SCAQMD RULE 2011-2 MJR SOURCES - CONT. EMIS. MONITORING SYS
LAST REVISED 11/11/11


         C H A P T E R   2



         M A J O R  S O U R C E S  -  C O N T I N U O U S  E M I S S I O N

         M O N I T O R I N G  S Y S T E M  ( C E M S )



                                  TABLE OF CONTENTS


             CHAPTER 2 - MAJOR SOURCES - CONTINUOUS EMISSION MONITORING
             SYSTEM (CEMS)

             A. Measurement Requirements................................5
             B. Monitoring Systems......................................8
             C. Reporting Procedures...................................23
             D. Alternative Procedures for Emission Stack Flow Rate
                Determination                                          24
             E. Missing Data Procedures................................27
             F. Time-Sharing...........................................31



             Rule 2011
             October 15, 1993

      PROTOCOL FOR RULE 2011


             The  criteria  for  determining  the  applicable SOx RECLAIM
             category for a specific piece of equipment  is  presented in
             Table 1-A for a major source.  If a major source category is
             applicable  to  this  equipment,  then  the  Facility Permit
             holder  shall  be  required  to  comply with the performance
             standards  associated  with  a  CEMS  (Continuous   Emission
             Monitoring  System)  or  an  approved Alternative Monitoring
             System (AMS).


             The Facility Permit holder of  a  source that is required to
             install CEMS may request the Executive Officer to approve an
             alternative  monitoring  device  (or system  components)  to
             quantify emissions of SOx.  The applicant  shall demonstrate
             to  the  Executive  Officer  that  the  proposed alternative
             monitoring  device  is at a minimum equivalent  in  relative
             accuracy, precision,  reliability,  and timeliness to a CEMS
             for that source, according to the criteria  specified  in 40
             CFR Part 75 Subpart E.  In lieu of the criteria specified in
             40  CFR Part 75 Subpart E, substitute criteria is acceptable
             if the  applicnt  demonstrates to the Executive Officer that
             the proposed alternative  monitoring  device  is  at minimum
             equivalent in relative accuracy, precision, reliability, and
             timeliness to a CEMS for that source.  Upon approval  by the
             Executive   Officer,   the   substitute  criteria  shall  be
             submitted to the federal Environmental  Protection Agency as
             an amendment to the State Implementation Plan (SIP).

             Chapter   2  describes  the  methodologies  for   measuring,
             monitoring, and reporting emissions from major sources.  All
             major sources  shall  be monitored by a continuous emissions
             monitoring system (CEMS) or an alternative monitoring system
             (AMS).   The  required  equipment-specific  variables,  both
             measured and reported, to  be  monitored are found in Tables
             2-A and 2-B, respectively.

             Another important requirement of  major  SOx  sources is the
             way  in  which they transmit data to the District's  Central
             Station and  the  reporting  frequency.  Major sources shall
             electronically transmit the data  via  an  RTU  on  a  daily
             basis.   In  addition, the aggregated NOx emissions from all
             major sources  must  be  submitted  in  a  Monthly Emissions
             Report.

             During the interim period, January 1, 1994 through  December
             31,  1994  for  Cycle  1 facilities and July 1, 1994 through
             June 30, 1995 for Cycle  2  facilities  mass  emissions  for
             major  sources  shall  be  determined using emission factors
             referenced in Table 2 of Rule 2002.

             Other  important aspects covered  in  this  chapter  include
             missing data procedures and CEMS timesharing requirements.



             A.   MEASUREMENT REQUIREMENTS

                  1.   Between  January  1,  1994  and  December 31, 1994
                       (Cycle 1 facilities) and between July  1, 1994 and
                       June 30, 1995 (Cycle 2 facilities), major  sources
                       shall  be  allowed  to  use  an  interim reporting
                       procedure to measure and record SOx emissions on a
                       monthly  basis  and  may  be  extracted  from  SOx
                       emission   data  gathered  by  existing   District
                       certified continuous  emissions  monitoring system
                       (CEMS).   Chapter  2,  Subdivison C,  Paragraph  1
                       specifies  the  requirements   for   this  interim
                       period.   On  and after January 1, 1995  (Cycle  1
                       facilities) and July 1, 1995 (Cycle 2 facilities),
                       the Facility Permit  holder  of  each major source
                       shall  report a daily average of NOx  emission  by
                       5:00 p.m. of the following day and comply with all
                       other applicable  requirements  (except Chapter 2,
                       Subdivision C, Subparagraph 1) specified  in  this
                       chapter.

                  2.   The Facility Permit holder shall by March 31, 1994
                       for  Cycle 1 facilities and September 30, 1994 for
                       Cycle  2  facilities,  submit  a  CEMS plan to the
                       Executive  Officer for approval.  The  plan  shall
                       contain at a minimum the following items:

                     a.   A list of all major sources which will have CEMS
                          installed.
                     b.   Details of all proposed Continuous Emission 
                          Monitors as well as the proposed flow monitors for 
                          each affected source.
                     c.   Details of the Quality Control/Quality Assurance 
                          Plan for the CEMS.
                     d.   Proposed range of each CEMS and the expected
                          concentrations of pollutants for each source.
                     e.   Date by which purchase order for each system will 
                          be issued.
                     f.   Construction schedule for each system, and date of
                          completion of the installation.
                     g.   Date by which CEMS certification test protocol will be
                          submitted to the District for approval for each 
                          system.
                     h.   Date by which certification tests will be completed 
                          for each system.
                     i.   Date by which certification test results will be
                          submitted for review by the District, for each 
                          system.
                     j.   Any other pertinent information regarding the
                          installation and certification for each system.
                     If a CEMS Plan is disapproved in whole or in part,
                     the District staff will notify the Facility Permit
                     holder in writing  and  the Facility Permit holder
                     shall have 30 days from the  date  it receives the
                     notice from the District to resubmit its plan.

             3. The Facility Permit holder of each major SOx equipment
                shall install, calibrate, maintain, and operate an approved
                CEMS to measure and record  the following:
                a.   Sulfur oxide concentrations in the gases discharged to
                     the atmosphere from affected equipment.
                b.   Oxygen concentrations, at each location where sulfur
                     oxide concentration are monitored, if required for
                     calculation of the stack gas flow rate.
                c.   Stack gas volumetric flow rate.  An in-stack flow meter
                     may be used to determine mass emissions to the atmosphere
                     from affected equipment, except:
                     i.   when  more  than one affected  piece  of
                          equipment  vents   to   the   atmosphere
                          through a single stack, or

                    ii.  during  periods  of low flow rates  when
                         the flow rate is no  longer  within  the
                         applicable  range  of  the in-stack flow
                         meter.

                d.   In lieu of complying with Chapter 2, Subdivision A,
                     Paragraph 1, Subparagraph c if heat input rate is needed 
                     to determine the stack gas volumetric flow rate, the 
                     Facility Permit holder shall include in the CEMS 
                     calculations the Fd factors listed in 40 CFR Part 60, 
                     Appendix A, Method 19, Table 19-1.  The Facility Permit 
                     holder shall submit data to develop Fd factors when 
                     alternative fuels are fired and obtain the approval of 
                     the Executive Officer for use of the Fd factors before 
                     firing any alternative fuels.
                e.   Fuel gas flow rate if the CEMS uses the fuel gas flow
                     rate and the sulfur content of the fuel gas to 
                     determine the sulfur oxide emissions.
                f.   Sulfur content of the fuel if the CEMS uses the fuel
                     input rate and the sulfur content of the fuel gas to
                     determine the sulfur oxides emission rate.
                g.   All applicable varaiables listed in Table 2-A.
                h.   The Facility Permit holder shall also provide any other
                     data necessary for calculating air contaminant emissions 
                     as determined by the Executive Officer.
                i.   The data shall be recorded both by strip chart
                     recorders and computer print out.  The strip chart shall
                     have a minimum chart width of 10 inches, a readability of
                     0.5% of the span, and a minimum of 100 chart divisions.
             4. The Facility Permit holder must submit to the District
                his certification test results and supporting document for
                each CEMS by December 31, 1994.  It must certify that the
                results show that the CEMS has met all the requirements of
                the rule if its submission is after August 31, 1994.  Upon
                receipt of the test results and the certification that the
                CEMS is in compliance, the District will issue a Provisional
                Approval.
                  After the Provisional Approval, all the data measured
                and recorded by the CEMS will be considered valid quality
                assured data, (retroactive to January 1, 1995) provided that
                the Executive Officer does not issue a notice of disapproval
                of final certification.  Final certification of the CEMS
                will be granted if the certification test results show that
                the CEMS has met all the requirements of the rule.
                  In the case where the test results show that the CEMS
                does not meet all the requirements of the rule, the
                Executive Officer will disapprove the final certification.
                If this occurs, the previously considered valid data from
                January 1, 1995 will have to be replaced by data as
                specified in the "Missing Data" section of the rule.  This
                procedure shall be used until the time that new
                certification test results are submitted, and the CEMS has
                received final approval by the District.
             5.   The variables listed in Table 2-A shall be measured and
                recorded to track the operation of basic and control
                equipment independent of measurements made by the monitoring
                equipment. The variables found in Table 2-B shall be
                reported to the District's SOx Central Station Computer.
                Alternatives in Table 2-A and 2-B indicated choices which
                must be specified in the Facility Permit for that equipment.
             6.   As part of the Facility Permit Application review, the
                Executive Officer may modify the list of Facility Permit
                holder-selected variables.
             7.   Data on Facility Permit holder - selected variables
                shall be made available to the District staff upon request.
             8.   Source tests shall be performed by testing
                firms/laboratories who have received approval from the
                District by going through the District's laboratory approval
                program.
             9.   All Relative Accuracy Test Audits (RATA) shall be
                performed by testing firms/laboratories who have received
                approval from the District by going through the District's
                laboratory approval program.
             10.  Whenever EPA Protocol 1 gases are not available because
                National Institute for Standards and Testing (NIST) does not
                produce Standard Reference Materials (SRMs) for these gases
                at the appropriate concentration, EPA Protocol 2 (use of gas
                dilution systems) may be used to certify calibration gas
                standards.  In the case where no SRMs are available, the
                facility can submit a gas calibration protocol for approval,
                which specifies the steps to be taken for analyzing the
                concentration and stability of calibration gases.
             B.   MONITORING SYSTEMS

             1.   Information Required for Each 15-Minute Interval
                  All CEMS for affected equipment shall, at a minimum,
                  generate and record the following data points once for each
                  successive 15-minute period on the hour and at equally
                  spaced intervals thereafter:
             a.   Sulfur oxide concentration in the stack in units of
                  ppmv.
             b.   Oxygen concentration or carbon dioxide in the stack in
                  units of percent.
             c.   Volumetric flow rate of stack gases in units of dry or
                  wet standard cubic feet per hour (dscfh or wscfh).  For
                  affected equipment standard gas conditions are defined as a
                  temperature at 68F and one atmosphere of pressure.
             d.   Fuel flow rates in units of standard cubic feet per
                  hour (scfh) for gaseous fuels or pounds per hour (lb/hr) for
                  liquid fuels if EPA Method 19 is used to calculate the stack
                  gas volumetric flow rate.
             e.   Sulfur  oxide  mass  emissions  in  units  of
                            lb/hour.  The  sulfur  oxide  emissions   are
                            calculated according to the following:

                             ei = ai x ci x 1.662 x 10-7          (Eq. 1)

                             where:

                             ei   =   The mass emissions of sulfur oxides
                                      (lb/hr),

                             ai   =The  stack gas concentration of sulfur
                                      oxide    measured    on    a    dry
                                      basis(ppmv),

                             ci   =The  stack  gas  volumetric  flow rate
                                      (dscfh).

             Example Calculation:

                                 ai = 2.7 ppm
                                 ci = 90,000 dscfh
                                 ei = ai x ci  x 1.662 x 10-7
                                 ei = (2.7)(90,000)(1.662 x 10-7)
                                     = 0.04 lb/hr SOx

                  When  the  CEMS  uses  the  heat  input rate and oxygen
                  concentration to determine the sulfur  oxide emissions,
                  the following equation would be used to  calculate  the
                  emission of sulfur oxide:

                                                  r
              ei = aix[20.9/(20.9-bi)]x1.662x10-7x(FdijxdijxVij)                                           (Eq. 2)
                                                 j=1

                  where:

                  ei   =     The mass emissions of sulfur oxide (lb/hr),

                  ai   =     The  stack  gas  concentration  of  sulfur
                             oxide on a dry basis (ppmv),

                  bi   =     The  stack gas concentrations of oxygen on a dry
                             basis (%),

                  r    =     The number of different types of fuel,

                  Fdij =     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/106 Btu),

                   dij =     The  metered  fuel flow rate for each type
                              of fuel measured every 15-minute period,

                  Vij  =      The higher heating value  of  the  fuel  for 
                              each type of fuel.

                  The product (dij x Vij) must have units of millions  of
                  Btu  per hour (106 Btu/hr).  Equation 2 may 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.

             Example Calculation:

                                                      r
                  ei = aix[20.9/(20.9-bi)]x1.662x10-7x(Fdij x dij x Vij)
                                                     j=1
                  where:

                  ai = 38.9 ppm

                  bi = 5.6%

                  Fdij = 8710 dscf/106 Btu

                  dij = 10,000 dscfh

                  Vij = 1394 Btu/dscf

                  ei= 38.9x[20.9/(20.9-5.6)]x1.662x10-7x[8710/106x10000x1394]

                  ei = 1.1 lb/hr of SOx

             When the CEMS uses the heat input rate and carbon dioxide
             concentration to determine the sulfur oxide emissions, the
             following equation shall be used to calculate the emission
             of sulfur oxide:

                                              r
                  ei = (ai/ti)x100x1.662x10-7x(FcijxdijxVij)                                                 (Eq. 3)
                                             j=1

                  where:

                  ei   =     The mass emissions of sulfur oxide (lb/hr).

                  ai   =     The stack  gas  concentration  of  carbon
                             dioxide on a dry basis (ppmv).

                  ti   =     The stack gas concentrations of carbon dioxide 
                             on a dry basis (%).

                  r    =     The number of different types of fuel.

                  Fcij =     The carbon-based, dry F factor for each
                              type of fuel, the ratio of the dry gas
                              volume of carbon dioxide to the heat
                              content of the fuel (dscf/106 Btu).

                  dij =       The metered fuel  flow  rate for each type
                              of fuel measured every 15-minute period.

                  Vij  =      The  higher heating value of the fuel for each
                              type of fuel.

                  The product  (dij x Vij) must have units of millions of
                  Btu per hour (106 Btu/hr).
             
             Example Calculation:

                                               r
                  ei = (ai/ti)]x100x1.662x10-7x(FcijxdijxVij)
                                              j=1
                  where:

                  ai = 38.9 ppm

                  ti = 11.0%

                  dFcij = 1040 scf/106 Btu

                  dij = 10,000 dscfh

                  Vij = 1394 Btu/dscf

                  ei= (38.9/11.0)x100x1.662x10-7x[1040/106x10000x1394]

                  ei = 0.85 lb/hr of SOx

                  When the CEMS  uses  the  fuel  gas  flow  rate and the
                  sulfur content to determine the sulfur oxides  emission
                  rate,  the  CEMS  shall  use the following equation  to
                  calculate the emissions of sulfur oxide:

                  ei = si x di x 1.662 x 10-7                     (Eq. 4)


                  where:

                  ei   =     The emissions of sulfur oxide (lb/hr),

                  si   =     The sulfur content of fuel gas (ppmv),

                  di   =     The fuel gas flow rate (scfh).

                  Example Calculation:

                       si = 38 ppmv

                       di = 1,576,980 scfh = 1.577 x 106 scfh

                       ei = (38)(1.577 x 106 scfh)(1.662 x 10-7)=9.96 lb/hr.

                  f.   All measurements for  concentrations and stack gas
                       flow rates, and selection  of  F  factor  shall be
                       made on a consistent wet or dry basis.

                  g.   CEMS status. The following codes shall be used  to
                       report the CEMS status:

                            1-1 - VALID DATA

                            2-2 - CALIBRATION

                            3-3 - OFF LINE

                            4-4 - ALTERNATE DATA ACQUISITION (e.g., manual
                                  sampling)

                            5-5 - OUT OF CONTROL

                            6-6 - FUEL SWITCH (e.g., gas to oil, coke to
                                  coal)

             2.   Hourly Calculations
                       The  hourly  average  stack  gas concentrations of
                       sulfur oxides and oxygen, the stack gas volumetric
                       flow  rate, the fuel flow rate,  the  fuel  sulfur
                       content  of the fuel gas, and the emission rate of
                       sulfur oxides  shall  be calculated for each piece
                       of affected equipment as follows:
                              n
                               ai
                              i=1
                        A =  ----    (for SOx concentration)      (Eq. 5)
                             n

                              n
                               bi
                              i=1
                        B =  ----    (for O2 concentration)       (Eq. 6)
                             n

                              n
                               ci
                              i=1
                        C =  ---- (for stack gas volumetric flow rate)(Eq. 7)
                             n

                              n
                               di
                              i=1
                        D =  ----    (for fuel flow rates)        (Eq. 8)
                             n

                        Calculate  D  for  each  type   of   fuel  firing
                  separately.

                              n
                               si
                              i=1
                        S  = ---- (for sulfur content of fuel  gas) (Eq. 9)
                               n

                              n
                               ei
                              i=1
                        Ek = ----    (for SOx emissions)         (Eq. 10)
                             n

                  All concentrations  and  stack  gas flow rates shall be
                  made on a consistent wet or dry basis

                  where:

             A    =    The  hourly  average  stack gas  concentration  of
                             sulfur oxides (ppmv),

             ai   =    The measured stack gas  concentrations  of  sulfur
                             oxides (ppmv),

             B    =     The     hourly    average    oxygen    stack
                               concentration (%),

             bi   =     The measured  stack  gas  concentrations  of
                               oxygen (%),

             C    =     The  hourly  average  stack  gas  flow  rate
                               (dscfh),

             ci   =     The measured stack gas volumetric flow rates
                               (dscfh),

             D    =    The  hourly  average  metered fuel flow rates, for
                             each  type  of fuel  (appropriate  units  of
                             volumetric flow  rate for each type of fuel,
                             e.g.,   scfh,   gal./hr,    lb/hr,   bbl/hr,
                             liters/hr, etc.),

             di   =    The metered fuel flow rates for each  type of fuel
                             (appropriate units of volumetric  flow  rate
                             for  each type of fuel, e.g., scfh, gal./hr,
                             lb/hr, bbl/hr, etc.),

             S    =    the hourly average  sulfur  content  of  the  fuel
                             (ppmv),

             Ek   =     The hourly average emissions of sulfur oxide
                               (lb/hr),

             ei   =     The   measured  emissions  of  sulfur  oxide
                               (lb/hr),

             n    =     Number of valid data points during the hour.

                  The values of A through  Ek  shall be recorded for each
                  affected piece of equipment.

                  Example Calculation:

                  For SOx concentration:a1 = 3.0 ppm, a2 = 4.6 ppm, a3 =
                  12.2 ppm,                                 a4 = 7.0 ppm.
                            n
                             ai
                            i=1
                  A    =    ____ =    3.0 + 4.6 + 12.2 + 7.0=6.7 ppm
                             n                   4

                  For O2 concentration:

                  b1, = 3.5% O2, b2 = 5.2%, b3 = 4.4%, b4 = 3.0%
                            n
                             bi
                            i=1
                  B    =    ____ =    3.5 + 5.2 + 4.4 + 3.0=4.0 %
                             n                   4

                  For stack gas volumetric flow rate:

                       c1 = 89,160 dscfhc3 = 91,980 dscfh
                       c2 = 90,120 dscfhc4 = 89,520 dscfh

                            n
                             ci
                            i=1
                  C    =    ____ =    89,160+90,120+91,980+89,520
                             n                  4

                       = 90,195 dscfh

                  For Sulfur:

                             n
                              Si
                      S =    i   =   1 (for sulfur content of fuel gas) n

                      S1     =  558 ppmv H2S S3  = 722 ppmv H2S

                      S2     =  630 ppmv H2S S4  = 785 ppmv H2S

                      S      =  588+630+722+785  = 681 ppmv H2S
                                         4

                  For fuel flow rate:

                       d1 = 106,392 dscfhd3 = 101,426 dscfh
                       d2 = 96,504 dscfhd4 = 92,065 dscfh
                            n
                             di
                            i=1
                  D    =    ____ =    106,392+96,504+101,406+92,065
                             n                  4

                       = 99,097 dscfh

                  For SOx emission rate:

                       e1 = .032 lb/hr e2 = .037 lb/hr e3 = .039 lb/hr e4
                  =.041 lb/hr

                            n
                             ei
                            i=1
                  Ek   =    ____ =    .032+.037+.039+.041
                             n                 4

                       = .037 lb/hr.

                  3.   Daily Calculations

             a.   Daily mass emissions calculation
                  The daily emissions of sulfur oxides shall be
             calculated and recorded for each affected SOx source using
             the following procedure:
                                     N             P
                             G      = Ek       + Em          (Eq. 11)
                                     k=1          m=1

                              where:

                             G   =    The daily emissions of sulfur oxide
                                      (lb/day),

                             Ek  =    The hourly  average  emission  rate
                                      using CEMS                 (lbs/hr)

                             Em  =    The hourly average emission rate of
                                      sulfur oxidesusing substitute data (see
                                      Chapter 2, SubdivisionB, Paragraph 5,
                                      Subparagraph b andChapter 2, 
                                      Subdivision F)(lb/hr),

                             N   =    Number  of hours of valid data (see
                                      Chapter 2,  Subdivison B, Paragraph
                                      5)  from the CEMS  coinciding  with
                                      the source operating hours,

                             P   =    Number  of  hours  using substitute
                                      data when the source  is operating;
                                      and

                             M   =    Number  of operating hours  of  the
                                      source during the day,

                             Note that M=  N + P

                  Example Calculation:

                       Em   =    1.7 lb/hr
                       N    =    23 hrs
                       P    =    1 hr
                       M    =    24 hr
                       Ek   =    0.037 lb/hr
                       G    =    (0.037 lb/hr)(23 hr) + (1.7 lb/hr)(1hr)
                       G    =    2.55 lb/day SOx

             4.   Operational Requirements
                  The CEMS shall be operated and data recorded during all
                  periods of operation of the affected SOx source including
                  periods of start-up, shutdown, malfunction or emergency
                  conditions, except for CEMS breakdowns and repairs.
                  Calibration data shall be recorded during zero and span
                  calibration checks, and zero and span adjustments.  For
                  periods of hot standby the Facility Permit holder may enter
                  a default value for SOx emissions.  Before using any default
                  values the Facility Permit holder must obtain the approval
                  of the Executive Officer and must include in the CEMS
                  applications or CEMS plans the estimates of SOx emissions,
                  the SOx concentrations, the oxygen concentrations, the
                  sulfur content of fuel gas, and the fuel input rates or the
                  stack gas volumetric flow rates during hot standby
                  conditions.  The Executive Officer will approve only those
                  emission values which are found to correspond to hot standby
                  conditions.
             5.   Requirements for Valid Data Points
                  Valid data points are data points from the CEMS which
                  meet the requirements of Chapter 2, Subdivision B, Paragraph
                  16 or which are obtained by the methods indicated in Chapter
                  2, Subdivision B, Paragraph 6 and Chapter 2, Subdivision B,
                  Paragraph 7.
                  a.   Each CEMS and component thereof shall be capable of
                       completing a minimum of one cycle of operation 
                       (sampling analyzing and data recording) for each 
                       successive 15-minute interval.  All SOx concentration, 
                       volumetric flow,  fuel gas sulfur content , and SOx 
                       emission data shall be reduced to 1 hour averages.  
                       These averages shall be equally computed from four or 
                       more data points equally spaced over each 1-hour 
                       period, except for periods of calibration, quality 
                       assurance activities, CEMS maintenance, or CEMS repair.
                       During these periods a valid hour shall consist of at 
                       least two data points with each representing a 15 
                       minute period and a cycle of operation as described 
                       above, provided the number of these periods does not 
                       exceed four per day.
                  b.   Failure of the CEMS  to  acquire the required
                       number of valid data points  shall  result in
                       the loss of such data for the entire hour and
                       the  Facility Permit holder shall record  and
                       report  data by means of the data acquisition
                       and handling  system  for the missing hour in
                       accordance with the applicable procedures for
                       substituting missing data in the Missing Data
                       Procedures  in Chapter 2,  Subdivision  E  of
                       this document.

             6.   Alternative  Data  Acquisition   Using   Reference
                  Methods

                       a.   When valid sulfur oxides emission data is not
                            collected by the permanently installed  CEMS,
                            emission  rate  data  may  be  obtained using
                            District  Methods  6.1  or  100.1  (for   SOx
                            concentration    in   the   stack   gas)   in
                            conjunction with District  Methods  1.1, 2.1,
                            3.1, and 4.1 or by using District Methods 6.1
                            or 100.1 in conjunction with District  Method
                            3.1  and  EPA  Method 19.  Emission rate data
                            may also be obtained  using  District Methods
                            307-91 or ASTM Method D1072-90, Standard Test
                            for  Total Sulfur in Fuel Gases  (for  sulfur
                            content  in the fuel gas) in conjunction with
                            the fuel gas flow rate.

                       b.   If the Facility  Permit holder chooses to use
                            a standby CEMS (such  as  in  a mobile van or
                            other  configuration), to obtain  alternative
                            monitoring   data  at  such  times  when  the
                            permanently installed  CEMS  for the affected
                            source(s) cannot produce valid data, then the
                            standby  CEMS  is  subject  to the  following
                            requirements:
                            i.   Standby  CEMS  shall  be  equivalent  in
                                 relative      accuracy,     reliability,
                                 reproducibility  and  timeliness  to the
                                 corresponding    permanently   installed
                                 CEMS.

                            ii.  The Facility Permit  holder shall submit
                                 a standby CEMS plan to  the District for
                                 review prior to using the standby CEMS.

                            iii. District acceptance of standby CEMS data
                                 shall be contingent on District approval
                                 of the plan.

                            iv.  The use of standby CEMS shall be limited
                                 to a total of 6 months for any source(s)
                                 within a calendar year.

                            v.   The Facility Permit holder  shall notify
                                 the  District  within  24 hours  if  the
                                 standby CEMS is to be used  in  place of
                                 the permanently installed CEMS.

                            vi.  During the first 30 days of standby CEMS
                                 use,  the  Facility  Permit holder shall
                                 conduct a Certified Gas  Audit  (CGA) of
                                 the standby CEMS.

                            vii. The Facility Permit holder shall  notify
                                 the District within the 30-day period if
                                 the  standby  CEMS  shall be used longer
                                 than 30 days.

                            viii.     After the first  30  days  of using
                                 the  standby  CEMS,  the Facility Permit
                                 holder shall conduct at  least  one RATA
                                 of  the standby CEMS and the RATA  shall
                                 be  conducted  within  90  days  of  the
                                 initial use of the standby CEMS.

                            ix.  All RATA  and  CGA shall be performed by
                                 testing  firms/laboratories   who   have
                                 received  approval  from the District by
                                 going through the District's  laboratory
                                 approval program.

                            x.   Immediately prior to obtaining data from
                                 the  source(s)  to  be  monitored,   the
                                 standby CEMS shall be quality assured in
                                 accordance with District Method 100.1


             7.   Alternative Data Acquisition Using Process Curves or
                  Other Means
                  Process curves of SOx emissions or other alternative
                  means of SOx emission data generation shall be used to
                  obtain sulfur oxides emission data, provided the Facility
                  Permit holder has obtained the approval of the Executive
                  Officer prior to using alternate means of SOx emission data
                  generation.  The process curves and the alternate means of
                  SOx emission data generation mentioned in this paragraph
                  shall not be used more than 72 hours per calendar month and
                  shall only be used if no CEMS data or reference method data
                  gathered under Chapter 2, Subdivision B, Paragraph 6 is
                  available.  Process curves may be used on units which have
                  air pollution control devices for the control of sulfur
                  oxides emissions provided the Facility Permit holder submits
                  a complete list of operating conditions that characterize
                  the permitted operation.  The conditions must be specified
                  in the Facility Permit for that equipment.  The process
                  variables specified in the Facility Permit conditions must
                  be monitored by the source.
             8.   Span Range Requirements for SOx Analyzers or Fuel Gas
                  Sulfur Analyzers
                       Full  scale  span  ranges  for the SOx or fuel gas
                       sulfur  analyzers shall be set  on  an  individual
                       basis.  The full scale span range of the analyzers
                       shall be  set so that all the data points gathered
                       by the CEMS  lie within 20-95 percent of the full-
                       scale span range.  During any clock hour, up to 25
                       percent of the  data  falling outside these limits
                       and between 0-99 percent  of  the  full scale span
                       range may be reported as valid data,  but  only up
                       to 2.5 hours during any reporting day. If any data
                       points  fall  above  99 percent of full scale span
                       range, the applicable  procedures for substituting
                       missing  data in the Missing  Data  Procedures  in
                       Chapter 2, Subdivision E of these guidelines shall
                       be used for that hour.

             9.   Calibration Drift Requirements
                  The CEMS design shall allow determination of
                  calibration drift (both negative and positive) at zero level
                  (0 to 20 percent of full scale and high-level (80 to 100
                  percent of full scale) values.  Alternative low-level and
                  high-level span values shall be allowed with the prior
                  written approval of the Executive Officer.
             10.  Relative Accuracy Requirements for Stack Gas Volumetric
                  Flow Measurement Systems
                       The stack  gas  volumetric flow measurement system
                       shall  meet  a relative  accuracy  requirement  of
                       being less than or equal to 10 percent of the mean
                       value of the reference  method  test data in units
                       of DSCFH.  Relative accuracy is calculated  by the
                       equations in Section 8 of 40 CFR Part 60, Appendix
                       B,  Performance Specification 2.   The  volumetric
                       flow   measurement  system  shall  also  meet  the
                       specifications in Attachment B (BIAS TEST) of this
                       protocol.   The  District recommends (but does not
                       require) performing a flow profile study following
                       the procedures in  40  CFR,  Part  60, Appendix A,
                       Test  Method  1,  Section  2.5  to  determine  the
                       acceptability   of   the  potential  flow  monitor
                       location and to determine  the number and location
                       of  flow  sampling  points required  to  obtain  a
                       representative flow value.

                  11.  Quality Assurance for Fuel Flow Meters

                       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 natural gas, fuel oil, or other fuels
                       which the Facility Permit  holder  can show to the
                       satisfaction of the Executive Officer  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.

                  12.  Relative Accuracy Requirements  for  Emission Rate
                       Measurement

                       The   emission  rate  measurement  shall  meet   a
                       relative  accuracy  requirement of being less than
                       or equal to 20 percent  of  the  mean value of the
                       reference  method  test  data in units  of  lb/hr.
                       Relative accuracy is calculated   by the equations
                       in  Section  8  of  40  CFR  Part 60, Appendix  B,
                       Performance Specification 2.   The  emission  rate
                       measurement shall also meet the specifications  in
                       Attachment B (BIAS TEST) of this Appendix A.

                  13.  Certification Requirements for Analyzers
                       The portion of the CEMS which samples, conditions,
                       analyzes, and records the sulfur oxides and oxygen
                       concentrations  in  the stack gas or the sulfur in
                       the fuel gas shall be  certified  according to the
                       specifications  in  40 CFR, Part 60,  Appendix  B,
                       Performance Specifications  2  and 3.  The portion
                       of  the CEMS which samples, conditions,  analyzes,
                       and records  the  sulfur  in the fuel gas shall be
                       certified using the specifications in 40 CFR, Part
                       60, Appendix B, Performance  Specification  2 with
                       the exception that District Method 307-91 shall be
                       used  for reference method to determine the sulfur
                       content  in  the  fuel  gas.  Units using monitors
                       with  more than one span range  must  perform  the
                       calibration  error  test on all span ranges.  This
                       portion   of  the  CEMS  shall   also   meet   the
                       specifications in Attachment B of this Appendix A.

             14.  Provisional Approval
                  The Facility Permit holder of a major source shall
                  submit certification test results and supporting documents
                  to the District for each CEMS by December 31, 1994 for Cycle
                  1 facilities and June 30, 1995 for Cycle 2 facilities.  The
                  Facility Permit holder shall certify that the results show
                  that the CEMS has met all the requirements of the protocol
                  if its submission is after August 31, 1994.  Upon receipt of
                  the test results and the certification that the CEMS is in
                  compliance, the District will issue a Provisional Approval.
                  After the Provisional Approval, all the data measured
                  and recorded by the CEMS will be considered valid quality
                  assured data, (retroactive to January 1, 1995) provided that
                  the Executive Officer does not issue a notice of disapproval
                  of final certification.  Final certification of the CEMS
                  will be granted if the certification test results show that
                  the CEMS has met all the requirements of the protocol.
                  In the case where the test results show that the CEMS
                  does not meet all the requirements of the rule, the
                  Executive Officer will disapprove the final certification.
                  If this occurs, the previously considered valid data from
                  January 1, 1995 will be replaced by data as specified in the
                  "Missing Data" section of the protocol.  This procedure
                  shall be used until the time that new certification test
                  results are submitted, and the CEMS has received final
                  approval by the District.
             15.  Sampling Location Requirements
                  Each affected piece of equipment shall have sampling
                  locations which meet the "Guidelines for Construction of
                  Sampling and Testing Facilities" in the District Source Test
                  Manual.  If an alternate location (not conforming to the
                  criteria of eight duct diameters downstream and two
                  diameters upstream from a flow disturbance) is used, the
                  absence of flow disturbance shall be demonstrated by using
                  the District method in the Source Test Manual, Chapter X,
                  Section 1.4 or 40 CFR, Part 60, Appendix A, Method 1.
                  Section 2.5 and the absence of stratification shall be
                  demonstrated using District method in the Source Test
                  Manual, Chapter X, Section 13.
             16.  Sampling Line Requirement
                  The CEMS sample  line  from  the CEMS probe to the
                  sample  conditioning  system shall  be  heated  to  
                  maintain  the  sample temperature  above  the  dew
                  point of the sample.   This  requirement  does not
                  apply  to  dilution  probe systems where no sample
                  condensation occurs.

              17.  Recertification Requirements

                   The  District  will  reevaluate   the   monitoring
                   systems  at any affected piece of equipment  where
                    changes to  the  basic  process  equipment  or air
                   pollution  control  equipment  occur, to determine
                   the proper full span range of the  monitors.   Any
                   monitor  system  requiring change to its full span
                   range in order to meet the criteria in Chapter 2,.
                   Subdivision B, Paragraph  8  shall  be recertified
                   according to all the specifications in  Chapter 2,
                   Subdivision   B,   Paragraph   10,   Chapter    2,
                   Subdivision  B,  Paragraph   11,  and  Chapter  2,
                   Subdivision   B,   Paragraph   12  as  applicable,
                   including   the  relative  accuracy   tests,   the
                   calibration drift tests, and the calibration error
                   tests.  A new  CEMS  plan  shall  be submitted for
                   each CEMS which is reevaluated.

                   The recertification for any existing CEMS shall be
                   completed within 90 days of the start-up  of newly
                   changed  or  modified equipment monitored by  such
                   CEMS.  The Facility  Permit holder shall calculate
                   and report SOx emission  data for the period prior
                   to  the  CEMS  recertification  by  means  of  the
                   automated  data acquisition  and  handling  system
                   according to the following procedures:
                   a.   For any  CEMS  which is recertified within 90
                        days  of  start-up   of  the  newly  modified
                        equipment, the emission  data recorded by the
                        CEMS  prior to the recertification  would  be
                        considered   valid  and  shall  be  used  for
                        calculating and  reporting  SOx emissions for
                        the equipment it serves.

                   b.   For any CEMS which is not recertified  within
                        90  days  of  start-up  of the newly modified
                        equipment, the 90th percentile  emission data
                        (lb/day)  for the previous 90 unit  operating
                        days  recorded  by  the  CEMS  prior  to  the
                        recertification shall be used for calculating
                        and reporting SOx emissions for the equipment
                        it serves.

                  18.  Quality Assurance Procedures for Analyzers

                       The  quality   assurance   and   quality   control
                       requirements for analyzers, flow monitors, and SO2
                       emission  rate systems are given in  Attachment  C
                       (QUALITY ASSURANCE AND QUALITY CONTROL PROCEDURES)
                       of these guidelines.   The quality assurance plans
                       required by Attachment C  of these protocols shall
                       be  submitted  along with the  CEMS  certification
                       application to the  District  for  the approval of
                       the Executive Officer.  Source test and monitoring
                       equipment  inspection  reports  required   by  the
                       Protocols shall be kept on-site for at least three
                       years.   The  reference  method  tests  are  those
                       methods   specified   in   Chapter   6  (Reference
                       Methods).  Any CEMS which is deemed out-of-control
                       by  Attachment  C shall be corrected, retested  by
                       the appropriate audit  procedure,  and restored to
                       in-control  status  within  24  hours after  being
                       deemed  out-of-control.  If the CEMS  is  not  in-
                       control at the end of the 24-hour period, the CEMS
                       data  shall  be  gathered  using  the  methods  in
                       Chapter  2, Subdivision B, Paragraph 6 and Chapter
                       2, Subdivision  B, Paragraph 7.  All data which is
                       gathered in order  to  comply  with  Attachment  C
                       shall  be  maintained  for three years and be made
                       available to the Executive  Officer  upon request.
                       Any  such  data  which  is  invalidated  shall  be
                       identified  and  reasons  provided  for  any  data
                       invalidation.  The sulfur oxides, oxygen, and fuel
                       gas   sulfur   monitors   shall   also   meet  the
                       specifications in Attachment B (BIAS TEST).

                  19.  Calibration Gas Traceability

                       All  calibration  gases  used during certification
                       tests and quality assurance  and  quality  control
                       activities shall be certified according to 40 CFR,
                       Part   75,   Appendix  H  -  Revised  Traceability
                       Protocol No. 1.


             C.   REPORTING PROCEDURES

                  1.   Interim Reporting Procedures

                       a.   From January  1, 1994 until December 31, 1994
                            (Cycle 1 facilities)  and  July 1, 1994 until
                            June  30,  1995  (Cycle  2  facilities),  the
                            Facility Permit holder shall  be  allowed  to
                            use  an  interim procedure for data reporting
                            and  storage.   The  Facility  Permit  holder
                            shall  submit  as part of the Facility Permit
                            application, the methodology for interim data
                            reporting and storage.   The  Facility Permit
                            application shall be subject to  the approval
                            of  the  Executive  Officer and shall,  at  a
                            minimum, meet the requirements  of Chapter 2,
                            Subdivision C, Paragraph 1, Subparagraphs  b,
                            c and d.

                       b.   All   the   data   required   in  Chapter  2,
                            Subdivision  C, Paragraph 1, Subparagraphs  c
                            and  d  shall  be   made   available  to  the
                            Executive Officer.

                       c.   For  each  affected  piece  of equipment  the
                            following information shall be stored on site
                            in   a   format  approved  by  the  Executive
                            Officer.

                            i.   Calendar  dates covered in the reporting
                                 period.

                            ii.  Each daily  emissions  (lb/day) and each
                                 hourly emissions (lb/hour).

                            iii. Identification of the operating hours 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.   The following information for the entire facility 
                            shall be reported on a monthly basis in a format 
                            approved by  the Executive officer:
                            i.   Calendar dates covered in  the reporting
                                 period.

                            ii.  The sum of the daily emissions  (lb/day)
                                 from each affected SOx RECLAIM sources.

                       e.   All data required by Chapter 2, Subdivision B,
                            Paragraphs 1,2,3,4,5 and Chapter 2, Subdivision 
                            C, Paragraph 1, Subparagraphs c and d shall be 
                            recorded and/or transmitted to the District in 
                            a format approved by the Executive Officer.
                  2.   Final Reporting Procedures

                       a.   On and after January 1, 1995 (Cycle 1 facilities) 
                            and July 1, 1995 (Cycle 2 facilities), the RTU 
                            installed at each location shall be used to 
                            electronically report total daily mass emissions
                            of SOx and daily status codes to the District
                            Central SOx Station.
                       b.   On   and  after  January  1,  1995  (Cycle  1
                            Facilities)   and   July  1,  1995  (Cycle  2
                            Facilities), the Facility Permit holder shall
                            submit  to the Executive  Officer  a  Monthly
                            Emissions  Report  in  the  manner  and  form
                            specified by the Executive Officer within ten
                            calendar  days  of the close of each calendar
                            month.

                       c.   On  and  after  January  1,  1995,  (Cycle  1
                            facilities)  and  July   1,   1995  (Cycle  2
                            facilities), all or part of the  interim data
                            storage  systems  shall  remain as continuous
                            backup systems.

                       d.   An  alternate  backup  data  storage   system
                            shall be implemented, upon request.

             D.   ALTERNATIVE PROCEDURES FOR EMISSION STACK FLOW RATE
                  DETERMINATION
                  1.   Multiple Sources Venting to a Common Stack
                       In the event that more than one source vents  to a
                       common stack, the alternative reference method for
                       determining individual source flow rates shall use
                       the  F-factors  in EPA Method 19 and the following
                       equation:

                                            r
                       ci =[20.9/(20.9-bi)]x(FdijxdijxVij)  (Eq.12)
                                           j=1



                            where:

                            ci   =    The mass emissions of sulfur
                                      dioxide (lb/hr),

                            bi   =    The stack gas concentrations of
                                      oxygen on a dry basis (%),

                            r    =    The number of different types of
                                      fuel,

                            Fdij =    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/106 Btu),

                            dij  =    The metered fuel flow rate for each
                                      type of fuel measured every 15-
                                      minute period,

                            Vij  =    The higher heating value of the
                                      fuel for each type of fuel

                       The  product  (dij  x  Vij)  must  have  units  of
                       millions  of  Btu  per  hour  (106  Btu/hr).   All
                       concentrations  and  stack gas flow rates shall be
                       calculated on a consistent  wet or dry basis.  The
                       measurement of wet concentration  and wet F factor
                       shall  be allowed provided that wet  concentration
                       of NOx is measured.

             Example Calculation:

                  Gaseous Fuel

                  bi = 4.2% O2

                  Fdji = 8710 dscf/106 Btu

                  dji = 50,000 scfh

                  Vji = 1050 Btu/dscf

                  cig = [20.9/(20.9 - 4.2)] x [(8710/106)(50,000)(1050)

                  cig = 570,938 dscfh

                  Liquid Fuel:

                  bi = 4.2% O2

                  Fdji = 9,190 dscf/106 Btu

                  dji = 500 gal/hr.

                  Vji = 136,000 Btu/gal.

                  cil = (20.9/20.9-4.2)(9,190/106)(136,000)(500)=781,150 
                        dscfh

                  Total Stack Flow Rate=cig+cil=570,938+781,150=1,352,088 
                                         dscfh
                                                                                        This method  shall  be used for applicable sources
                       before and after the  interim  period mentioned in
                       Chapter  2,  Subdivision  C,  Paragraph   1.   The
                       orifice  plates  used  in  each affected piece  of
                       equipment vented to a common  stack shall meet the
                       requirements   in   Chapter   2,  Subdivision   D,
                       Paragraph 2.

             2.   Quality Assurance for Orifice Plate Measurements
                  (Applies Only to Multiple Sources Venting to a Common Stack)
                  Each orifice plate used to measure the fuel gas flow
                  rate shall be checked once every 12 months using Reference
                  Methods.  If the orifice plate cannot be checked using
                  Reference Methods, it may be checked using other methods
                  that can show traceability to NIST Standards.  If the
                  orifice plate cannot be checked by Reference Methods or
                  other methods that can show traceability to NIST standards,
                  the orifice plate shall be removed from the gas supply line
                  for an inspection once every 12 months, and  the following
                  inspection procedure shall be followed:
                  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 
                       manufacturer.
                  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 microinches.
                  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 plate fails to meet any of the
                       manufacturer's specifications, it shall be replaced 
                       within two weeks.
             3.   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 natural gas,
             fuel oil, or other fuels which the Facility Permit holder
             can demonstrate to the Executive Officer 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.
        E.   MISSING DATA PROCEDURES
             1.   Procedures for Missing SOx Concentration Data or Fuel
                  Gas Sulfur Content
                  For each equipment, whenever a valid hour of SOx
                  pollution concentration data has not been obtained or
                  recorded, the Facility Permit holder shall provide
                  substitute data using the procedures in 40 CFR Part 75
                  Subpart D if the relative accuracy of the pollutant
                  analyzer, flow measurement system, and emission 
                  measurement is less than 10%, or use the procedure below.
                  a.   The Facility Permit holder shall calculate on a daily
                       basis the percent data availability from the SOx 
                       pollutant concentration monitoring analyzer or the 
                       fuel gas sulfur content monitoring analyzer according 
                       to the following procedures.
                  i.   Calculate on a daily basis a rolling percentage of the
                       operating hours of each equipment that each 
                       concentration monitoring system was available for the 
                       previous 90 days.
                  ii.  Record on a daily basis the percent annual
                       concentration monitor availability using the following
                       equation:

                                 W  =  Y/Z x 100                  (Eq.13)

                                 where:

                                 W    =    the   percent  annual  monitor
                                      availability

                                 Y    =    the total  operating hours for
                                           which  the  monitor   provided
                                           quality-assured   data  during
                                           the previous 365 days


                                 Z    =    the total operating  hours  of
                                           the    affected    piece    of
                                           equipment  during the previous
                                           365 days.

                  Example Calculation:

                                      Y = 1,680 hrs

                                      Z = 2,160 hrs

                                      W = Y/Z x 100

                                      W = (1,680/2,160) x 100

                                      W = 78%

                       b.  Whenever data from the pollutant concentration 
                           monitor 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 
                           according to the following procedures.
                           i.   For a missing data period less than or equal 
                                to 24 hours, substitute data shall be 
                                calculated using the 1N Procedure in 
                                Attachment A.

                            ii.  For a missing data period  greater  than
                                 24   hours,  substitute  data  shall  be
                                 calculated   using  the  maximum  hourly
                                 concentration     recorded     by    the
                                 concentration  monitor  for the previous
                                 30 days.

                      c.   Whenever data from the concentration monitor 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 
                           according to the following procedures.
                           i.   For a missing data period of less than or 
                           equal to 3 hours, substitute data shall be 
                           calculated using the average of the recorded 
                           concentration for the hour immediately
                           before the missing data period and the hour 
                           immediately after the missing data period.
                           ii.  For a missing data period of more than 3 
                           hours but less than or equal to 24 hours, 
                           substitute data shall be calculated using the 
                           maximum hourly concentration recorded by the 
                           concentration monitor for the previous 30 days.
                           iii. For a missing data period of greater than 24 
                           hours, substitute data shall be calculated using 
                           the maximum hourly concentration recorded by the 
                           concentration monitor for the previous 365 days.
                           iv.  Whenever data from the concentration monitor 
                           have been available for less than 90 percent of 
                           the total operating hours of the affected piece of 
                           equipment during the previous 365 days, substitute 
                           data shall be calculated using the highest hourly 
                           concentration recorded during the service of the 
                           monitoring system.
                      d.   For missing data periods where there is no prior 
                           CEMS data available:
             1.   for less than or equal to 24 hours, the mass emissions
                  shall be calculated using totalized fuel usage and the
                  starting emission factor specified in Table 2 of Rule 2002
                  or any alternative emission factor used in the determination
                  of initial allocations; or
             2.   For less than or equal to 24 hours and where fuel usage
                  is not available, the mass emissions shall be calculated
                  using the equipment maximum rated capacity, 100 percent
                  equipment uptime, and the starting emission factor specified
                  in Table 2 of Rule 2002.
        2.   Procedures for Missing Stack Flow Data
             a.   For each affected piece of equipment, the Facility
                  Permit holder shall provide substitute data as described
                  below whenever a valid hour of flow data has not been
                  obtained and recorded.
             b.   The Facility Permit holder shall calculate on a daily
                  basis the percent data availability from the flow monitoring
                  system according to the following procedures.
                  i.   Calculate  on  a daily basis  a  rolling
                       percentage  of the  operating  hours  of
                       each equipment that each flow monitoring
                       system was available  for  the  previous
                       365 days.

                  ii.  Record  on  a  daily  basis  the percent
                       annual  flow monitor availability  using
                       the following equation:

                       W  =  Y/Z x 100                 (Eq. 14)

                  Example Calculation:
                                      Y = 1,680 hrs
                                      Z = 2,160 hrs
                                      W = Y/Z x 100
                                      W = (1,680/2,160) x 100
                                      W = 78%

                            where:

                            W    =    the percent annual flow monitor
                                 availability

                            Y    =    the total operating hours for which
                                      the monitor provided quality-
                                      assured data during the previous
                                      365 days

                            Z    =    the total operating hours of the
                                      affected piece of equipment during
                                      the previous 365 days.

             c.   Whenever data from the flow monitor have been available
                  and recorded for 95 percent or more of the total operating
                  hours of the equipment during the previous 365 days, the
                  Facility Permit holder shall calculate substitute data for
                  each hour according to the following procedures.
                  i.   For a missing data period less than or equal to 24
                       hours, substitute data shall be calculated using the 1N
                       Procedure in Attachment-A.

                  ii.  For a missing  data  period greater than
                       24  hours,  substitute  data   shall  be
                       calculated using the maximum hourly flow
                       recorded  by  the  flow monitor for  the
                       previous 30 days.
             d.   Whenever data from the flow monitor have been available
                  for 90-percent or more but less than 95-percent of the total
                  operating hours of the equipment during the previous 365
                  days, the Facility Permit holder shall calculate substitute
                  data for each hour according to the following procedures.
                  i.   For a missing data period of less than or equal to 3
                       hours, substitute data shall be calculated using the 
                       average of the recorded flow rate for the hour 
                       immediately before the missing data period and the hour 
                       immediately after the missing data period.
                  ii.  For a missing data period of more than 3 hours but less
                       than or equal to 24 hours, substitute data shall be
                       calculated using the maximum hourly flow rate recorded 
                       by the flow monitor for the previous 30 days.
                 iii.  For a missing data period of greater than 24 hours,
                       substitute data shall be calculated using the maximum 
                       hourly flow rate recorded by the flow monitor for the 
                       previous 365 days.
                  iv.  Whenever data from the flow monitor have been available
                       for less than 90 percent of the total operating hours 
                       of the equipment during the previous 365 days, 
                       substitute data shall be calculated using the highest 
                       hourly flow rate recorded during the service of the 
                       monitoring system.

  F.   TIME-SHARING

       1.   Time-sharing is where an analyzer and possibly the
            associated sample conditioning  system  is used on
            more than one source.  Timesharing is allowed  for
            SOx RECLAIM sources provided the CEMS can meet the
            following  requirements  in  addition to the other
            requirements in this document for each source that
            is timeshared.

        2.   All sources shall have mutually compatible span
             range(s).  The span range(s) must be able to meet the
             criteria in Chpater 2, Subdivision B. Paragraph 8.
        3.   Each source must have a data reading period greater
             than or equal to 3 times the longest response time of the
             system.  For shared systems the response time is measured at
             the input or probe at each source.  A demonstration of
             response time for each source must be made during
             certification testing.  Data is not to be collected
             following a switch of sampled sources until an amount of
             time equal to the response time has passed.
        4.   The CEMS must be able to perform  and  record zero
             and span calibrations at each source.









                                      TABLE 2-A

                       MEASURED VARIABLES FOR MAJOR SOx SOURCES

                   EQUIPMENT TYPE : FLUID CATALYTIC CRACKING UNITS

                      EQUIPMENT       |       MEASURED VARIABLES
             FCCUs                    |  1.Stack SOx concentration and
                                           exhaust flow rate;
                                         2.Status code;
                                         3.Feed rate.
             FCCUs with feed
              hydrodesulfurization    |  All variables
              identified for FCCUs.
             FCCUs with SOx reducing
              catalyst                |  All variables identified
              for FCCUs; AND
                                      |  4. Type and amount of catalyst
                                            used.
             FCCUs with wet flue gas
              desulfurization         |  All variables
              identified for FCCUs; AND

             (e.g., slurry of
              Ca(OH)2/CaCO3           |  4.Scrubber solution injection
              rate.
             or NaOH/Na2CO3)          |

             FCCUs with dry flue
              gas desulfurization     |  All variables
              identified for FCCUs; AND
             (e.g., dried slurry of
              Ca(OH)2/CaCO3           |  4.Scrubber solution
              injection rate.
             or NaOH/Na2CO3)          |





                                TABLE 2-A (CONTINUED)

                       MEASURED VARIABLES FOR MAJOR SOx SOURCES

                           EQUIPMENT TYPE : TAIL GAS UNITS

  EQUIPMENT                              |            MEASURED VARIABLES

  Tail gas units                         |  1.Stack SOx concentration and
   exhaust flow rate;
                                         |  2.Status code;
                                         |  3.Production rate;

  Tail gas units with amine treatment    |  All variables identified
   for tail gas units; AND

 (e.g.MEA, DEA, SCOT)                    |  4.Amine solution injection
             rate

  Tail gas units with caustic wash       |  All variables identified
   for tail gas units; AND
 (e.g., MEROX w NaOH, catalyst)          |  4.Caustic solution injection
             rate

 Tail gas units with metal based wash    |  All variables
  identified for tail gas units; AND

 (e.g., CHEMSWEET with                   |  4.Metal based solution
   injection rate ZnO and Zn Acetate,
   IRON SPONGE with wood chips w iron oxide)

 Tail gas units with carbonate wash      |  All variables identified
  for tail gas units; AND
 (e.g., CATACARB with                    |  4.Carbonate solution
  injection rate K2CO3, catalyst, and inhibitor)

 Tail gas units with REDOX processes     |  All variables identified
  for tail gas units; AND
  (e.g., STRETFORD with                  |  4. REDOX solution injection
             rate

 Vanadium based solution, WELLMAN-LORD
  SULFEROX with iron w/chelating agent)
  Tail gas units with other catalytic    |  All variables identified
  for tail gas units
  conversion processes to H2S
  (e.g., Hydrotreating)




                                TABLE 2-A (CONTINUED)

                       MEASURED VARIABLES FOR MAJOR SOx SOURCES

                   EQUIPMENT TYPE : SULFURIC ACID PRODUCTION PLANTS

   EQUIPMENT                           |        MEASURED VARIABLES
   Sulfuric acid production plants     |  1.Stack SOx concentration
    and exhaust flow rate;
    with dual absorption processes     |  2. Status code;
                                       |  3. Sulfuric acid production
    rate;
                                       |  4. Strength of acid produced;
                                       |  5. Inlet SO2, O2
    concentrations to 1st and 2nd
                                       |   stage converters;
                                       |  6. Inlet SO3 to absorption
    tower;
                                       |  7. Conversion efficiency of
   1st and 2nd stage
                                       |   converters;
                                       |  8. Conversion efficiency of
  absorption tower;
                                       |  9. Efficiency of acid mist
  control devices;
                                       |  10.Type and amount of fuel            
                                             usage for furnace.

 Sulfuric acid production plants       |  1.Stack SOx concentration
 and exhaust flow rate;
 with sodium sulfite/bisulfite/ammonia |  2.Status code;
 scrubbing processes                   |  3. Sulfuric acid production
 rate;
                                       |  4. Strength of acid produced
                                       |  5. Sodium
sulfite/bisulfite/ammonia injection rate;
                                       |  6. Scrubber solution pH
                                       |  7. Conversion efficiency of
absorption tower
                                       |  8. Efficiency of acid mist
control devices;
                                       |  9. Type and amount of fuel
usage for furnace.




                                TABLE 2-A (CONTINUED)

                       MEASURED VARIABLES FOR MAJOR SOx SOURCES

              EQUIPMENT TYPE :  EQUIPMENT BURNING REFINERY, LANDFILL OR
                                DIGESTER GASEOUS FUELS

  EQUIPMENT                               |        MEASURED VARIABLES

 Combustion equipment                     |  1.  Stack SOx, O2
  concentrations, and fuel flow rate; OR
                                          |  Fuel sulfur content and
 fuel flow rate;
                                          |  2.Status code;
 Combustion equipment                     |  All variables identified for
 combustion equipment; AND
 with wet scrubber                        |  3.Scrubber solution injection
             rate.
 (e.g., Lime CaO, Limestone CaCO3,        |
    Sodium Sulfite Na2SO3,                |
    Double alkali Na2SO3/CaO/CaCO3,       |
    Magnesium oxide Mg(OH)2)              |
 Combustion equipment with spray dryer       All variables
  identified for combustion equipment; AND
  or dry scrubber                         |  3.Scrubber solution injection
             rate;
 (e.g., absorption with Na2CO3
      or slaked lime solution)            |

Combustion equipment with carbon          |  All variables identified
             for combustion equipment.
             adsorption                   |




                                      TABLE 2-B

                     REPORTED VARIABLES FOR ALL MAJOR SOx SOURCES

    EQUIPMENT                                         REPORTED VARIABLES

 Fluid Catalytic Cracking Units           |  1.Total Daily SOx mass
  emissions from each source;
 Tail Gas Units                           |  2.Daily status codes
 Sulfuric Acid Production                 |
 Equipment that burns refinery, landfill  |
  or sewage digester gaseous fuel except  |
  gas flares.  Any existing equipment using
  SOx CEMS or equivalent monitoring
  device, or that is required to install
  such monitoring device under District
  rules to be implemented as of [date of
  adoption].  Any SOx source or process
  unit elected by the Facility Permit
  holder or required by the Executive
  Officer to be monitored with CEMS or
  equivalent monitoring device.  Any SOx
  source or process unit whose reported
  SOx emissions was equal to or greater
  greater than 10 tpy for any calendar
  year from 1987 to 1991, inclusive,
  excluding any SOx source or process
  which has reduced SOx emissions
  below 10 tons per year prior to
  January 1, 1994.