source vents to a common
             stack, the alternative reference method for determining
             individual source flow rates shall be EPA Method 19.  The
             orifice plates used in every unit vented to a common stack
             shall meet the requirements in  Chapter 3, Subdivision H,
             Paragraph 3.
          2. Quality Assurance Procedures for Volumetric Flow
             Measurement System
             a.      Each volumetric flow measurement system shall be
               audited at least once each calendar year.  Successive audits
               shall occur no closer than six months or after any
               modification to the process which would significantly alter
               the flow.
             b.If the volumetric flow measurement system is found to be
               out of calibration by 10 percent or greater, then recalculation of
             the flow measurement must be performed from the last audit date to
             the current audit date.
          3. Quality Assurance for Orifice Plate Measurements
             Each orifice plate used to measure the fuel gas flow rate
             shall be removed from the gas supply line for an inspection
             once every 12 months, if the orifice cannot be checked using
             Reference Methods or other methods that can show
             traceability to NIST standards.  However, with the prior
             approval of the Executive Officer, orifice plates may be
             inspected not less than once every 36 months provided the
             Facility Permit holder demonstrates to the Executive Officer
             that orifice plates used for 36 months or longer meet the
             specifications set forth in this paragraph.  This
             demonstration shall be completed by July 1, 1995 or within
             one year for facilities that enter RECLAIM on and after July
             1, 1994.  The following items shall be subject to
             inspection:
             a.   Each orifice plate shall be visually inspected for
               any nicks, dents,corrosion, erosion, or any other signs of
               damage according to theorifice plate manufacturer's
               specifications.
             b.  The diameter of each orifice shall be measured using the
               method recommended by the orifice plate manufacture.
             c.  The flatness of the orifice plate shall be checked
               according to the orifice plate manufacturer's instructions.
               The departure from flatness of an orifice plate shall not
               exceed 0.010 inches per inch of dam height (D-d/2) along any
               diameter.  Here D is the inside pipe diameter and d is the
               orifice diameter at its narrowest constriction.
             d.  The pressure gauge or other device measuring
               pressure drop across the orifice shall be calibrated against
               a manometer, and shall be replaced if it deviates more than
               ñ2 percent across the range.
             e.  The surface roughness shall be measured using the method
               recommended by the orifice plate manufacturer.  The surface
               roughness of an orifice plate shall not exceed 50 micro
               inches.
             f.  The upstream edge of the measuring orifice shall be
               square and sharp so that it shall not show a beam of light
               when checked with an orifice gauge.
             g.  In centering orifice plates, the orifice shall be
               concentric with the inside of the meter tube or fitting.
               The concentricity shall be maintained within 3 percent of
               the inside diameter of the tube or fitting along all
               diameters.
             h.   Any other calibration tests specified by the orifice plate
               manufacturer shall be conducted at this time.  If an orifice
               fails to meet any of the manufacturer's specifications, it
               shall be replaced within two weeks.
 I.  MISSING AND INVALID DATA PROCEDURES
    1.      For each large source or large sources using a common
          fuel meter, the Facility Permit holder shall provide substitute
          data as described below whenever a valid month of fuel usage
          data has not been obtained and recorded.  Alternative data is
          acceptable for substitution if the Facility Permit holder can
          demonstrate to the Executive Officer that the alternative
          system is fully operational during meter down time and within +
          2% accuracy.
    2.      Whenever data from the process monitor is not available
          or not recorded for the affected equipment or when the
          equipment is not operated within the parameter range specifed
          in the Facility Permit, the Facility Permit holder shall
          calculate substitute data for each month according to the
          following procedures.
          a.           For a missing data period less than or equal to
            one month, substitute data shall be calculated using the large
            source(s) average monthly fuel usage for the previous 12
            months.
          b.  For a missing data period greater than one month, substitute
            data shall be calculated using the large source(s) highest
            monthly fuel usage data for the previous 12 months.
          c.  For a missing data period greater than two months,
            or if the facility has no records, substitute data shall be
            calculated using 100 percent uptime during the substitution
            period and the large source(s) maximum rated capacity and
            uncontrolled emission factor for each month of missing data.
 J. FUEL METER SHARING
     1.   A single totalizing fuel meter shall be allowed to measure
          the cumulative fuel usage for more than one equipment in a
          large NOx source provided that each equipment has the same
          concentration limit, emission rate, or emission factor as
          specified in the Facility Permit and that any equipment in a
          large NOx source does not use the annual heat input in order to
          be classified from a major source to a large source.
     2.      One or more pieces of equipment in a large NOx source
          shall be allowed to share the fuel totalizing meter with the
          equipment in a process unit provided that each equipment elects
          for the same concentration limit, emission rate, or emission
          factor as specified in the Facility Permit.
     3.   Fuel meter sharing for the interim period shall be allowed
          for those equipment in a large NOx source with the same
          emission factor, emission rate, or concentration limit.


                              Table 3-A

               MEASURED AND PROCESS VARIABLES FOR LARGE NOx SOURCES

                             EQUIPMENT TYPE : BOILERS





               MEASURED AND PROCESS VARIABLES FOR LARGE NOx SOURCES

                             EQUIPMENT TYPE : FURNACES




               MEASURED AND PROCESS VARIABLES FOR LARGE NOx SOURCES

                              EQUIPMENT TYPE : OVENS



             MEASURED AND PROCESS VARIABLES FOR LARGE NOx SOURCES

                              EQUIPMENT TYPE : DRYERS



             MEASURED AND PROCESS VARIABLES FOR LARGE NOx SOURCES

                         EQUIPMENT TYPE : PROCESS HEATERS



             MEASURED AND PROCESS VARIABLES FOR LARGE NOx SOURCES

                           EQUIPMENT TYPE : INCINERATORS





             MEASURED AND PROCESS VARIABLES FOR LARGE NOx SOURCES

                            EQUIPMENT TYPE : TEST CELLS





               MEASURED AND PROCESS VARIABLES FOR LARGE NOx SOURCES

                   EQUIPMENT TYPE : INTERNAL COMBUSTION ENGINES



               MEASURED AND PROCESS VARIABLES FOR LARGE NOx SOURCES

                           EQUIPMENT TYPE : GAS TURBINES



           

              MEASURED AND PROCESS VARIABLES FOR LARGE NOx SOURCES

                       EQUIPMENT TYPE : KILNS AND CALCINERS



           
             MEASURED AND PROCESS VARIABLES FOR LARGE NOx SOURCES

                 EQUIPMENT TYPE : SULFURIC ACID PRODUCTION PLANTS



                                Table 3-B

                   REPORTED VARIABLES FOR ALL LARGE NOx SOURCES



                                TABLE 3-C

             RULE-SPECIFIC CONCENTRATION LIMITS FOR LARGE NOx SOURCES
                               AND NOx PROCESS UNITS

               * Converted from Rule limit, which is 0.03 lb/mmBtu.








                                     Table 3-D

            EMISSION FEE BILLING FACTORS FOR LARGE NOx SOURCES AND NOx
                                   PROCESS UNITS



                                      Table 3-E

                     UNREGULATED DEFAULT CONTROL EFFICIENCIES




                                       Table 3-F

               STANDARD OXYGEN CONCENTRATIONS FOR LARGE NOx SOURCES
                               AND NOx PROCESS UNITS