SEPA
United States      Industrial Environmental Research  EPA-600 7-80-087
Environmental Protection  Laboratory          April 1980
Agency         Research Triangle Park NC 2771 1
Environmental
Assessment of an  Oil-fired
Controlled Utility  Boiler

Interagency
Energy/Environment
R&D Program  Report
                               -


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                  RESEARCH REPORTING SERIES


Research reports of the Office of Research and Development, U.S. Environmental
Protection Agency, have been grouped into nine series. These nine broad cate-
gories were established to facilitate further development and application of en-
vironmental technology. Elimination  of traditional  grouping was consciously
planned to foster technology transfer and a maximum interface  in related fields.
The nine series are:

    1. Environmental Health Effects Research

    2. Environmental Protection Technology

    3. Ecological Research

    4. Environmental Monitoring

    5. Socioeconomic Environmental Studies

    6. Scientific and Technical Assessment Reports (STAR)

    7. Interagency Energy-Environment Research and Development

    8. "Special" Reports

    9. Miscellaneous Reports

This report has been assigned to the INTERAGENCY ENERGY-ENVIRONMENT
RESEARCH AND  DEVELOPMENT series. Reports in this series result from the
effort funded  under the 17-agency Federal  Energy/Environment Research  and
Development Program. These studies relate to EPA's mission to protect the public
health and welfare from adverse effects of pollutants associated  with energy sys-
tems. The goal of the Program is to assure the rapid development of domestic
energy supplies in an environmentally-compatible manner by providing the nec-
essary environmental data and control technology. Investigations include analy-
ses of the transport of energy-related pollutants and their health and ecological
effects; assessments  of, and development of, control technologies for energy
systems; and integrated assessments of a wide range of energy-related environ-
mental issues.
                       EPA REVIEW NOTICE
This report has been reviewed by the participating Federal Agencies, and approved
for  publication. Approval does not signify that the contents  necessarily reflect
the  views and policies of the Government, nor does mention of trade names or
commercial products constitute endorsement or recommendation for use.

This document is available to the public through the National Technical Informa-
tion Service, Springfield, Virginia 22161.

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                                     EPA-600/7-80-087

                                               April 1980
Environmental Assessment of an
           Oil-fired Controlled
                Utility Boiler
                          by
                 C. Leavitt, K, Arledge, C. Shih,
                R. Orsini, A. Saur, W. Hamersma,
              R. Maddalone, R. Beimer, G. Richard,
                  S. Unges, and M. Yamada

                       TRW, Inc.
                     One Space Park
                Redondo Beach, California 90278
                  Contract No. 68-02-2613
                       Task No. 8
                Program Element No. EHE624A
              EPA Project Officer: Michael C. Osborne

            Industrial Environmental Research Laboratory
          Office of Environmental Engineering and Technology
                Research Triangle Park, NC 27711
                      Prepared for

           U.S. ENVIRONMENTAL PROTECTION AGENCY
               Office of Research and Development
                   Washington, DC 20460

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                                 ABSTRACT

     A comprehensive emissions assessment was performed on the Haynes No.  5
boiler during oil firing.  Level  1  and Level  2 procedures were utilized to
characterize pollutant emissions.  Results of the comprehensive assessment,
in conjunction with assumed typical and worst case meteorological  conditions,
were utilized to estimate the environmental impact of emissions from this
type of unit.  Principal  conclusions indicated are as follows:  1) The risk
of violating National Ambient Air Quality Standards (NAAQS) due to criteria
pollutant emissions is low.  2) Little adverse health effect is anticipated
as a result of SO^, S0.~, and particulate emissions projected from wide-
spread use of oil-fired units of the type tested.  3) The impact of trace
element burdens in drinking water,  plant tissue, soil and the atmosphere is
negligible.  4) The risk of plant damage due  to criteria pollutant emissions
is remote.  5) The likelihood of plant damage due to trace element emissions
is remote.
                                    n

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                                                 Environmental
                                                Protection Agency
                                                   Region 9
                                CONTENTS        JUN 1 1  1980
Abstract	    ii
Metric Conversion Factors and Prefixes  .  	    iv

     1.   Introduction  	     1
     2.   Summary and Conclusions	     3
     3.   Test Setting	     7
     4.   Assessment of an Oil-fired  Utility Boiler	    16
     5.  Environmental  Impact Assessment  	    33

Appendices
     A.   Simplified Air Quality  Model	    58
     B.   Organic Analysis Methods  	    64
                                    lii

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                                 TABLES
Number                                                                Page
 2-1     Summary of Pollutant Emissions From an Oil-fired Utility
         Boiler	     4
 3-1     Boiler Number 5 Design Data	    11
 3-2     Typical Fuel Oil Analysis	    13
 4-1     Summary of Test Conditions 	    17
 4-2     Summary of Ultimate Fuel Analysis	    18
 4-3     Concentration of Major Trace Elements in Oil 	    19
 4-4     Existing and Proposed Federal Emission Standards for
         Oil-fired Utilities	    21
 4-5     Comparison of Average Criteria Pollutant Emissions with
         EPA AP-42 Emission Factors for Oil-fired Utility Boilers .    21
 4-6     Summary of Criteria Pollutant Emissions	    22
 4-7     SOpj S03, and SO," Emissions	    25
 4-8     Summary of Sulfate Emissions 	    25
 4-9     Emission Concentrations of Trace Elements. . .  	    27
 4-10    Emission Factors for Trace Elements	    29
 4-11    POM Emissions from Oil Firing	    31
 5-1     Emission Rates from a Controlled 353 MW (Gross) Oil-fired
         Utility Boiler  	    34
 5-2     Annual Emissions 	    35
 5-3     Comparison of Federal Air Quality Standards With Air
         Quality Predicted to Result From Oil Combustion in a 353
         MW (Gross) Utility Boiler	    37
 5-4     Health Impacts of Sulfate Aerosol	    41
 5-5     Expected Trace Element Concentrations in Vicinity of a
         353 MW (Gross) Oil-fired Utility Boiler	    43
 5-6     Annual Deposition of Trace Elements in Vicinity of
         Controlled Oil-fired Power Plants	    45
 5-7     Long Term Effect of Controlled Oil-fired Utility Boiler
         Emissions on Soil Concentrations of Trace Elements ....    45
 5-8     Long Term Effect of Controlled Oil-fired Boiler Emissions
         on Concentrations of Elements in Plants	    46
 5-9     Trace Element Concentration in Runoff Water in Vicinity
         of Controlled Oil-fired Utility Boiler 	    48
                                    iv

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                            TABLES (Continued)
Number                                                                Page
 5-10    Projected Ozone Concentrations Which Will Produce, for
         Short Term Exposures, 20 Percent Injury to Economically
         Important Vegetation Grown Under Sensitive Conditions. .  .     50
 5-11    Sensitivity of Common Plants to SO^ Injury	     53
 A-l     Stack Parameters and Plume Rise	     61
 A-2     Predicted Maximum Ambient Concentrations of Criteria
         Pollutants	     62
 B-l     Sample Code for Organic Samples Analyzed 	     67
 B-2     Results of TCO Analysis of Unconcentrated and Concentrated
         Samples	     69
 B-3     Results of Field GC Analysis	     70
 B-4     Gravimetry of Sample Concentrates	     71
 B-5     Interpretation of Infrared Spectra of Sample Concentrates.     73
 B-6     Summary of GC/MS Samples and Analyses From the Oil-fired
         Site	     76
 B-7     GC/MS Analysis of 141-XMB-SE-KD (Blank) Combined Extracts.     76
 B-8     GC/MS Analysis of 142 SASS Composite	     77
 B-9     GC/MS Analysis of 143 SASS Composite	     78

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                                 FIGURES
Number                                                                Page
 3-1     Plot Plan Haynes Power Plant	     8
 3-2     Schematic of the Oil Boiler	     9
 3-3     System Schematic	    12
 5-1     Health Effects from Sulfate Levels Resulting From Oil
         Combustion in Utility Boilers	    40
 5-2     Increase in Mortality Rates in Vicinity of Oil-fired
         Utility Boilers as a Result of SOo and Total Particulate
         Emissions	    42
 5-3     N02 Threshold Concentrations for Various Degrees of Plant
         Injury	    51
 5-4     S02 Dose-Injury Curves for Sensitive Plant Species ....    53
 B-l     Flow Chart of Sample Handling and Analysis Procedures.  .  .    66
                                    vi

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                   METRIC CONVERSION FACTORS AND PREFIXES
                             CONVERSION FACTORS
To convert from
Degrees Celsius (°C)
Joule (0)
Kilogram (kg)
Kilojoule/kilogram (kJ/kg)
Megagram (Mg)
Megawatt (MW)
Moter (m)
Meter3 (rn3)
Moter3 (m3)
Meter3 (m3)
To
Degrees Fahrenheit (°F)
Btu
Pound-mass (avoirdupois)
Btu/lbm
Ton (2000 lbm)
Horsepower (HP)
Foot (ft)
Barrel (bbl)
Foot3 (ft3)
Gallon (gal)
Multiply by
t(°F) = 1.8 t(°C) + 32
9.478 x 10"4
2.205
4.299 x 10"1
1.102
1.341 x 103
3.281
6.290
3.531 x 101
2.642 x 102
Nanogram/joule (ng/J)
Picogram/joule (pg/J)
Ib /million Btu
Ib /million Btu
2.326 x 10
2.326 x 10
-3
-6
                                  PREFIXES
                               Multiplication
Prefix
Peta

Tera
Giga
Mega
Kilo
Milli
Micro
Nano
Pico
Symbol
P

T
G
M
k
m
V
n
P
Factor
10

1
1
1
1
1
1
1
1

0
0
0
0
0
0
0
0
15
1?
J £
9
6
3
-3
-6
-9
-12
1

1
1
1
1
1
1
1
1
Pm =

Tm =
Gm =
Mm =
km -
mm =
ym =
nm =
pm =
Examp_l_
1

1
1
1
1
1
1
1
1
x

x
X
X
X
X
X
X
X
10

10
10
10
10
10
10
10
10
e
meters
12
meters
g
meters
meters
3
meters
rneter
meter
-9
meter •
-12
meter
                                   VI1

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                                 SECTION 1
                               INTRODUCTION

     Conventional methods for conversion of fuels into usable forms of
energy historically have impacted all segments of the environment.  Most
conventional combustion processes emit sulfur oxides, nitrogen oxides,
carbon oxides, particulate matter and other potentially harmful pollutants
to the air.  Conventional fuel combustion processes are playing an in-
creasing role in the movement toward national energy independence.  As a
result, the potential for adverse environmental impact is also increasing.
In recognition of these facts, IERL-RTP established the Conventional
Combustion Environmental Assessment program (CCEA) to conduct comprehensive
assessments of the effects of combustion pollutants on human health,
ecology, and the general environment.  The assessments will result in re-
commendations for control technology and standards development to control
adverse effects within acceptable limits.
     This report details results of a comprehensive emissions assessment
performed on the Haynes No. 5 utility boiler in Long Beach, California.
The No. 5 unit is a once-through, supercritical boiler with a net electric
generating capacity of 346 MW.  Although either oil or gas may be burned
in this unit, tests described herein were performed exclusively during oil
firing.  The unit has a horizontally-opposed wall fired furnace and is
equipped with off-stoichiometric firing and flue gas recirculation for NOY
                                                                         /\
control.  No particulate or SO  controls are utilized.
                              A
     Based on 1978 data, non-tangential  units comprise 59% of all generating
capacity for residual oil-fired utility boilers.  The average size for
non-tangential units is 100 MW which is a factor of three smaller than the
tested unit.  Only 18% of all non-tangential oil-fired generating capacity
is associated with NO  controls although 54% of the capacity provided by
                     A
controlled horizontally-opposed firing is associated with some form of off-
stoichiometric firing in conjunction with flue gas recirculation.  Oil-fired
utility boilers typically do not utilize particulate or SO  controls.  Since
                                                          /\

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the Haynes No. 5 unit is somewhat larger than the average non-tangential

utility boiler, it may be considered typical  of large horizontally-opposed
units with N0¥ controls.
             A

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                                SECTION 2
                         SUMMARY AND CONCLUSIONS

     A comprehensive emissions assessment was performed on the number 5
boiler at Haynes Power Plant in Long Beach, California.  The plant is owned
and operated by the Department of Water and Power of the City of Los Angeles.
The number 5 boiler is a Babcock and Wilcox supercritical Universal-Pressure
boiler with a net electrical generating capacity of 346 MW.  Either low
sulfur oil or natural gas may be fired in the horizontally-opposed wall
fired furnace of the number 5 unit.  MO  emissions are controlled with off-
                                       A
stoichiometric firing and flue gas recirculation.
     Emissions testing was performed during oil-fired operation.  Level 1
and Level 2 (1) analyses were performed on the fuel oil and the flue gas.
Level 1 analyses were performed to determine NO  and hydrocarbon concentra-
                                               A           w  *
tions in the flue gas.  Concentrations of CO, S02, S03, SO.', Cl", F", and
total particulates in the flue gas were determined by Level 2 analyses.
Trace element concentrations in the flue gas were estimated from Level 1
analysis of the fuel oil assuming all trace elements were emitted from the
stack.  No significant liquid or solid waste streams are produced by the
boiler unit.
     Results of the emissions assessment are presented in Table 2-1.  Measured
emissions of the criteria pollutants and SO^ correspond well with published
AP-42 (2) emission data from oil-fired utility boilers although measured
NO  and total organic emissions were somewhat lower.  Reduced NOV emissions
  A                                                             X
are the result of NO  control systems on the number 5 unit.
                    A
     Of the 39 trace elements studied during this effort, only the estimated
flue gas concentrations of Cr and Ni were found to exceed their respective
Discharge Multimedia Environmental Goal (DMEG) values.  Hence, emission
factors for these elements have been included in the emissions summary table.
     Speciation of organic compounds present in the flue gas indicated the
presence of aliphatic hydrocarbons, benzaldehyde, trimethyl cyclohexane-one,

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             TABLE 2-1.  SUMMARY OF POLLUTANT EMISSIONS
                         FROM AN OIL-FIRED UTILITY BOILER
         Pollutant                            Emission Factor, ng/J


    NO * (as N09 near full load)                      116 ± 2.12ftt
      "        £

    C0f                                               6.6 ± 3.1m

    S02*                                               98 ± 7.0ttt

    S03**                                               1.14

    S04=**                                              1.27

    Total Organicsft                                 0.42-0.58

    Total Parti oil ates**                              7.5 ± 1.2ttf
      _**
    Cl                                                  1.34
     _**
    F                                                   0.061
      ***
    Cr                                               .   0.002
      ***
    Ni                                                  0.2
    NO  was determined by continuous chemiluminescent analysis (Level  1).
  j.   x
    CO was determined by continuous non-dispersive infrared analysis
    (Level 2).
    SOg v/as determined by continuous pulsed fluorescence analysis and by
    the CCS (Level 2).
    SO,, SO/, Cl" and F" were determined by analysis of the CCS (Level  2).
 tt
    C-|- C-J6 fractions were determined by gas chromatograph while the >C-jg
    fraction was determined gravimetrically (Level 1).
    Total particulates were determined by a modified Method 5 procedure
    (Level 2).
***
    Trace element emission factors were estimated from the SSMS fuel
    analysis under the assumption that all trace elements in fuel would
    be emitted from the stack.  Only the estimated flue gas concentrations
    of Cr and Ni were found to exceed their respective DMEG values.
    The indicated uncertainty represents one standard deviation.

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t^ substituted acetophenone,  methyl  esters of benzole acid and substituted
benzoic acid, diethylphthalate, and  ethylbenzaldehyde at concentrations
                 3           3
between 0.02 ug/m  and 2 yg/m .  POM emissions consisted primarily of

naphthalene.  With the exception of  the possible presence of benzo(a)-pyrene
(benzopyrenes were detected but benzo(a)pyrene was not specifically identi-
fied), comparison of measured concentrations of organics with their

respective DMEG values indicates that all POM compounds were present at
levels too low to be of environmental concern.

     An environmental impact assessment was performed based upon emission
rates measured at the Haynes No. 5 boiler and assumed typical and worst case

type meteorological parameters.  Principal conclusions indicated by this
assessment are as follows:

     •   The environmental acceptability of emissions from oil-fired
         boilers is largely dependent on site-specific factors such
         as background pollution levels and meteorology.  However,
         the risk of violating NAAQS due to criteria pollutant emis-
         sions from an oil-fired boiler  (353 MW gross output scale)
         like Haynes No. 5 appears low.

     •   Based on the Lundy-Grahn Model for health effects associated
         with suspended sulfate levels, limited adverse health
         effects would result from these emissions.  Similar results
         were obtained with this model considering the effects of
         S02 and total particulate emissions on people older than 40
         years of age.

     t   The impact of trace element burdens in drinking water, plant
         tissue, soil and the atmosphere as a result of measured
         emissions from this oil-fired utility boiler is generally
         orders of magnitude less than allowable exposure levels.

     t   The risk of plant damage due to criteria pollutant emissions
         from this oil-fired boiler appears to be remote.  However,
         the effect of secondary pollutants formed by reactions
         between NOX and hydrocarbons, and the synergistic effects of
         $02 in the presence of ozone are uncertain.

     •   The likelihood of damage occurring in plants due to trace
         elements from oil firing at Haynes appears remote.

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                   REFERENCES FOR SECTION  2
Hamersma, J.W., D.G.  Ackennan,  M.M.  Yamada,  C.A.  Zee,  C.Y.  Ung,  K.T.
McGregor, J.F. Clausen, M.L.  Kraft,  J.S.  Shapiro, and  E.L.  Moon.
Emissions Assessment of Conventional  Stationary Combustion  Systems,
Methods and Procedures Manual for Sampling and Analysis.  Report
prepared by TRW Systems Group for the U.S. Environmental  Protection
Agency.  EPA-600/7-79-029a.   January 1979.
Compilation of Air Pollution Emission Factors, AP-42,  Part A.
Edition.  U.S. Environmental Protection Agency.  August  1977.
Third

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                                SECTION 3
                              TEST SETTING

PLANT DESCRIPTION
     The oil-fired utility boiler tested was Boiler Number 5 at Haynes
Power Plant, Long Beach, California.  The boiler is owned and operated  by
the Department of Water & Power of the City of Los Angeles.  Boiler Number
5 is one of six boiler units at the facility.  It burns either natural  gas
or low sulfur oil, and utilizes off-stoichiometric firing and flue gas
recirculation to control NO  emissions.
                           7\
     The Haynes Power Plant is located in the urban Los Angeles Basin
approximately 32 kilometers south of downtown Los Angeles.  Figure 3-1
shows a general plot plan of the entire facility, and Figure 3-2 shows  the
general material flow diagram for the unit tested.
     As shown in Figure 3-1 the facility has six boiler units.  This number
is made up of three identical pairs of boilers, that is units 1 and 2 are
identical, units 3 and 4 are identical, and units 5 and 6 are identical.
     Fuel for the facility is supplied by ARCO, Coastal States Marketing,
and Asiatic Petroleum.  It is usually transported to the facility by pipe-
line.  There is approximately 1,000,000 barrels of oil  storage capacity at
the facility.
     Water for boiler feed water makeup, fire fighting, and general usage
is supplied by the City of Long Beach Water System.  Waste water from general
wash-down, and contaminated condensate is treated on site in settling ponds
and ultimately discharged into the San Gabriel River.  Metal cleaning waste
solutions are removed via vacuum trucks and hauled to designated waste
disposal areas.
Boiler
     Boiler Number 5 was built to the Department of Water and Power's
specifications by Babcock and Wilcox.  It is a double reheat, supercritical

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UNIT
  6
GT 6
       OCUJ
 GAS TURBINE
               GT 5
UNIT
4
UNIT
3
I   GT3  I
UNIT
2
UNIT
1
GT2
GT1
                                                                                                  ADMIN
                                                                                                   BLDG
                                                                                                   PARKING
                             Figure 3-1.  Plot Plant Haynes Power Plant

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                                     AIR
                                    HEATER
sx\\\\v
\\N  UN IT NO. 5
                  AIR
                 HEATER
            RECIRCULATION
                     FAN
 FEEDWATER
 HEATERS
    T
RECIRCULATION
FAN
 CONDENSATE
 FROM
 L.P. TURBINE
                                      FORCED
                                      DRAFT
                                      FAN
                                                         FORCED
                                                         DRAFT
                                                         FAN
                Figure 3-2.  Schematic of the Oil  Boiler
                                                                   FLUE
                                                                   GAS TO
                                                                   STACK
                                                                   OUTSIDE
                                                                   AIR
                                                                   OUTSIDE
                                                                   AIR
                                                                   STEAM
                                                                   TO
                                                                   H.P. TURBINE

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pressure, horizontally-opposed wall  fired, Universal-Pressure  boiler.   The
boiler can burn either natural gas or oil.  Boiler number 5 was  put into
commercial operation in August 1966.  Table 3-1  contains  the boiler specifi-
cation data.  A schematic diagram of the boiler and ancillary  equipment is
given in Figure 3-2.
     Combustion air is supplied to the unit by two forced draft  fans.
Prior to entering the combustion zone the temperature of  the air is in-
creased to approximately 550 K in the preheater section.   The  air preheaters
recover heat from the flue gas and transfer it to the combustion air via
heat exchangers.
     Fuel is usually brought to the facility via natural  gas and oil  pipe-
lines.  The oil is continuously circulated through the system  to avoid
gumming and waxing due to settling of heavy hydrocarbons.  The oil  is  pumped
about the facility at a rate of 0.024 m /s.
     Combustion air is supplied to the unit by two variable speed fluid
drive, air foil blade fans.  Each fan supplies 10,100 m3  of air  at 300 K
at a pressure of 113 kPa.
     Recirculation of the flue gas to the boiler combustion zone is accom-
plished by two constant speed, damper controlled fans. Each flue gas
                                 3
recirculation fan delivers 5500 m  at 648 K at a pressure rise of 4.16 kPa.
     Figure 3-3 is a simplified schematic of the system showing  the
generalized flow through the system.  Super heated steam  leaves  the boiler,
passes through the high pressure turbine and is then routed back to the
boiler where it passes through the 1st reheater.  From the 1st reheater the
steam is sent to the intermediate pressure turbine and is then routed  back
to the boiler where it passes through the 2nd reheater.  From  the 2nd re-
heater the steam is sent to the low pressure turbine.  From the  low pressure
turbine the steam is sent to a condenser.  From the condenser  the liquid
passes through a system of eleven heaters arranged in series where it is
heated and returned to the boiler.  The heaters are supplied with steam
from various points in the system.
     The boiler powers two generators.  One is driven by  the high and  inter-
mediate pressure turbines, the other by the low pressure  turbines.   The
                                    10

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                 TABLE 3-1.  BOILER NUMBER 5 DESIGN DATA
  Type
  Manufacturer
  Number of Burners
  Burner Arrangement
  Air Preheater
  Combustion Air Temperature
  Combustion Air Volume
  Recirculation Gas
       Volume
       Temperature
  Reheat
  Design Steam Rate
       Super Heat
       First Reheat
       Second Reheat
  Design Generating Capacity
Oil/gas
Babcock & Wilcox
24
Front and Rear Firina
Yes
572 K
6.02 m3/s (300 K)
Yes
3.26 m3/s
647 K
Two Stage

16,200 Kg/s, 25 MPa, 811 K
13,700 Kg/s, 7.3 MPa, 835 K
12,100 Kg/s, 2.6 MPa, 849 K
353 MW (gross)
combined generators have a capacity of 353 MW (i.e.,  maximum gross  output
is 353 MW as opposed to the salable or net output of  346 MW).
     The fuel oil specifications are critical because burning of "clean"
fuel constitutes the only S02 and particulate control mechanism.  A typical
fuel oil analysis is presented in Table 3-2.  Because the boiler can burn
gas, the oil tests were scheduled such that they occurred after the boiler
had been burning only oil for at least a week.
Air Quality Control
     Emissions of sulfur dioxide and particulates are controlled by burning
low sulfur fuel oil, by the furnace design, and by rigorous maintenance and
operational procedures.
     Off-stoichiometric firing and flue gas recirculation are used to
minimize NOV emissions.  Off-stoichiometric firing consists of running each
           A
                                    11

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I



mi

AT
,.'!
:R
-1 1

si



I    ^T
                          CONDENSER
 Figure  3-3.  System Schematic

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                  TABLE 3-2.  TYPICAL FUEL OIL ANALYSIS
          Heating Value                            44,000 KJ/Kg
          Viscosity, SUS at 333 K                  112.9
          Sulfur, % by Weight                      0.18
          Ash, Weight % of Oil                     0.030
          Specific Gravity of 289 K                0.9100
          Water Content, %                         0.21
          Metal (ppn)
               Iron                                9.3
               Vanadium                            3.9
               Nickel                              5.1
               Sodi urn                              30
               Calcium                             0.13
               Magnesium                           5.6
               Copper                              0.40
               Potassium                           1.85
               Lead                                2.3
               Zinc                                0.51
               Aluminum                            1.0
   Data were provided by Haynes personnel.  No information is available
   regarding the number of samples analyzed or standard deviations  of
   analyses.
burner fuel rich (i.e., less than stoichiometric oxygen).   The remainder of
the oxygen necessary for complete combustion is added to the furnace either
through burners to which the fuel feed has been terminated or through
special air injection points called "NO  ports".  Running  the burners fuel
                                       /\
rich stretches out each flame and causes it to burn cooler.  NO  is formed
                                                               A
two ways, by thermal fixation of atmospheric nitrogen and  from the fuel
nitrogen.  Lowering the combustion temperature reduces the rate at which
atmospheric nitrogen is converted to NO .  Also, fuel rich flames are
                                       /\
oxygen deficient.   Reduced availability of oxygen minimizes NO  formation
                                                              J\
from both of the mechanisms outlined above.

                                    13

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     Flue gas recirculation consists of recirculating some part of flue
gas through the burners.  This procedure results in combustion air with a
reduced oxygen concentration which in turn reduces the NO  formation rates.
                                                         A
Liquid Effluents
     No significant liquid streams are produced by the boiler.
Solid Waste
     No significant solid wastes are produced by the boiler.
OIL-FIRED UTILITY TEST
     The only major emission source at the oil-fired utility  site is the
stack.  There are no emission controls other than rigid fuel  specifications,
except for NO.  Control of NOV is by off-stoichiometric firing and flue
             A                X
gas recirculatiori.  Therefore, only two streams were sampled, the fuel  oil
feed and the stack emissions.  No solid or liquid streams were sampled.
     The stack emissions of criteria pollutants are very low.  As a result,
analysis of the particulates and organics was difficult because of small
sample sizes.
     Emissions were characterized using EPA's phased approach to sampling
and analysis.  This approach utilizes two separate levels of sampling and
analytical effort (Level 1 and Level 2).  Level 1 is a sampling and analysis
procedure accurate within a factor of about 3.  This level provides pre-
liminary assessment data and identified problem areas and information gaps
which are then utilized in the formulation of the Level 2 sampling and
analysis effort.  Level 2 provides more accurate detailed information that
confirms and expands the information gathered in Level 1.  The methods and
procedures used are, in some instances, modified for Level 1  sampling and/or
analysis procedures and are documented in the manual, "Combustion Source
Assessment Methods and Procedures Manual for Sampling and Analysis",
September 1977.  The Level 2 methods and procedures included "state-of-the-
art" techniques as adapted to the needs of this site.  Normally all Level
1 samples are analyzed and evaluated before moving to Level 2.  However,
because of program time constraints, the Level 1 and Level 2 samples were
obtained during the same test period.
                                    14

-------
     The Source Assessment Sampling System (SASS)  was used to collect both
gaseous and particulate emission samples at the scrubber inlet and outlet
for Level 1 organic and inorganic analysis.  The train v/as run for 6  to 8
hours until a minimum of 30 cubic meters of gas had been collected.
     Previous sampling and analysis efforts had indicated possible inter-
ference of SASS train materials on certain organic and inorganic analysis
when at the lower detection limits of Level 2 methods.  To avoid this
possibility, all glass sampling trains were used to collect Level  2 samples.
Two Method 5 sampling trains were modified for Level 2 organic and inorganic
sample acquisition.  Both trains sample approximately 10 cubic meters of
flue gas during a 6- to 8-hour run time.
     A controlled condensate train (Goksoyr-Ross)  was used at each location
to obtain samples for S0o> SOg (as FLSO^), particulate sulfate, HC1 and HF.
                                    15

-------
                                SECTION 4
           EMISSION ASSESSMENT OF AN OIL-FIRED UTILITY BOILER

TEST CONDITIONS
     Four tests were performed firing residual fuel oil.  Electrical output
at this site ranged from 218 to 330 gross MW, corresponding to 62 to 94%
of full-load capacity.  These test conditions are tabulated in Table 4-1.
Efficiencies and emission factors for oil firing are computed using the heat
input from oil feed rates.  The accuracy of tabulated steam production rates
has been estimated to be about 1325, based on oil feed rates and gross
electrical output.  Oxygen concentrations presented are the averages
obtained from continuous monitoring at the stack.  Typical furnace oxygen
levels for normal operation are 3 to 4%.  Using fuel oil analyses, this
oxygen range corresponds to an excess air input of approximately 16 to 22%.
Flue gas flow rates were computed from the oxygen concentration at the
stack, fuel analyses, and fuel feed rates (estimated from steam production
rate data) using the following expression:
                4.762 (nc + n$ + .45 n^) + .9405 nH - 3.762 nQ
                              1 - 4.762 (02/100)
where:
nFG
        nPQ  =  9ram moles of dry effluent per gram of fuel
        n.   =  gram moles of element j per gram of fuel
         J
        02   =  volumetric Og concentration in percent

Flue gas flow rates are expressed as dry standard cubic meters per second;
standard temperature and pressure are defined as 293 K and 101.3 kPa,
respectively.
     Ultimate analyses of the fuel oil are presented in Table 4-2, along
with averages and standard deviations.  Analysis results indicate that the
main fuel components and heat contents were essentially constant during the
test period.  Variation in oxygen contents is attributed to the low fuel
oxygen content and the fact that oxygen is determined by difference.

                                    16

-------
TABLE 4-1.  SUMMARY OF TEST CONDITIONS

Test
No.
141
142
143
144
Electrical
Output
(Gross)
MW
330
218
325
310
% of
Maximum
Load
94
62
92
88
Nominal
Fuel Feed
Rate,
kg/hr
69,000
54,900
66,300
61,700
Steam
Production
Rate, ,.
kg/hr x 10°
0.781
0.536
0.860
0.717
Overall
Efficiency
39
32
40
40
Average 02
in Flue Gas
6.35
5.76
5.66
5.98
Excess Air
At Furnace
16-22
16-22
16-22
16-22
Flue Gas
Flow Rate
dscm/s
300
230
280
270

-------
              TABLE 4-2.   SUMMARY OF ULTIMATE  FUEL  ANALYSIS

Component
Carbon
Hydrogen
Ni trogen
Sulfur
Ash
Oxygen
Heating Value (kJ/kg)

141
86.94
12.41
0.37
0.21
0.01
0.06
43,994

142
86.41
12.40
0.16
0.17
0.00
0.86
44,224
Test
143
86.60
12.33
0.17
0.16
0.01
0.73
44,131

144
86.21
12.43
0.87
0.19
0.01
0.98
44,035

Average
86.54
12.39
0.39
0.18
0.01
0.66
44,096

a*
0.31
0.04
0.33
0.02
0.01
0.41
103

  a = one standard deviation.
f Oxygen concentration by difference.
     Additional analyses were performed on a composite oil  sample (tests
141-144) to determine concentrations of trace and minor elements.  The oil
analysis was performed by spark source mass spectrometry (SSMS), except for
mercury, which was performed by elemental sparging.  These  data are presented
in Table 4-3.  Typical ranges of some trace and minor elements in U.S. and
foreign crude oils and in fuel oils are also presented for  comparison.
Analyses of most trace and minor elements for which typical oil values are
available appear to be consistent with the literature values.   However,
several elements, notably Br, Cl, Cu, F, Fe, Ge, K, Pb, Rb, and V are some-
what lower than the cited literature values.  The significance of these
concentration differences is not apparent due to the limited quantity of
published data.  Comparison of SSMS data with typical oil  analyses from the
Haynes plant (Table 3-8) indicates excellent agreement for Cu, Fe, K, Ni,
V, and Zn.  However, Al, Ca, Na, and Mg were indicated to be major components
by SSMS although they are normally present at the ppm level.  Pb was detected
at somewhat lower levels than normal for oil burned at this plant.
                                    18

-------
                        TABLE 4-3.  CONCENTRATION OF MAJOR TRACE ELEMENTS IN OIL
Element
Al
As
B
Ba
Be
Br
Ca
Ce
Cl
Co
Cr
Cs
Cu
F
Fe
Ga
Ge
Hg
K
La
ppm in
Fuel Oil
MC+
<0.01
0.5
0.5
<0.01
<0.01
MC+
<0.01
0.1
0.5
0.09
0.07
0.1
<0.01
2
0.08
<0.01
0.07**
3
0.01
Typical
Concentration,
ppmt
4
0.0006-1.1
0.4
1
0.08
0.1
14
0.006
12
2
0.002-0.02
0.09
3
0.1
0.003-14
0.4
0.2
0.02-30
34
No Data
Reference
2
1
2
2
2
2
2
2
2
2
1
2
2
2
1. 3
2
2
1
2

Element
Li
Mg
Mn
Mo
Ma
Ml
P
Pb
Pr
Rb
Sc
Se
Si
Sr
Th
Ti
U
V
Zn

ppm in
Fuel Oil
0.02
MC+
0.04
0.1
MC+
8
1
0.04
<0.01
<0.01
<0.01
0.02
4
0.09
<0.2
0.3
<0.2
1
0.2

Typical
Concentration,
ppmt
0.06
13
0.001-6
0.9
31
14-68
1
3
No Data
2
0.02
0.03-1
17
0.1
No Data
2
0.7
15-590
1

Reference
2
2
1
2
2
2, 4
2
2

2
2
1
2
2

2
2
2, 4
2


 Composite sample analyzed by SSMS  (Level  1).


 References 1  and 3 provided ranges  for U.S.  and  foreign crude oils.   References  2 and 4 provided either

 average values  or ranges  for residual  oil.


 MC indicates  a  major component for  which  SSMS  did  not  provide a  numerical  value.
*

 Mercury was analyzed by elemental sparging  (Level  1).

-------
FLUE GAS EMISSIONS
Criteria Pollutants
     Federal New Source Performance Standards (NSPS) currently in effect
define allowable emission rates of NOY (as N09), S00 and total particulates
                                     A       £     L.
from fossil fuel fired utility boilers having 25 MW or greater output.
More stringent limitations have been proposed by EPA for NOX, S02 and total
particulate emissions.  Federal NSPS currently address neither CO nor total
hydrocarbon emissions.  Existing NSPS and corresponding proposed emission
standards for oil-fired utility boilers are summarized in Table 4-4.  It
should be noted that this plant is not required to meet NSPS; they are
provided for comparison only.
     A total of 4 tests v/ere performed.  Criteria pollutant emissions data
for these tests are summarized in Table 4-5 and compared with the EPA AP-42
emission factors for uncontrolled sources (5).  In Table 4-6, average
emissions data are presented.  The emissions data are discussed by specific
pollutant in the ensuing subsections.
Nitrogen Oxides—
     NO  emissions were monitored continuously by chemiluminescent instru-
       A
mentation.  The NO  emission factor near full load condition was 116 ng/J,
                  A
which is 62£ lower than the average NO  emission factor of 309 ng/J
                                      A
tabulated in AP-42 (5).  The lower NO  emission factor was due to the use
                                     A
of flue gas recirculation and off-stoichiometric firing for NO  control.
                                                              A
Measured NO  emissions are slightly below the NSPS limit of 130 ng/J for
           A
oil-fired utility boilers.
Carbon Monoxide-
     Average CO emissions were 6.6 ng/J.  This is in reasonable agreement
with the AP-42 emission factor of 14.7 ng/J for oil-fired utility boilers,
considering the normal scatter in reported CO data.
Sulfur Dioxide—
     S02 emissions were monitored continuously by pulsed fluorescent
analyzer for all tests.  Additionally, S02 was determined in conjunction
with the Goksoyr-Ross Controlled Condensation System (CCS) for Test 143.
                                    20

-------
      TABLE 4-4.  EXISTING AND PROPOSED FEDERAL EMISSION STANDARDS
                  FOR OIL-FIRED UTILITIES
 Pollutant
                          NSPS
   Proposed Standard
NOX (as N02)


SOo
Total
Participates
                        130 ng/J
                    (0.30 Ib/MM Btu)

                        344 ng/J
                    (0.80 Ib/MM Btu)
                         43 ng/J
                    (0.10 Ib/MM Btu)
130 ng/J (0.30 Ib/MM Btu)
520 ng/J (1.20 Ib/MM Btu)
max. with 85% reduction to
85 ng/J (0.20 Ib/MM Btu)

13 ng/J (0.03 Ib/MM Btu)
   TABLE 4-5.  COMPARISON OF AVERAGE CRITERIA POLLUTANT EMISSIONS WITH
               EPA AP-42 EMISSION FACTORS FOR OIL-FIRED UTILITY BOILERS


Pollutant

*
NOX (as N02 near full load)
C0f
SO *
2
**
Total Organics
Total Parti culatestf
Emission
Test Data


116
6.6
98


0.42-0.58
7.5
Factor (nq/J)
AP-42
Emission Factor

309
14.7
84


2.94
14.2

  NO  was determined by continuous chemiluminescent analysis (Level  1).
t
  CO was determined by continuous non-dispersive infrared analysis (Level  2),
  S09 was determined by continuous pulsed fluorescence analysis (Level  2).
tt
Cl-Cie fractions were determined by gas chromatograph while the >C,g
fraction was determined gravimetrically (Level 1).
Total particulates v/ere determined by a modified Method 5 procedure
(Level 2).
                                    21

-------
                                 TABLE 4-6.  SUMMARY OF CRITERIA POLLUTANT EMISSIONS
IV)
ro

Test No.
141
142
143
144
Average
Emission Factor (ng/J)
NO
(as N02)
114
91
117
98
105
CO
11.3
5.2
5.6
4.5
6.6
•MI^BH^HH^MMBMBHM
so2
105
95
90*
103
98
CTC6
Organlcs*
0.35-0.56
0.29-0.43
0.11-0.22
NDf
0.25-0.40
C7"C16
Organlcs
NDf
0.02
0.02
NDt
0.02
>C16
Organlcs
NDf
0.16
0.14
NDf
0.15
Total
Organlcs
NDf
0.47-0.61
0.27-0.38
NDt
0.37-0.50
Total
Parti culates
NDf
8.3
6.6
NDf
7.5
        Upper limit values Include detection limits.


      f ND - data not available.


      * Average of continuous monitoring (105 ng/J) and CCS (75.6 ng/J) data for Test 143.

-------
     Average S02 emissions were 98 ng/J for oil firing.  This uncontrolled
emission factor is higher than the AP-42 emission factor of 84 ng/J for oil
firing but is well below the NSPS limit of 344 ng/J for oil-fired utility
boilers.
Total Organics—
     In the determination of organic emissions, gas chromatographic analyses
were performed on grab bag samples of flue gas and catches from the Level 1
sampling (SASS train).  Additionally, gravimetric analyses were performed
on Level 1  samples to quantify high molecular weight organics.  Each bag
sample was  collected over an interval of 30 to 45 minutes, with a single
sample being collected per test.  These samples were utilized to measure
C, to Cg hydrocarbons.  The SASS train collects approximately 30 cubic
meters of flue gas which are drawn isokinetically during the test.  Samples
from the SASS train were analyzed to determine organics higher than Cg.
The C7 to C16 fraction was determined by gas chromatograph while organics
higher than C,g were determined gravimetrically.
     Measured organics consisted primarily of the C-j-Cg fraction.  Average
emissions of the C-,-Cg fraction were 0.25 to 0.40 ng/J while those for the
Cy-C-ic and higher molecular weight fractions were 0.02 ng/J and 0.15 ng/J,
respectively.
     Average organic emissions were 0.4-0.5 ng/J, which is only 15% of the
reported AP-42 value of 2.94 ng/J for oil-fired utility boilers.  The higher
"measured" organic value includes the detection limit concentrations for
fractions which were not detected and, as such, represents an upper limit.
Total Particulates--
     Average emissions of total particulates were 7.5 ng/J.  The measured
particulate emission factor is only about half the reported AP-42 value of
14.2 ng/J, probably due to the extremely low ash content (0.01%) of the
fuel oil burned.  Measured emissions are well  below the NSPS limit of 43
ng/J.
                                    23

-------
Particulate Size Distribution
     Due to the extremely light particulate loading, particulate size
distribution data are not available.  However, data available from the
literature have indicated that generally 90 wt. % of emitted particulates
are less than 7 ym for oil-fired boilers (7).
     In a recent draft document issued by the  Health Effects Research
Laboratory (HERL) of EPA (8), it is stated that larger particulates (from
3 to 15 ym) deposited in the upper respiratory system (in the nasopharynx
and conducting airways) can also be associated with health  problems.   This
is in contrast to the past belief that particulates of health consequence
were those less than 3 ym size and deep-lung penetrable.  The area of
concern now is particulates which are 15 ym and less, which have been
designated as "inhaled particulates" (IP).  For oil firing, it can be
reasonably assumed that almost all the particulates emitted are 15 ym or
less.
Sulfur Compounds;  SOo. SO^, and S0^~
     Sulfur species were determined using several methods.   SOp at the stack
was continuously monitored during all  tests using a pulsed fluorescent
analyzer.  During test 143, the CCS was also used to collect SC^ (from the
impinger), SO, (condensed as HgSO^), and S0^~  (by anion analysis of the
particulate catch).  Sulfur speciation data are listed in Table 4-7.   An
average of 97.7% of the output sulfur is emitted as SCL.
     Parti cul ate sulfate represented 1.1% of sulfur emissions.  Sulfate
emissions broken down into water- and acid-soluble fractions are presented
in Table 4-8.  The bulk (>872») of the parti cul ate sul fates  was present in
the water-soluble fraction.
     Approximately 1.2% of the sulfur emitted was in the form of SOg.  The
S03 emissions were lower than typical  values reported in the literature (9),
probably because of the lower vanadium and nickel content of the fuel oil
burned, and because of the use of flue gas recirculation which reduces the
oxygen concentration and, therefore, reduces SO  formation rate.
                                   24

-------
               TABLE  4-7.   S02,  S03,  AND S04  EMISSIONS

Sulfur
Compound

S09
L.




S03
SV


Test No.


141
142
143
144
143
Average
143
143


Sarupl i ng
Method

Continuous
"
11
11
CCS

CCS
CCS


Stack
Gas
ng/J
105
95
105
103
75.6
98
1.14
1.27


Mole % of Total
Sulfur Species
in Flue Gas




97.7

1.2
1.1

 Level  2 procedures  v/ere utilized.
               TABLE 4-8.   SUMMARY OF SULFATE EMISSIONS

Test
No.
143
Sampling
Point
Stack
Water Soluble
Sul fates
ng/J % of Total
1.27 >87.0
Acid Soluble
Sul fates
ng/J % of Total
<0.19 <13
Total
ng/J
1.27-1.46

Level  2 procedures were utilized.
                                  25

-------
Inorganics
     Trace element concentrations in the flue gas were computed by assuming
that all trace elements present in the fuel oil are emitted in the stack.
Trace elements in the fuel oil were determined using spark source mass
spectrometry (SSMS).
     Concentrations of 39 major trace elements present in the flue gas are
presented in Table 4-9.  To assess the hazard potential of these emissions,
the emission concentrations are compared with the DMEG values.  The DMEG
values are emission level goals developed under direction of EPA, and can
be considered as concentrations of pollutants in undiluted emission streams
that will not adversely affect those persons or ecological systems exposed
for short periods of time (10).  The DMEG values tabulated represent air
concentrations which were derived from human health considerations based on
the most hazardous compound formed by the element in question.  Only
chromium and nickel exceeded their DMEG values at the stack.  Chromium and
nickel have low DMEG values due to considerations of potential human
carcinogenicity.  Emission factors for the trace elements analyzed are
presented in Table 4-10.
Chloride and Fluoride Emissions
     Specific anion analysis was performed on extracts from particulate
catches and iropinger solutions from  the Goksoyr-Ross sampling train  (Test
143).  Emissions of Cl" and F" were  1.34 ng/J and 0.061 ng/J, respectively.
However, anticipated emissions based on SSMS analysis of a composite fuel
sample from Tests 141-144 are 0.002  ng C1~/J and 0.0002 ng F"/J.  Whether
this discrepancy is the result of analytical problems or due  to significant
variation in Cl~ and F" contents of  the different fuel samples cannot be
conclusively determined from available data.  Yet,  ultimate fuel analyses
indicate little variation among  the  fuel samples.   Also, it is known that
halogens are not determined well by  SSMS.  Fluorine  is  particularly  difficult
to analyze by SSMS.  On the other hand, specific ion electrode analyses are
generally accurate to within approximately 15%.  Hence, it appears  reason-
able to conclude that the observed discrepancy is primarily the result of
analytical problems associated with  SSMS analyses of Cl" and  F" in  the fuel
oil.
                                    26

-------
TABLE 4-9.  EMISSION CONCENTRATIONS OF TRACE ELEMENTS
Element
AH
As
B
Ba
Be
Br
Ca*
Ce
Cl
Co
Cr
Cs
Cu
F
Fe
Ga
Ge
Hq**
K
La
Li
Mg+
Mn
Mo
Ha*
Ni
P
Pb
Pr
Rb
Sc
Se
Si
Sr
Th
Ti
U
V
Zn
Flue Gas
Concentration*
mg/m3
0.066
<0.0007
0.03
0.03
<0.0007
<0.0007
0.0086
<0.0007
0.007-H-
0.03
0.006
0.005
0.007
<0.0007tt
0.1
0.005
<0.0007
0.005
0.2
0.0007
0.001
0.37
0.003
0.007
2.0
0.5
0.07
0.003
<0.0007
<0.0007
<0.0007
0.001
0.3
0.006
0.01
0.02
<0.01
0.07
0.01
DMEG for Air
(Health Basis)
mg/m3
5.2
0.0020
3.1
0.50
0.0020
10
16
37
No Data
0.050
0.0010
82
0.20
2.5
1.0
5.0
0.56
0.050
2.0
no
0.022
6.0
5.0
5.0
53
0.015
0.10
0.15
No Data
120
53
0.20
10
3.0
No Data
6.0
0.009
0.50
4.0
Discharge
Seven' tyf
0.013
<0.3
0.01
0.06
<0.3
<0. 00007
0.0005
<0. 00002
— — _
0.6
6
0.00006
0.03
<0.0003
0.1
0.001
<0.2
0.1
0.1
0.000006
0.05
0.062
0.0006
0.001
0.038
30
0.7
0.02
___
<0. 000006
sO. 00001
0.005
0.03
0.002
— — «.
0.003
si
0.1
0.002

                                                   - Continued -
                          27

-------
                          TABLE 4-9. (Continued)
*
  Estimates based on average trace element content of the fuel oil, as
  analyzed by SSMS.

  Discharge severity is defined as the ratio of the discharge concentration
  to the DMEG value.

  Estimates based on typical trace element content of the fuel oil reported
  for this site.  SSMS analyses performed on the fuel oil samples indicated
  Al, Ca, Mg, and Na as major components without specific numerical values
  being given.

  Mercury was determined by elemental sparging (Level 1).

  Specific ion analysis performed on the Goksoyr-Ross catch (test 143)
  indicate that the chloride and fluoride concentrations may be as high as
  4.7 and 0.2 ng/m3, respectively.  This discrepancy is considered to result
  primarily from analytical problems associated with SSMS analysis of these
  halides.
                                    28

-------
           TABLE 4-10.   EMISSION  FACTORS  FOR TRACE  ELEMENTS

Element
Alt
As
B
Ba
Be
Br
Cat
Ce
Cl
Co
Cr
Cs
Cu
F
Fe
Ga
Ge
Ha
K
La
Emission Factor,
ng/J
0.023
<0.0002
0.01
0.01
<0.0002
<0.0002
0.0030
<0.0002 .
0.002 (1.34)*
0.01
0.002
0.002
0.002 .
<0.0002 (0.061)*
0.03
0.002
<0.0002
0.002
0.7
0.0002
Element
Li
Mqt
Mn
Mo
Hat
Ni
P
Pb
Pr
Rb
Sc
Se
Si
Sr
Th
Ti
U
V
Zn

Emission Factor,
ng/J
0.0003
0.13
0.001
0.002
0.70
0.2
0.02
0.02
<0.0002
<0.0002
sO.0002
0.0003
0.1
0.002
0.003
0.007
iO.003
0.02
0.003


  Computed  assuming  that all  trace  elements  in the  fuel  were emitted
  through the  stack.   Fuel  trace  elements  were determined by SSMS with
  the exception of Hg  which was determined by elemental  sparging.

  Emission  factors for Al,  Ca, Mg,  and Na  are based on  typical  fuel
  concentrations  of  these elements  for this  site.   SSMS  analyses
  indicated these elements  as major components without  specific
  numerical  values being given.

* Values in parentheses were  obtained from specific ion analysis  of the
  Goksoyr-Ross catch from Test  143.
                                    29

-------
Specific Organic Compounds
     Selected samples were analyzed by combined gas chromatography/mass
spectrometry (GC/MS) for the identification of organic compounds present.
The organic compounds identified include aliphatic hydrocarbons, benzal-
dehyde, trimethyl cyclohexane-one, ^ substituted acetophenone, the methyl
esters of benzoic acid and substituted benzoic acid, diethylphthalate, and
                                                                  3
ethylbenzaldehyde, at concentration levels between 0.02 and 2 yg/m .
     Emissions of polycyclic organic matter (POM) determined by GC/MS are
summarized in Table 4-11.  Naphthalene is the principal component of the
POM emissions.  Benzopyrenes were detected at low levels but specific
isomers cannot be differentiated.  Hence, it is not known whether benzo(a)-
pyrene was present.  With the exception of the possible presence of
benzo(a)pyrene, all POM compounds from oil firing are at levels too low to
be of environmental concern.
LIQUID WASTE
     There are no significant wastewater streams associated with the oil-
fired boiler tested.
SOLID WASTE
     There are no significant solid wastes generated from the oil-fired
boiler tested.
                                    30

-------
               TABLE 4-11.  POM EMISSIONS FROM OIL FIRING
Compound
Naphthalene
Phenanthridine
Dibenzothiophene*
Anthracene/
phenanthrene
Fluoranthene
Pyrene
Chrysene/
benz(a)anthracene
**
Benzopyrene and
perylenes
Tetramethyl - . .
phenanthrene
Total
Emission 3
Concentration, yg/m
Test 142 Test 143
7 3
0.3
0.6
1 0.2
1
1
0.1
0.04
0.6
11.0 3.8
DMEG
Value
vg/m^
50,000
No data
23,000
1,600
90,000
230,000
45
0.02
1,600

Discharge
Severity

Test 142 Test 143
0.0001 <0.
ND
<0.0001
0.0006 0.
<0.0001
<0.0001
0.0022
2
0.

0001
0001
--
--
--
0004

  Level  2  procedures were utilized.
f Due to the low compound concentration, phenanthridene has not been
  positively identified.
  Due to the low compound concentration, dibenzothiophene has not been
  positively identified.  Also, the DMEG value for dibenzothiophene is
  assumed to be the same as that for benzothiophene.
  The DMEG value for benzo(a)pyrene is used in the computation of the
  discharge severity.
      DMEG value for tetramethyl phenanthrene is assumed to be the
  same as that for phenanthrene.
                                   31

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                         REFERENCES  FOR SECTION 4
 1.   Magee,  E.H.,  H.J.  Hall, and G.M. Varga, Jr.  Potential pollutants in
     Fossil  Fuels.  Report  prepared by ESSO Research and Engineering Co.
     for EPA under contract No. 68-02-0629.  June 1973.

 2.   Tyndall, M.F., F.D.  Kodras, J.K. Pickett, R.A. Symonds, and W.C. Tu.
     Environmental Assessment  for  Residual Oil Utilization - Second Annual
     Report.  Report prepared  by Catalytic Inc. for EPA under contract No.
     68-02-2155.   EPA-600/7-78-175.  September 1978.

 3.   Woodle, R.A.  and W.B.  Chandler, Jr.  Mechanism of Occurrence of Metals
     in Petroleum  Distillates.  Industrial and Engineering Chemistry 44:
     2591, November 1952.

 4.   Bennett, R.L. and  K.J. Knapp.  Particulate Sulfur and Trace Metal
     Emissions from Oil-fired  Power Plants.  Presented at AIChE meeting.
     June 1977.

 5.   Compilation of Air Pollution  Emission Factors, AP-42, Part A.  Third
     Edition.  U.S. Environmental  Protection Agency.  August 1977.

 6.   Ctvrtnicek, T.E. and S.J. Rusek.  Applicability of NOX Combustion
     Modifications to Cyclone  Boilers  (Furnaces).  Report prepared by
     Monsanto Research  Corp. for the U.S. Environmental Protection Agency.
     EPA-600/7-17-006.  January 1977.  NTIS PB 263 960.

 7.   Fine Particulate Emission Inventory  and Control Survey.  Prepared by
     Midwest Research Institute for the U.S. Environmental Protection Agency,
     EPA-450/3-74-040.  January 1974.  NTIS PB 234 156.

 8.   Miller, S.S.   Inhaled  Particulates.  Environmental Science and Tech-
     nology  12 (13): 1353-1355.  December 1978.

 9.   Homolya, J.B. and  J.L. Cheney.  An Assessment of Sulfuric Acid and
     Sulfate Emissions  from the Combustion of Fossil Fuels.  In Workshop
     Proceedings on Primary Sulfate Emissions from Corabustion~S~ources.
     Volume  2 - Characterization.  EPA-600/9-78-020b.  August 1978.

10.   Cleland, J.6. and  G.L. Kingsbury.  Multimedia Environmental Goals for
     Environmental Assessment.  Volumes 1 and 2.  EPA-600/7-77-136a.
     November 1977.
                                    32

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                                 SECTION 5
                      ENVIRONMENTAL IMPACT ASSESSMENT

     This section presents an evaluation of impacts resulting from emissions
from oil  combustion in utility boilers similar to the emissions observed at
the Haynes station.  The evaluation is conducted in five parts.  The first
part introduces background information pertinent to the development of the
environmental assessment, including a review of relevant studies, plant
emissions, and air quality forecasts.  In the succeeding parts, the major
health, ecological, and economic impacts resulting from oil firing in con-
trolled utility boilers of the type tested are estimated.  The final section
assesses the implications of the impacts for energy development by consi-
dering:  1) the additional controls which may be needed to mitigate the
expected damage levels, and 2) the potential effect of such control needs
on energy cost and energy resource development.
INTRODUCTION
     Economic and environmental concerns over the nation's energy develop-
ment policies have precipitated several research efforts to evaluate the
consequences of all phases of energy development, from fuel production to
fuel end use.  To organize the various efforts into a systematic, coordinated,
environmental assessment structure, the Environmental Protection Agency is
implementing a Conventional Combustion Environmental Assessment (CCEA)
Program.  This program has been established for the purpose of integrating
together separate data generated by past and current studies into a complete
environmental assessment of conventional combustion processes.  The integra-
tion procedure involves coordination and information exchange between EPA
related studies to:  1) determine  the extent to which the  total environmental,
economic, and energy impacts of conventional combustion process can be
assessed, 2) identify additional information needed for complete assessment,
3) define the requirements for modifications or additional developments of
control technology, and 4) define  the requirements for modified or new
standards to regulate pollutant emissions.  The CCEA Program coordinates
                                    33

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and integrates current and future studies encompassing a wide spectrum of
environmental assessment areas and conventional combustion processes.
Integration of these studies, including the present effort, will provide
the basis for energy policies which result in the expanded use of conven-
tional combustion processes at reasonable environmental, economic, and
energy costs.
AIR QUALITY
Model Plant Emissions
     Air quality impacts of oil firing in utility boilers were estimated
based on a hypothetical model plant.  The model plant was characterized
using emission factors derived from the Haynes plant test data and assumed
meteorological parameters.  The model plant was assumed to have the same
fuel and boiler characteristics as the Haynes station.  The criteria pollu-
tant emission rates utilized are shown in Table 5-1.  Comparison of the
measured trace element emission concentrations with DMEG values revealed
that the flue gas contained only 2 elements which exceed their DMEG values
at the stack, Cr and Ni.  Hence, only these trace elements were considered
in the analysis.
           TABLE 5-1.  EMISSION RATES FROM A CONTROLLED 353 MW
                       (GROSS) OIL-FIRED UTILITY BOILER
           Pollutant                            Emissions, gm/sec
           NO                                         95.2
           CO                                          5.4
           S02                                        80
           Total Organics                          0.34 - 0.4
           Total Particulates                          6.2
           Cr*                                         0.002
           Ni*                                         0.2
    Trace  element concentration in the  flue  gas  (based upon fuel analyses)
    exceeds  DMEG value.
                                    34

-------
Annual Emissions
     Estimated annual emissions for oil-fired plants generating 353 MW
(gross) are presented in Table 5-2.  These estimates are based on the
emission factors determined for the Haynes No. 5 boiler during oil  firing.
For annual emission computations, the plant was assumed to operate at 93%
of its maximum load with 40% overall efficiency, for 7008 hours/year (80%
of the year).  These assumptions are based upon measurements made during
the test period and operability data provided by Haynes personnel.
Impact on Air Quality
     The duration of exposure is important in determining effects of changing
air quality.  The highest concentrations occur  for short periods (usually
less  than one hour) under meteorological conditions causing plume trapping.
The stack emissions are trapped  under an inversion layer, with the plume
spreading downward.  The frequency of occurrence and the severity of plume
trapping conditions varies depending on the  site.  As  a conservative worst
case  estimate in this study, plume  trapping  conditions were assumed to
persist for  periods as long as three hours.

                        TABLE 5-2.  ANNUAL EMISSIONS*

Pollutant
NOV
x
so2
SO,
3
so4"
CO
Total Organics
f r
1 6
C7"C16
>C16
Total Parti culates
kg/yr
2.40 x 106
2.0 x 106
2.36 x 104
2.63 x 104
c
1.4 x 10s
7.7 x 103 - 10 x 103
5.2 x 103 - 8.3 x 103
y
4 x NT
3.1 x 103
5
1.5 x 10°

     -fired plants  generating  353 MW operating  7008 hours/year.
                                     35

-------
     Typical 24 hour maximum concentrations were estimated assuming Gaussian
steady state plume dispersion under conditions of low wind speed and stable
atmosphere.  Typical 24 hour levels were translated to annual  expected con-
centrations by applying ratios for the one day maximum and annual  mean as
empirically derived from the Continuous Air Monitoring Project (1, 2, 3,  4).
The effective stack height was estimated based on assumed meteorological
conditions, and the actual stack height of the Haynes unit.
     Maximum predicted levels for criteria pollutants in the vicinity of
the model plant are presented in Table 5-3.  Ambient concentrations resulting
from oil firing are in conformance with all tabulated air quality  standards.
The short term maximum concentrations present the most significant air
pollution problem.  For any of the pollutants, it should be noted  that the
short term maximum concentrations generally occur infrequently, depending
on site meteorology, and are usually of very brief duration (about 1  hour or
less).  The maximum concentration levels are localized within a distance  of
about one-half to four miles from the boiler stack.  These concentrations
diminish to about one-half the peak level another one to eight miles further
downwind.  Concentrations of CO and total organics are seen to be  in-
significant with respect to short term NAAQS.  Hence, these compounds will
not be considered further.
     Federal standards limiting deterioration of air quality are generally
more restrictive than the NAAQS.  Included in Table 5-3 is a list  of the
allowable increments of deterioration for the three classes of growth and
development areas.  Allowable emissions may depend primarily on the existing
air quality and the allowable deterioration increment.  Consequently, siting
of the plants would be a major consideration in their environmental accept-
ability, since areas which already experience marginally acceptable air
quality may not tolerate the increases projected to occur.
HEALTH IMPACT
     The health effects of exposure to high concentrations of the  various
pollutants are well known and have been tabulated throughout the literature
(5).  However, the specific extent to which health is affected by  ambient
pollutant exposure levels (dose-response relationships) is unclear.  Moreover,
                                    36

-------
        TABLE 5-3.  COMPARISON OF FEDERAL AIR QUALITY STANDARDS
                    WITH AIR QUALITY PREDICTED TO RESULT FROM OIL
                    COMBUSTION IN A 353 MW (GROSS) UTILITY BOILER

3
Concentration, yg/m
Pollutant Model
Plant NAAQS
PSD
Class
I
**
Increments
Class Class
II III
Annual Mean
     HOX
     CO
     SOo
2
     Total Organlcs
     Total Particulates
24 Hour1"
     NOX
     CO
     so2
     Total Organics
     Total Particulates
1-3 Hour*
0.1
2
0.01
0.1

8
0.4
6
0.04
0.5
100
 80
 75
         20
         19
        40
        37
   tt
365
260
         91      182
10
37
75
NOV
x
CO
so2
Total Organics
Total Particulates
260

15
230
1
18
___

40,000tf
1,300
160
« _ _
___ ___ ___

— — —
25 512 700
— — —
__ _ ___ ___

   The expected annual average levels were estimated based on the conser-
   vative end of the range of typical ratios for 24 hour maximum to annual
   as reported in the Air Quality Criteria Documents (1, 2, 3, 4).
   Based on typical meteorological conditions for 24 hour period.
   Based on worst case meteorological conditions (plume trapping).
**
   Prevention of significant deterioration standards (PSD).
ft The NAAQS for CO are 40,000 yg/m3 for a 1 hour period and 10,000 yg/m
   for an 8 hour period.
                                    37

-------
it is unclear how pollutant specific dose-response curves may be related
to the overall health effects of the gas-aerosol complex associated with
fossil fuel combustion products.
     Most attempts to establish dose-response functions for ambient pollu-
tion levels involve the formulation of some indicator which is then assumed
to represent the entire spectrum of primary and secondary pollutants present.
The indicator (usually sulfur dioxide, total particulates, or sulfates) is
then related to mortality or morbidity data for various areas by various
statistical approaches designed to factor out effects of other variables
(e.g., population age, climatology, etc.).  Dose-response curves derived
from these studies are then employed to estimate health effects of air
quality changes resulting from proposed projects.
     Recently, the health effects model by Lundy and Grahn (6) has been
developed for application in the National Coal Utilization Assessment Studies
being conducted at Argonne National Laboratories.  The model combines
mortality functions for suspended sulfates as developed by Finch and Morris
(7) and age-dependent and established response curves for cigarette smoke.
The mortality dose-response functions for suspended sulfates are based on
statistical studies of various populations experiencing different sulfate
exposures.  Unlike the dose-response air pollution studies, investigations
of smokers have been relatively well controlled with respect to age, degree
of exposure, and effect.  Thus, to expand the predictability of the sulfate
dose-response curves to populations of different age distribution (e.g.,
future populations), the cigarette response curves are adjusted to fit the
observed mortality/sulfate data, resulting in a model which predicts age-
specific death rates.  This elaboration is important because death rates
vary exponentially with age, and shifts in the age distribution of a
population will result in substantial shifts in total mortality.  According-
ly, the Lundy-Grahn Model utilizes projections of the population age
distribution to estimate the age-specific and total death rates due to air
pollution at any specific time in the future.  The basic relationship of
the model is:
                                             bX
                          B(X' XO) =
                                    38

-------
where B is the number of excess deaths per year for the population of age
                                                           •5
X which was exposed to the sulfate concentration S (in yg/m) since age Xo.
The constants a,b,c and d are coefficients to fit the model  to cigarette
smoking mortality data and response data for a specific population subgroup
exposed to air pollution.
     The Lundy-Grahn Model is being used in the ongoing National  Coal Utili-
zation Assessment Program to estimate excess mortality resulting  from
increased coal utilization.  Air diffusion modeling was conducted first to
predict a population-weighted exposure increase for suspended sulfates.  The
Lagrangian Statistical Trajectory Model of Argonne National  Laboratory (8),
which assumes a constant transformation of S02 to sulfate, is employed in
the estimation procedure.  This technique has been applied to oil firing;
based on the predicted exposure increase and projections of the population
age distribution, excess death rates are calculated for each age  and summed
to yield the expected mortality associated with oil combustion.  Figure 5-1
presents the adjusted projections for an oil firing scenario through the
year 2020.  The figure indicates that the expected health effects caused by
air pollution (as indexed by suspended sulfates) from oil-firing  of con-
trolled utility boilers are minimal.  The maximum impact is  expected to
occur in the year 2000, when the proportion of population in the  highest
risk age groups will be greatest.  For each million persons, the  expected
increase in death rate when oil firing of utility boilers is prevalent is
49 persons per million.
     Health effects caused by sulfate levels may also be expressed in terms
of morbidity.  Table 5-4 presents data for increases in incidents of health
disorders due to ambient sulfate exposures.  In those areas  which already
experience high sulfate levels, respiratory disease may increase  signifi-
cantly with increases of suspended sulfates due to increased fuel consumption,
                                                       3
For example, in areas where the threshold level 10 yg/m  is  exceeded regu-
larly, the contribution of 2.4 yg/m  of sulfate concentration associated
with controlled oil-fired boilers would be estimated to produce a 32%
increase in the incidence of chronic respiratory disease caused at the
threshold level.
                                    39

-------
oo;
  <
 • LU
O >-


fc"*
f-o

3S
«=C LU
ii
LU
CO

-------
                  TABLE 5-4.  HEALTH IMPACTS OF SULFATE  AEROSOL
Pollute nt and
Health Effect
Si'1 fates
TortfTity
Aggravation of
Heart and Lung
Disease in Elderly
Aggravation of
Asthnia
Lower Respiratory
DiS2P.se in Children
Chronic Respiratory
Disease
Nonsisokers
Smokers
Population at Risk -
Total Population •
Same as above for
oxidants function
Sane as cbove for
oxidants function
Sane as above for
nitrogen dioxide
function
62 percent of
population ags 21
or older
38 percent of
population age 21
or o]dsr
Assumed Baseline
Frequency of
Disorder within
Population at Risk
Dally death rate of
2.58 per 100, DOO
Same
Same
Sams
Two percent
prevalence
Ten percent
prevalence
PolTutcnt
Concentration
Threshold
For Effect
25 iig/n3 for
one day or
more
9 yg/rc3 fcr
ons day or
rare
6 yjAn3 for*
one" day or
mere
13 ug/m3 for
several years
10 va/m3 for
several years
15 gg/m3 for
several years
>
Effect Increase a> ;
of Bsseline Pcr
Pc'Ui^art 'JrcU Abnv.-.
Tt-irc^^o^c1
2.5S por 10 ug/r.3
74. 1 2 par 70 pg/n3
33.5- per 10 vg/n3
75.95 psr 10 vg/^3
13« per 10 pc/ns
73. Si pr>r 10 vg/n3
Reference 9.

-------
     In addition to potential health effects created by long range sulfate
levels from utility boilers, high concentrations of pollutants in the pro-
ximity of the power plant pose a potentially serious health problem.  The
Lundy-Grahn model may also be applied to estimate mortality effects caused
by ambient levels of SCL and total suspended particulates.  The model gives
the following relationships when fitted to Lave and Seskin dose-response
data (6) for S02 and total suspended particulate (TSP):

                        .823e-'064X
     per 10  males:
                         100e
                             "'2(X ' Xo)
                                          (.835  TSP  +  .715  S02)
           (•               nccQ-088X
     per 10b females:  	'-^^	  (.835 TSP + .715 S02)
                       1 + 100e"'2(X " Xo)
If the model is applied for average concentrations expected to occur in the
vicinity of a power plant (Table 5-3), the expected increase in mortality
is appreciable.  Figure 5-2 illustrates the estimated impact on mortality.
When boilers are fired with oil, the increased death rate is about 19 male
and 9 female deaths per million persons per year, at age 50.
o
  a:
  • «C
O Lul
i_- >-
  a**^*
UJ ~j
=50
£X CO
  a:
      50-1-
      40-
      30-
ui z
oo
  »—I
5J   20- •
  i
LU:
CO '
   CO
 cc
      ID-
                                               Male response
                                                Female response
               10
                     20
30    40    50    60
     POPULATION AGE
         Figure 5-2.  Increase in Mortality Rates in Vicinity
                      of Oil-fired Utility Boilers as a Result
                      of S00 and Total Particulate Emissions.
                                    42

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Effect of Trace Elements--
     Trace elements from combustion emissions  enter the atmosphere  and  are
then dispersed to the upper atmosphere or deposited in the  environment
around the sources.  The principal  routes of entry to man are  by  inhalation,
drinking water, and food.
     Table 5-5 summarizes estimates of the annual  average atmospheric con-
centrations of Cr and Ni expected in the vicinity  of a single  oil-fired
utility boiler of 353 MW gross  capacity.  These elements were  examined
because their stack concentrations  exceeded their  respective DMEG values.
Also included in Table 5-5 is a listing of concentrations considered accept-
able for continuous ambient exposure.  The allowable concentrations are
based on proposed regulations for control of air pollution  from hazardous
waste management facilities, as required by Section 3004 of the Resource
Conservation and Recovery Act.   It is clear that the air concentrations of
trace elements resulting from operation of the utility boiler  are several
orders of magnitude below either the allowable exposure level  or typical
urban air concentrations.
      TABLE 5-5.  EXPECTED TRACE ELEMENT CONCENTRATIONS IN VICINITY
                  OF A 353 MW (GROSS) OIL-FIRED UTILITY BOILER

Annual Ambient
Element Concentration
vg/m3
Cr 0.00003
Ni 0.004
Typical
Urban Air
Concentration
vg/m3
.010
1.40
Allowable
Exposure
Levelt
yg/m^
50
100

     Based on data reported in References 10, 11, and 12.
     Based on ambient air objectives proposed for hazardous waste
     management facilities (13).
                                    43

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     A primary concern in emissions of trace elements is the contribution
of these elements to body burden due to exposure to water and food.  To
estimate this contribution, pollutant deposition rates are approximated by
the product of the ambient concentrations and the deposition velocity of
the pollutant.  The deposition rate is dependent on particle size.  As dis-
cussed previously particles emitted from an oil-fired boiler are predomi-
nantly less than 7 ym in diameter.  Available data indicate that the median
particle size is in the 1 ym to 3 ym range.  The deposition velocity of
particles this size over grass surfaces is approximately 0.1 to 0.2 cm/sec
(14).  Accordingly, the deposition rates of the various trace elements were
approximated and are shown in Table 5-6.
     The significance of the deposition rates is evaluated by considering
the associated effect on drinking water and diet.  The pathway to drinking
water is by run-off of soil particles containing deposits of trace elements,
and the pathway to the diet is by plant uptake from trace elements in the
soil.  In either pathway, the incremental concentration of elements in the
soil determines the extent of the potential impact.  Table 5-7 summarizes
the maximum predicted soil concentration in the .vicinity of the oil-fired
model plant.  The concentrations are estimated by assuming mixing of the
deposited elements to a depth of 10 cm, and over a period of 40 years.  For
these trace elements, only minor increases over the background soil levels
would be expected.  The significance of elevated soil concentrations is
evaluated by considering the associated increase in trace element concentra-
tion in plant tissues and drinking water.
     The concentration of elements in plant tissues is related to the bio-
logically available fraction of the elements in the soil.  This is often
expressed as the soluble concentration in the soil, and is some fraction of
the total concentration reported in Table 5-7.  Plants possess the ability
to concentrate elements from dilute soil solutions.  This ability is depen-
dent on the concentration of elements in the soil, and usually increases with
decreasing soil concentrations.  The ratio of concentration of elements in
plants to the concentration in the soil is known as the concentration ratio.
Table 5-8 lists average plant concentration ratios for various elements.
The data are based on various published data as compiled in a study by
                                    44

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     TABLE 5-6.   ANNUAL DEPOSITION OF TRACE ELEMENTS IN  VICINITY
                 OF CONTROLLED OIL-FIRED POWER PLANTS
     Element
     Annual  Deposition Rate ,
             g/m2-yr.
       Cr

       Ni
            1.9 x 10

            2.5 x 10
-6

-4
       Calculated by assuming a particulate deposition velocity
       of 0.2 cm/sec.  The deposition velocity is multiplied by
       the annual average concentration to estimate the total
       deposition rate.  The deposition rate is calculated for the
       location where the maximum average annual  concentration
       occurs.
TABLE 5-7.   LONG TERM EFFECT OF CONTROLLED OIL-FIRED UTILITY BOILER
            EMISSIONS ON SOIL CONCENTRATIONS OF TRACE ELEMENTS
              Increased Soil
 Element      Concentration
             After 40 Years*,
                  mg/kg
   Typical
    Soil
Concentration'5'
    mg/kg
 Increase Over
 Average Soil
Concentrations,
Cr
Ni
0.001
0.07
40
40
0.003
0.2

   Based on deposition rate (Table 5-6), an assumed mixing depth of
   10 cm and soil  density of 1.5 gm/cm3.

   Based on data compiled in Reference 15.
                                  45

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       TABLE 5-8.  LONG TERM EFFECT OF CONTROLLED OIL-FIRED BOILER
                   EMISSIONS ON CONCENTRATIONS OF ELEMENTS  IN PLANTS
           Concentration     Solubility*       Typical         Increase  in
Element       Ratios*       of Elements     Concentration    Concentration
                                 01           in Plants,*      of Plants,t
                                                rig/kg            rng/kg
10
Cr
N1
250
331
0.004
0.1
.23 0.00001
3 0.02

  Extracted from Reference 15.
f Calculated by multiplying concentration ratio by the incremental  increase
  in soil concentration (Table 5-7) by the fraction of the element  which is
  soluble.
Battelle  (15).  The effect of increased trace element soil  loadings (caused
by 40 years of boiler emissions) on concentration of the elements in plants
is then estimated by assuming that the soluble portion of the loadings  is
available for plant takeup.  The estimates reveal that oil  firing produces
less than a 1% increase in concentrations of chromium and nickel  in plants.
The actual impact of trace element emissions on plant burden depends greatly
on many site-specific variables, such as temperature, precipitation, soil
type, water chemistry, and plant species at a given site.
     Trace elements also enter the plant via foliar absorption.  Intake
from the leaf surface to the interior occurs through stomatal openings,
walls of epidemal cells, and leaf hairs.  Although relatively little is
known regarding the efficiency of foliar intake, it would appear that the
plant burden produced by soils containing long term deposits is several
orders of magnitude greater than that which could be transferred from foliar
interception of trace elements in the atmosphere.  Soil concentrations  are
the result of accumulation of elements over the long-term,  and crops raised
in these soils tend to concentrate the trace elements in the plant tissue.
                                    46

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By contrast, the foliar intake rate can be no greater than  the deposition
rate on the plant surface, and there is much uncertainty regarding the
efficiency of the plant in absorbing the deposited particles.   Thus,  it is
clear that the soil  uptake scenario (Table 5-8) represents  the more adverse
case for plant uptake of trace elements.  This scenario assumes no inter-
ference (e.g., animal or crop uptake) with trace element buildup in soils
over a 40 year period, and a fixed concentration of elements  in the soil
despite crop uptake.
     Trace elements  emissions could also affect the quality of drinking
water.  The impact of trace element particle deposition on  runoff water
concentration will be related to the relative increase in soil concentration
due to long term atmospheric deposition of elements.  The actual runoff con-
centrations may be estimated by applying average sediment burden rates for
representative runoff per unit of watershed area.  The sediment is assumed
to carry the cumulative deposits of metals originating from the boiler
emissions.  Table 5-9 summarizes estimates of increased soluble metals con-
centrations for runoff waters in the vicinity of the model  plant.  Runoff
water in this vicinity contains trace elements at levels from six to nine
orders of magnitude  less than the potable water standard.
IMPACT ON ECOLOGY
     The ecological  environment will be affected by air emissions and by
solid waste residuals generated by air pollution control equipment.
Effect of Air Emissions
     A major ecological impact category most likely to be affected by
utility boiler emissions is plant life.  Of the major gaseous pollutants
emitted by fossil fuel combustion, plant life is most affected by SOg and
NO  in the concentration ranges expected.  Concentrations of CO and hydro-
  A
carbons produced by oil firing of utility boilers would be  expected to cause
negligible impact on vegetation (4, 16).  The maximum levels  of NOX and SOg
expected to occur in the vicinity of utility boilers may exceed the
threshold injury values for these pollutants.  Sensitive plants in the
vicinity of the utility boiler could suffer injury, although  such injury
would be limited to a downwind sector a few miles from the  plant.
                                    47

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00
                         TABLE  5-9.  TRACE ELEMENT CONCENTRATION IN RUNOFF WATER IN VICINITY
                                    OF CONTROLLED OIL-FIRED UTILITY BOILER



Element




Cr
Ni
Typical
Background
Concentration
of Soluble
Metals In
Runoff Water*
mg/1
1 x 10"5
1 x 10"4
Increase in
Soluble Metals
Concentration
in Soil After
40 Yearst

mg/kg
4 x 10"8
7 x 10"5
Increase in
Soluble Metals
Concentration
In Runoff Water*
After 40 Years

mg/1
4 x 10"11
7 x 10"8
EPA Proposed
Maximum
Acceptable
Concentration
for Livestock

mg/1
1
—
Standard
As Critical
Concentration
in Potable
Water

mg/1
2 x 10"2
5 x 10"2
          Based on  average  soil  parti culate  runoff  rate of 1000 mg/1 of runoff water, and soluble endogenous
          concentration  of  metals  in  soils  (15).
        f Based on  increase in  trace  element concentration (Table 5-7) and solubility of elements (Table 5-8)

        * Based on  average  soil  particle  runoff rate of 1000 mg/1 of runoff water, and increased soluble
          metals concentration  in  soil  after 40 years.

-------
     The secondary pollutants  (ozone and peroxyacytylnitrates)  formed  by
reaction of hydrocarbons and nitrogen oxides  are considerably more  toxic
than either of the precursors  alone.  The formation of secondary  compounds
in boiler stack plumes  and the impact of the  boiler nitrogen oxides  emis-
sions on urban photochemical smog depend on complex relationships which
are not yet totally understood.  Therefore, it is not possible  to reliably
estimate the effect of NOV emissions levels on levels of photochemical com-
                         A
pounds.  However, based on typical  regional emissions figures,  it appears
that emissions from power plant fuel combustion provide a significant  source
of the regional emissions of NO  necessary for photochemical smog.   Approxi-
                               A
mately 28% of the nation's NOX emissions are  produced by combustion in power
plants (17).
     If NOV emissions from utility boilers are a significant contributor  to
          A
photochemical smog, then there is valid concern that boiler emissions  may
contribute to plant injury. The effects of photochemical air  pollution on
plant life have been observed  frequently at various different  severities
throughout the United States.   In addition, the effect of the  major consti-
tuents of photochemical smog (products of nitrogen oxides and  organic  com-
pounds) on plants has been investigated separately.  The pigmentation  of
small areas of palisade cells  is characteristic of ozone injury,  and a
bronzing of the undersurface of leaves is typical for peroxyacytylnitrate
injury.  Table 5-10 illustrates the relatively low levels of ozone  which
will produce significant plant injury to crops.  The concentrations shown
are typical of many areas experiencing photochemical air pollution, and
suggest the necessity for concern over sources emitting high levels of NOX>
     Nitrogen oxides may also  cause injury to vegetation by direct  contact.
The significant oxides of nitrogen are NO and NO .  The major  oxide in com-
                                                A
bustion emissions is NO.  However, after residence in the atmosphere,  NO  is
converted to NO,, by photolysis and by photochemical interaction with hydro-
carbons.  The effect of NOp on plant life has been studied under  controlled
laboratory conditions.  Acute  injury is characterized by collapse of cells
and subsequent development of necrotic patterns.  Chronic injury, caused  by
exposure to low concentrations over long periods, is characterized  by
chlorotic or other pigmented patterns in leaf tissue.  Such injury  results
                                    49

-------
   TABLE 5-10.  PROJECTED OZONE CONCENTRATIONS WHICH WILL PRODUCE,  FOR
                SHORT TERM EXPOSURES, 20 PERCENT INJURY TO ECONOMICALLY
                IMPORTANT VEGETATION GROWN UNDER SENSITIVE CONDITIONS*

Concentrations
Time, Hr
0.2
0.5
1.0
2.0
4.0
8.0
producing injury
Sensitive
0.40-0.90
0.20-0.40
0.15-0.30
0.10-0.25
0.07-0.20
0.05-0.15
in three types
Intermediate
0.80-1.10
0.35-0.70
0.25-0.55
0.20-0.45
0.15-0.40
0.10-0.35
of plants, ppm
Resistant
1.00 and up
0.60 and up
0.50 and up
0.40 and up
0.35 and up
0.30 and up

*
  Reference 18.
in reduction of growth and reproduction.  Only limited data are available
to characterize the effect of NO on plants.  Generally, it appears that NO
leads to effects somewhat similar to those observed for N02, but at slightly
higher threshold concentrations.  Therefore, for worst case evaluations of
the impact of ambient NO  levels, it is assumed that NOV exists as NO,, and
                        A                              X             t
that the NOX levels are not depleted by the photochemical  reactions which
typically occur in urban areas.
     Figure 5-3 illustrates the threshold concentrations at which various
degrees of damage result from exposure to NOg.  As the long term concentra-
tion of NOX in the vicinity of the model plant is estimated at 2 yg/m3,
injury to plants from oil  firing is not likely to occur.  Even the maximum
short term ambient concentration of NOV near the oil-fired boiler, which is
                        3
estimated to be 260 yg/m ,  is below the threshold levels which induce plant
injury.
                                    50

-------
              0.01
                         0.1
                        „ !
                               DAYS
                                 1.0
                                            10
                                            f
100
       1030-j.
    CL.
    CL
    CV
   o
U-
c

o
I—•<
H-
   8
        100
        10-
        o.i
                                                                •: -1000
                        IH:ATH
                                                             1
                                                               100
                                THRESHOLD FOR FOLIAR LESIONS
                METABOLIC AND GHOWTl-i PFFECTS
                                                                      ro
                                                                       cv;
                                                                      O
                                                                  •10   1'
                                                                  •1.0
                                                              10,000
       0.1         i!c          10         100        1000
                      DURATION OF EXPOSURE (HOURS)
            Figure 5-3.  NOg Threshold Concentrations for Various
                         Degrees of Plant Injury (19).
     Acute short term injury  to  vegetation  by SOg exposure is characterized
by damaged leaf areas which first  appear as water soaked spots, and later
appear as bleached white areas or  darkened  reddish areas.  Chronic S02
injury is usually characterized  by chlorosis (yellowing) which develops from
lower concentrations over extended periods  of time.  Either acute or chronic
SOg injury may result in death or  reduced yield of the plant if the extent
of the damaged tissue exceeds 5  to 30  percent of the total amount of foliage.
                                     51

-------
     The impact of the expected SOg concentrations  varies  with  the plant
species.  Threshold injury in sensitive plants may  be  caused by short-term
                            o
S00 levels as low as 30 ug/m  (20).  Table 5-11 summarizes the  broad cate-
gories of sensitivity for different plants.  Grain, vegetable,  pasture,  and
forage crops are susceptible to SOg damage for most of the growing season.
These crops may suffer yield reductions in areas where power plants such as
that of the present study are located, although the damage v/ould be relati-
vely localized.  Data presented in Figure 5-4 indicate that the peak short
                                  3
term S02 concentration of 230 yg/m  near the oil-fired boiler may exceed the
injury threshold of sensitive plants, although the  damage  would be slight.
     It should be noted that the plant damage thresholds illustrated by
Figure 5-4 apply to conditions of temperature, humidity, soil moisture,
light intensity, nutrient supply, and plant age which  cause maximum sus-
ceptibility to injury.  The occurrence of such conditions  are rare.  In
fact, in the unlikely event that all such conditions are met, the dose-
response curves indicate that plant injury could occur without  a violation
of the federal air quality standard for the 3 hour or 24 hour concentration
of SOp.  Additional susceptibility may also result from synergistic effects
of sulfur dioxide and other pollutants.  Particularly relevant  to the urban
environment are combinations of sulfur dioxide and ozone.   Moderate to
severe injury of tobacco plants have been observed for four hour exposures
                                      q
to concentrations of 0.1 ppm (262 ug/m ) SOg in combination with 0.03 ppm
ozone.  Because high ozone levels are a frequent problem in the vicinity of
urban areas, susceptibility to plant injury by S02 pollution is greater
when utility boilers are also sited in urban areas.  One of the major con-
cerns associated with fossil fuel utilization is acid precipitation resulting
from wet deposition of suspended sulfur and nitrate compounds.   Data show
that there has been an intensification of acidity in the northeastern region
of the U.S. since the mid 1950's.  Precipitation in a large portion of the
eastern U.S. averages between pH 4.0 and 4.2 annually.  Values  between pH
2.1 and 3.6 have been measured for individual storms at distances several
hundred miles downwind of urban centers.  The areas experiencing highest
acidity are typically downwind of the areas where sulfur emissions are
highest (19, 22).
                                    52

-------
      TABLE 5-11.   SENSITIVITY OF  COMMON PLANTS TO S02  INJURY
Vegetation
Sensitive intoiT*cliatt Resistant
'.:-jiic pin--1 Kaple ' Sufjar ;njjjle
r.oldfci'irod Virginia irccpor Phlox
f.nttOri.o.';fi V.'hito 03r Gok
Viiv.ir.ia 'cri-oper F.lm Mdplc
,'••;«. or Short loaf pine Shrub!:/ willow
n.jssrlitrry '.stcr
I}::- Linden
v;ild §rcpfi
A:-sric«'i eln
Wnito Ash
Virijinij pine -•
Tulip tree
Cro;>s
Str.si'.ive Inten-Pi!iatc
Alfalfa Irish Potato
Borloy Clover
Oils Sweet clover
Rye
Wi.c?.t
Siveei; potato
Soybcaii
Sweet clover
Cotton Tobacco
Clover


1
Resistant
Corn
.Sor.;l.j7!










Reference 21.
                           SO, DOSE-INJURY CURVES
                         FOR SENSITIVE PLANT SPECIES
                                DAMAGE LIKELY
                 INJURY OR DAMAGE
                    POS?!c'.LE
                 (THKESIIOL!) RANGE)

                       DURATION OF EXPOSURE, hi

      Figure 5-4.   SOg Dose-Injury Curves for  Sensitive
                     Plant Species (20).
                                 53

-------
     Acid rain affects plant life in varying degrees depending on the pH
and the type of plant species.  Experiments show that the effects on plants
may include reduction in growth or yield, leaf damage, death, and chlorosis.
Acid rain also has been shown  to affect aquatic organisms, and it is be-
lieved that thousands of lakes are now experiencing reductions in fish
population due to acidification between pH 5.0 and 6.0 (19).  The level  of
                                                              3
sulfates estimated to result from oil firing is about 2.4 yg/m , a level
not expected to result in significant acid precipitation.  Based on tests
of the utility boiler of this  study, it appears that emissions from oil
firing are not apt to cause adverse plant burdens of either chromium or
nickel.
ECONOMIC  IMPACT
     The  direct economic impacts associated with residuals of fuel combus-
tion involve the  costs of damages (or benefits) sustained when the residuals
enter  the environment.  Second order economic impacts associated with the
residuals involve the alterations that occur in employment, the tax base,
energy prices, income, and  land values due to the damages (or benefits)
resulting from combustion residuals.  The quantification of direct economic
impacts involves  the difficult task of ascribing economic values to environ-
mental changes.   Quantification of second order economic effects are yet
more difficult because of gaps in knowledge which make it impossible to
determine the complex relationships between cost and the numerous socio-
economic  factors  involved.
     A number of ongoing energy related studies are attempting to develop
sophisticated economic models which will predict the cost of environmental
damages (6, 21, 23).  The models address the cost of visibility reduction,
health effects (morbidity and mortality), and certain second order effects.
Utilization of the models requires substantial input data involving regional
demography and emission source distributions.  The models require further
refinement and are currently under continuing development.  The data base
or scope of the present program did not permit the adaption and utilization
of such models.
                                    54

-------
     The extent of the economic impacts resulting from residuals  of 353 MW
oil-fired utility boilers is proportional to the extent of the environmental
damages which occur.  The analyses have shown that while some impact of
emissions from the oil-fired boiler tested in this study may occur, federal
ambient air quality standards for sulfur oxides and nitrogen oxides will
probably not be violated in the vicinity of the model plant.  However, in
spite of conformance with air quality standards, the economic cost of plant
emissions in the affected areas may be significant.  These costs  include
medical expenses, loss of productivity, cost of cleanup and maintenance for
soiling damages, and reduced crop revenues.
     Whatever the extent to which additional controls may be required for
oil-fired boilers, the cost of such controls will probably be relatively
minor compared to the overall operating cost of a boiler and other factors
affecting the overall costs.  Even when predicted pollutant loadings meet
environmental standards, it is not entirely clear whether the increasing use
of fossil fuels may be continued at the forecasted levels of control tech-
nology without potential long term environmental damages.  If it  is found
that long term effects of pollution (e.g., trace metals accumulation, lake
acidity, land use) are unacceptable, then more stringent environmental
regulations can be expected, and it is clear that energy cost will  increase
with increasing control requirements.
                                    55

-------
                        REFERENCES FOR SECTION 5


 1.  U.S. Department of Health, Education,  and Welfare.   Air Quality Criteria
     for Sulfur Oxides.  AP-50.  March 1967.

 2.  U.S. Department of Health, Education,  and Welfare.   Air Quality Criteria
     for Nitrogen Oxides.  January 1971.

 3.  U.S. Department of Health, Education,  and Welfare.   Air Quality Criteria
     for Particulate Matter.  January 1969.

 4.  U.S. Department of Health, Education,  and Welfare.   Air Quality Criteria
     for Carbon Monoxide.  March 1970.

 5.  Waldbott, G.  Health Effects of Environmental Pollutants.   1973.

 6.  Lundy, R.T. and D. Grahn, Argonne National Laboratory.   Predictions of
     the Effects of Energy Production on Human Health.   Paper presented at
     the Joint Statistical Meetings of the  American Statistical  Association
     Biometric Society, Chicago, Illinois.   August 1977.

 7.  Finch, S. and S. Morris, Brookhaven National Laboratory.  Consistency
     of  Reported Health Effects of Air Pollution.  BNL-21808.

 8.  Sheih, C.  Application of a Langrangian Statistical Trajectory Model to
     the Simulation of Sulfur Pollution over North Eastern United States.
     Preprints of Third Symposium on Atmospheric Turbulence, Diffusion, and
     Air Quality.  1976.

 9.  Nelson, W., J. Knelson, V. Hasselblab, Health Effects Research Labora-
     tory of Environmental Protection Agency.  Air Pollutant Health Effects
     Estimation Model.  EPA Conference on Environmental  Modeling and Simula-
     tion, Cincinnati.  April 1976.

10.  Effects of Trace Contaminants from Coal  Combustion.  Proceedings of a
     Workshop Sponsored by Division of Biomedical and Environmental Research
     and Development Administration, August 1976, Knoxville, Tennessee.

11.  Sullivan, R.J. Litton Systems, Inc.  Air Pollution  Aspects  of Iron and
     its  Compounds.  U.S. Department of Commerce/National  Bureau of Standards,
     September 1969.

12.  Y.C., Athanassiadis, Litton Systems, Inc. Air Pollution Aspects of
     Zinc and its Compounds.  U.S. Department of  Commerce/National Bureau
     of Standards,  September 1969.
                                    56

-------
13.  Draft of proposed rules for "Standards  Applicable  to Owners and
     Operators of Hazardous Waste Treatment, Storage, and Disposal Facili-
     ties".  Obtained from Office of Solid Waste,  Environmental Protection
     Agency.  March 1978.

14.  Sehmel, G., Battelle Pacific Northwest  Laboratories.   Pacific Northwest
     Laboratory Annual Report for 1972.  BNUL-1751,  Volume  II,  1973.

15.  Vaughan, B., et al, Battelle Pacific Northwest  Laboratories.  Review of
     Potential Impact on Health and Environmental  Quality from  Metals
     Entering the Environment as a Result of Coal  Utilization.  August  1975.

16.  Department of Health, Education, and Welfare.  Air Quality Criteria
     for Hydrocarbons.  March 1970.

17.  U.S. Environmental Protection Agency.  1975 National Emissions  Report.
     May 1978.

18.  Department of Health, Education, and Welfare.  Air Quality Criteria
     for Photochemical Oxidants.  March 1970.

19.  Glass, N., Office of Health and Ecological Effects.  Ecological  Effects
     of Gaseous Emissions from Coal Combustion.  November 1977.

20.  Argonne National Laboratory.  The Environmental Effects of Using Coal
     for Generating Electricity.  Prepared for Nuclear Regulatory  Commission.
     Washington, D.C.  May 1977.

21.  Argonne National Laboratory.  A Preliminary Assessment of the Health
     and Environmental Effects of Coal Utilization in the Midwest.  January
     1977.

22.  Argonne National Laboratory.  Assessment of the Health and Environmental
     Effects of Power Generation in the Midwest, Vol. II,  Ecological  Effects.
     April  1977.

23.  Ford,  A. and H.W. Lorber, Los Alamos Scientific Laboratory.   Methodolo-
     gy for the Analysis of the  Impacts of Electric Power Production in the
     West.  January 1977.
                                     57

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                                 APPENDIX A
                         SIMPLIFIED AIR QUALITY MODEL

     Simple ambient air quality models were used to estimate the maximum
expected ground level concentrations of criteria pollutants.  It is
important to recognize that these air quality values are estimates only.
based upon several simplified assumptions, as discussed below.  Two sets
of meteorological conditions were considered: worst case and typical.
Conditions were selected that are representative of what could reasonably
be expected to occur almost anywhere in the country but are not specific
to the area of the plant from which the pollutant emission rates were
obtained.  It was assumed that all species were inert.  No photochemical
reactions were considered.
     There are several meteorological conditions which can produce high
ground level pollutant concentrations.  These conditions can result in
plume coning, looping, fumigation, and trapping, all of which can cause
high ambient concentrations.  In the case of coning, high levels occur
along the plume centerline.  Looping causes high ground level concentrations
at points where the plume impacts the ground.  Fumigation causes high ground
level concentrations which are generally lower than those from plume
trapping.  For this study it was assumed that plume trapping constituted
the worst case in terms of ground level concentrations.
     Trapping conditions occur when an inversion layer or stable air aloft
inhibits upward dispersion of the plume.  Although the plume is trapped by
the capping stable layer at height L, the plume distribution is still
Gaussian in the horizontal and uniform in the vertical directions.  Ambient
concentrations can be estimated by the following equation (1):
r
*-
                     exp . 1/2            + exp .
                                                                       (1)
              N-l   L                                    °z
                                    58

-------
            + exp - 1/2 (zrH±2Nk)2  + exp _      (z±H±2NL)2] j
                           az                       °z     J >

Where: X (x,y,z;H) = Concentration at point (x,y,z)  assuming  an
                     effective stack height of H, yg/m^
                H  = Effective stack height, m
                Q  = Pollutant emission rate, kg/hr
                H  = Mean wind speed, m/s
                a  = Concentration distribution within the  plume
                     in the horizontal (^y) and vertical  (^z)
                     directions, m
                z  = Height above the ground, m
                J  = Maximum wind speed class index, unitless
                N  = Wind speed class index, unitless
                L  = Height of the stable layer, m
     At ground level (z=0) and at the plume center line (y=0)
Equation (1) reduces to:
                                                                   2
                                                             +2NL

                                                                      (2)
     For typical conditions, ground level  concentrations were  calculated
using a Gaussian solution to the convective diffusion equation (2):
                                  2            2
X (x,y,o) = yq Q .  exp - {(H2/2az ) + ( y2/2ay ) }                    (3)
              y z s
Where:          X  = Concentration, g/m
                Q  = Pollutant release rate, g/s
                                                •
            a  a,  = Crosswind and vertical plume  standard deviations, m
             y» z
               q   = Mean wind speed, m/s
                H  = Effective stack height, m
              x,y  = Downwind and crosswind distances,  m.

                                    59

-------
At the plume center-line, Equation  (3) reduces  to:

                X  (x.o.o)  =   m 9  -   exp   -  -L                  (4))
                               TOy  V          2a£2

The maximum value  of  this equation occurs at the distance where

a  = H /
      In Equations  (3)  and  (4),  H  is  defined by:

                            H  =  H? +  AH                                 (5)

 Where Hg  =  physical  height of the stack  and H »  plume rise, both, expressed
 in meters.   There  are  more than 30 plume-rise formulas in  the  literature,
 all  of which require empirical  determination of  one or more constants,  for
 the  purpose of this  study, the  Briggs plume rjs.e formula was chosen to
 calculate the final  plume  rise  in stable conditions,
                          AH  * 2.6   ( rfr)                           C6)
 Where:         AH  -  Plume  rise, ro
                 v  =  Wind speed, m/s
                 s  *  Stability  parameter,  unitless
                 F  =  Buoyancy flux.
 The stability parameter, s, is defined as:

                           S - 1 H                                 (7)
                               e  3 z
                                                2
Where:          g = Gravitational constant, m/s ;
                e = Potential air temperature,  K
            3G/3Z = (3T^z)  + 0,0098 K/m, the potential temperature
                    gradient.   Based on the normal lapse rate, 3T/3Z, of
                    temperature in the atmosphere of -0.0065 K/m, a value
                    of .0033 K/m was employed for  Jia  in this study,
                                                   3Z
                                    60

-------
The buoyancy flux, F, is defined as:
                F = f1  gwr2                                           (8)

Where       AT = Stack temperature minus the ambient air temperature,  K
            T  = Stack temperature,  K
                                            2
             g = Gravitational constant, m/s
             w = Stack exit velocity, m/s
             r = Inside radius of the stack, m.
     The plume rise was calculated using Equation (6).  The data used  for
the calculations are shown in Table A-l.  The values selected for wind speed
are discussed below.
                TABLE A-l.  STACK PARAMETERS AND PLUME RISE

             Stack temperature,  K                       394
             Ambient temperature, K                      293
             Stack exit velocity, m/s                     24
                          2
             Stack area, m                                26
             Stack height, m                              73
     Equation (2) was used to estimate maximum ambient concentrations
resulting from short term meteorological conditions causing plume trapping.
As a worst case estimate for this study, plume trapping conditions were
assumed to persist for periods as long as three hours.  Equation (4) was
used to estimate maximum ambient concentrations for condtions which could
typically persist over a 24 hour period.  For the 24 hour concentration
forecasts, typical conditions of wind speed (4 m/sec) and atmosphere sta-
bility (Class D stability) were assumed to persist.  For the short-term
plume trapping, conditions of low wind speed (1 m/sec) and a moderately
unstable atmosphere (Class B stability) were assumed to persist throughout
the applicable averaging period.  These conditions were selected because
                                    61

-------
they produce high ground level concentrations.  The inversion inducing
plume trapping was assumed to be at an elevation equivalent to the
effective stack height (504  m).   Results of these calculations are
presented in Table A-2.
           TABLE A-2.  PREDICTED MAXIMUM AMBIENT CONCENTRATIONS
                       OF CRITERIA POLLUTANTS
          Pollutant
Pollutant Concentration,
        ug/n\3
        24  hour  period:
            N0x
            CO*
            S02
            Particulates
            Total  organics

        Plume  trapping:

            NOX
            CO
            S02
            Particulates
            Total  Organics
      8
      0.4
      6
      0.5
      0.04
    260
     15
    230
     18
      1
                                    62

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                        REFERENCES FOR APPENDIX A
1.  Bierly, E. W., and E. W. Hewson.  Some Restrictive Meteorological
    Conditions to be Considered in the Design of Stacks, Journal  Applied
    Meteorology, 1,3, 383-390, 1962.

2.  Slade, D. H. Meteorology and Atomic Energy, U. S. Atomic Energy
    Commission, 1968.
                                    63

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                                APPENDIX B

                       ORGANIC ANALYSES - OIL FIRING


Sample Preparation

     Emissions from the stack at the oil-fired utility boiler were sampled

both while the unit was operating at 62 and 92% of full load.  The test run

at 62% of full load conditions will be referred to as test 142; the run at

92% of full load will be called test 143.

     Two  additional  test runs were made,  using the SASS train, which were

not analyzed.  All  samples  from the four  tests were  prepared for analysis

using  procedures  detailed in  Reference B-2, with modifications whenever

necessary to  ensure Level 2 quality data  would be produced.  The steps

involved  for  each  sample type are summarized below.

      XAD-2 resins:  Each sample was extracted  in a Soxhlet apparatus
          for 24 hours with  methylene  chloride.

      Filters:  Each sample  was extracted  In  a  Soxhlet apparatus for
          24 hours with methylene  chloride.

      XAD-2 module condensates:  Each  sample  was extracted three
          times with methylene chloride at adjusted pH condition
          to first 11, and then 2.  The volume  of methylene chloride
          used for each extraction was  ten percent of the  condensate
          volume.

      Organic  rinses:  No preparation  required.

      One  milliliter aliquots  were taken of all  these samples for  subsequent
TCO analysis.  Then the solutions were concentrated  to 10 ml  in Kuderna-

Danish evaporators.   Aliquots taken for analyses  Included 1  ml for TCO,

1 ml  for  GRAV/IR and a  composite  for  GC/MS prepared  as follows:

     CD-LEA-KD      1  ml              CDB-LEA-KD      1  ml
     CD-LEB-KD      1  ml              CDB-LEB-KD      1  ml
     XR-SE-KD       2  ml              XRB-SE-KD       2 ml
     PF-SE-KD       2  ml              PFB-SE-KD       2 ml
     PR-O-KD        2  ml              MAB-O-KD        4 ml
     MR-O-KD        2  ml
                                    64

-------
     The flow diagram in Figure B-l shows the sample  handling and analysis
scheme used.  The sample code is explained in Table  B-l.
Summary
Level 1 —
     The total amounts of organics found in the stack emissions  during these
two tests are shown below:
     Test       C1"C6          C7"C16       * C16     ^ota1  Or9anics
      142   850-1241 yg/m3   61 .1 yg/m3   478 yg/m3   1389-1780 yg/m3
      143   327-652          54.6         397         779-1104

     The field GC analysis showed measurable amounts of only C-j , i.e.,
methane.  The laboratory GC analysis indicated about fifty percent  of the
                                                                        3
less volatile materials were in the Cg boiling range.  The other 20 yg/m
were reasonably well distributed throughout the entire 200°C boiling point
range being examined.
     A peak-by-peak evaluation of the chromatograms of the Cy-C-ic compounds
shows no signs of the acetone condensation products mesityl  oxide (a Cg) or
diacetone alcohol (a CQ).
     The amount of material less volatile than n-heptane in individual
samples was too low to trigger the Level 1 liquid chroma tographic separation
procedure.  Also, the infrared spectra of XAD-2 resin samples were  in-
distinguishable from the resin blank.
Level 2--
     Results of the analysis of the combined SASS train extracts and the
controls are summarized as follows:
     1)  The compounds found in the combined SASS train extracts
         and which are believed to have been present in the gas
         sample are present at 2 yg/m3 or less.  Many of the
         compounds identified in the total sample are sorbent
         resin artifacts.
     2)  Some compounds could not be identified by computerized
         data reduction techniques.  These are believed to be
         si li cone artifacts, for the most part.
                                    65

-------

1 ml allqu
N »
JH]
t * i 1 ml all
JTCOJ
F





ot
quot
yes

LC
RACTIONATION
frcol
}GRAV/IR|
I—*T
IGC/MSI
H^
IS THE SAMPLE
ADEQUATELY
CHARACTERIZED
.no
SPECIAL
ANALYSIS
I solution


.XfsN.
^r CONTENT. ^S..,, no
"V^ bOO yg/m" ^^
bulk
. » r .L
IKUOERNA-DANISH
CONCENTRATION
* 1 mi aliquot
JGRAV |
1 ^
B
COMPOSITE
SASS TRAIN
SAMPLES
10 ml
^•Jl '
1^^^^™^^™^
Cr/uc 1
uu/ro-i

IS THE
ADEQUJ
CHARAC


SAMPLE yes / 	 N
in Y , . . . f 5TOP I
TERIZED v-^ 	 '
no
SPECIAL
ANALYSES
Figure B-l.  Flow Chart of Sample Handling and Analysis Procedures
                              66

-------
                              TABLE B-l.  SAMPLE CODE FOR ORGANIC SAMPLES ANALYZED

                                                     SAMPLE CODE

                                                  •XXX-XX-XX-XX-XX-
cr>
Site
Identification
Sample
Type
Sample
Preparation
First Level
Analysis
Second Level
Analysis
                141
                142
                143
                144
CD-condensate

   from XAD-2
   module
PR-solvent probe
   rinse
MR-solvent XAD-2
   module rinse

XR-XAD-2 resin

PF-filters

XM-composite of
   SASS train
   component
   samples
0-no preparation
LEA-liquid-liquid
   extraction,
   acidified
   sample
LEB-liquid-liquid
   extraction,
   basic sample

SE-Soxhlet solvent
   extraction
                      KD-K-D
                         concen-
                         tration
GC-C7-C16


GI-GRAV/IR

MS-GC/MS
LC-LC separation

-------
     3)  Some POM were found in the samples  at levels  ranging
         from less than 0.05 to 10 vg/m3 of  sampled  gas.
Level 1 Data
Total Chromatographable Organics Analysis (TCO)--
     TCOs were performed as described earlier.   All  samples were analyzed
both prior to and after the Kuderna-Danish concentration  step.   The results
of the C7-C,g analyses on the K-D concentrates are given  in Table B-2.
The unconcentrated samples did not contain any detectable quantity of
hydrocarbons, and are, therefore, not listed.
Field Gas Chromatographic Analyses—•
     The chromatographic analyses performed  in the field  make  use of a
Shimadzu GC-Min 1 gas chromatograph with dual  flame ionization detectors.
Separations are made on a 183 cm x 0.32 cm stainless steel Poropak Q
packed column.
     Calibration and quantitation is accomplished using the same techniques
as in the laboratory.  The n-alkanes and the data reporting ranges are
listed below.
            C1     -160 to -100°C            C4     0 to  30°C
            C2     -100 to - 50°C            C5     30 to 60°C
            C3     - 50 to 0°C               Cg     60 to 90°C
     The detection limits for the field GC analyses, properly  calibrated
                                            3
with C,-C, standards, are 0.1 ppm or 65 yg/m  hydrocarbon as methane.
     Results of the field analysis are summarized in Table B-3.
Gravimetry for C13 and Higher Hydrocarbons-
     Gravimetric determinations were performed on the concentrates of
solvent rinses and extracts in accordance with the procedure in Reference
B-2:  a one milliliter aliquot was taken from each sample and  evaporated to
dryness in an aluminum pan.  The residues were then weighed on a micro-
balance.  The results are presented in Table B-4.
                                    68

-------
                   TABLE  B-2.   RESULTS OF TCO ANALYSIS OF UNCONCENTRATED AND CONCENTRATED SAMPLES
10
0
Hydrocarbon Content, pg/m
Sample
142-CD-LEA-KD-GC
142-CD-LEB-KD-GC
143-CD-LEA-KD-GC
143-CD-LEB-KD-KC
142-XR-SE-KD-GC
143-XR-SE-KD-GC
142-PF-SE-KD-GC
143-PF-SE-KD-GC
142-PR-O-KD-GC
143-PR-O-KD-GC
142-MR-O-KD-GC
143-MR-O-KD-GC
C7
LB
LB
LB
< 0.1
0.4
0.4
0
0
0
0
0
0
C8
0
0
0
0
26.5
28.1
LB
0
0
0.2
0
0
C9
0
0
0
0
1.0
2.2
0
0.9
2.9
3,6
4.6
3.6

-------
TABLE B-3.  RESULTS OF FIELD GC ANALYSIS
3
Hydrocarbon Content, vg/m
Sample GI Cg C3 C^ Cg Cg
141 981 <65 <262 <131 < 65 < 65
142 850 < 65 <131 < 65 < 65 < 65
143 327 < 65 < 65 < 65 < 65 < 65
144 (no data)
Total
981 - 1569
850 - 1241
327 - 652


-------
TABLE B-4.  GRAVIMETRY OF SAMPLE CONCENTRATES
Sampl e
142-CD-LEA-KD-GI
142-CD-LEB-KD-GI
143-CD-LEA-KD-GI
143-CD-LEB-KD-GI
142-XR-SE-KD-GI
143-XR-SE-KD-GI
142-PF-SE-KD-GI
143-PF-SE-KD-GI
142-PR-O-KD-GI
143-PR-O-KD-GI
142-MR-O-KD-GI
143-MR-O-KD-GI
141-COB-LEA-KD-GI
141-COB-LEB-KD-GI
141-XRB-SE-KD-GI
141-PFB-SE-KD-GI
141-MCB-O-KD-GI
141-MAB-O-KD-GI
Weight
mg/ml
0.078
0.051
0.103
0.050
1.470
1.582
0.135
0.093
0.159
0
0.142
0.138
0.075
0.036
0.582
0.121
0.075
0.109
Correction for
Blank, mg/ml
LB
LB
0.028
0.013
0.954
1.104
0.014
LB
0.110
0
0.077
0.070






Aliquot
Factor
XI 0
XI 0
xio
X10
XIO
XIO
XIO
XIO
XIO
XIO
XIO
XIO






Sample 3
Volume, m
24.4
24.4
30.6
30.6
24.4
30.6
24.4
30.6
24.4
30.6
24.4
30.6






Net Gcav,
yg/nr
0
0
9.2
4.2
396
361
5.7
0
45.1
0
31.5
22.9







-------
Infrared Analyses (IR) on Samples Concentrated in Kuderna-Danish Evaporators--
     Each of the concentrates weighing more than 0,5 mg was also scanned by
infrared (IR) spectroscopy.  After the final weighing, the residue in each
weighing pan was redissolved in methylene chloride and smeared onto a NaCl
window.  The resulting spectra and the compound classes whose presence was
identified are summarized in Table B-5.  The spectra of the samples were
indistinguishable from those of the blanks.
Other Analyses—
                                           3
     No sample contained more than 0.5 mg/m  of organic material.  Applying
stated Level 1 decision criteria, the organic analysis was halted.  A com-
posite sample of all the SASS train components was prepared for Level 2
organic work.
Level 2 Data
     Two different GC/MS analyses were performed.  GC/MS was performed using
parameters as similar as possible to those used in the Total Chromatographable
Organics (TCO) analysis.  The objective of this approach was to identify
peaks seen in the TCO chromatograms.  In addition, several of the samples
in this study were also subjected to a specific POM analysis using a Dexsil
300 column.  Both of these techniques are described in Reference B-2.  A
total of three samples was submitted for this effort.  A description of the
samples analyzed is presented in Table B-6.
     Tables B-7 through B-9 present the results of the GC/MS analyses as
source concentrations.  DMEG values are also given.  Compounds marked with
an asterisk were not found in the blank, as described in the next paragraph.
Except for the possible benzopyrene in the 142 SASS composite, DMEG values
for compounds in Tables B-8 and B-9 were at least 1600 times larger than the
concentrations found.  Benzopyrene was not positively identified, but if the
compound was benzopyrene, it is present at a level 32% above its DMEG value.
     The results for the blank sample (Table B-7) are included in this
document because chemical compound contribution from the blank is substan-
tial v/hen compared to the samples.  Furthermore subtraction of the blank
levels from the sample levels could lead to misinterpretation of the data.
                                    72

-------
TABLE B-5.  INTERPRETATION OF INFRARED
            SPECTRA OF SAMPLE CONCENTRATES
Samp! e
Identifica-
tion
141-XRB-SE-KD-
GI


























Band
Location,
cm"1

3400
3060
2920, 2860
1720
1690, 1670, 1640,
1630
1600
1550
1530
1510, 1480
1460"
1450
1410
1370
1345
1270
mo
930
700









Band
Intensity

W
W
S
M

W
U
W
W
W
M
M
W
M
M
M
S
W
N









Compound
Classification

OH, NH or C « 0 overtone
CH stretch-aromatic
CH stretch-aliphatic
C = 0

C = C
Jenzene ring
<02 antisym stretch
tenzene ring
tenzene ring
sf\n
«Hn
Carboxylic acid
CH3
NO, sym stretch
C-6-C
C-O-H
Carboxylic acid
Ben.zene ring substitution
Indicates esters, poly-
ethylene oxide with
alcohol possible, i.e.,
resin
N.B. Samples 142-XR-SE-KD-
61 and 143-XR-SE-KD-GI
indistinguishable from
blank
- Continued -
                     73

-------
TABLE B-5  (Continued)
Sampl e
Identifica-
tion
142-XR-SE-KD-GI

















Band
Location,
cm"1
3560-3140
3060
2920, 2860
1720
1710
1640, 1630
1600
1550
1500, 1495, 1480
1470
1460, 1450
1410
1370
1345
1270
1175
1105
1025, 1015
940
855
835
800
755
710

Band
Intensity
W
W
S
S
S
W
U
W
W
N
W
W
W
M
W
S
W
W
W
K
W
W
W-

Compound
Classification
OH, NH or C » 0 overtone
CH stretch-aromatic
'CH stretchraliphatic
C = 0
C « 0
C = C
Benzene ring
N02 antisym stretch
Benzene ring
CH2
Carboxylic acid
CH3
N02 sym stretch
C-O-C
Unassigned
C-O-H
Unassigned
Carboxylic acid
Benzene ring substitution
- Continued -
        74

-------
                            TABLE B-5  (Continued)
Sampl e
Identifica-
tion
  Band
  Location,
  cm'l
Band
Intensity
 Compound
 Classification
143-XR-SE-KD-GI
    3600-3150
    3060
2960, 2920/2870
    1720
    1710
1640, 1630, 1600,
1530, 1510, 1500
1490, 1470
    1.550
    1460
    1450
    1410
    1370
    1275
    1250
    1175
    1100
    1030
     940
850, 800, 760, 710
   W
   W
   M
   M
   N

   W

   W
   W
   W
   W
   W
   N
   M
   U
   M
   W

   W
OH, NH or C = 0 overtone
CH stretch-aromatic
CH stretch-aliphatic
C = 0
C = 0

Unsaturation; 1600 in
benzene ring
N02 antisym stretch

CH2
Carboxy!ic acid
CH3
C-O-C
c-o-c
Unassigned
C-O-H
Unassigned
Carboxylic acid
Benzene ring substitution
                                    75

-------
          TABLE B-6.  SUMMARY OF  6C/MS  SAMPLES  AND ANALYSES
                      FROM THE  OIL-FIRED SITE
  Sample No.
                  Description
142-XM-SE-KD



143-XM-SE-KD


141-XMB-SE-KD
Composite of SASS Train  Extract and Rinse
Concentrates

Composite of SASS Train  Extract and Rinse
Concentrates

Composite of Blank Samples  Related to SASS Train
Sampling; Also Concentrated
             TABLE B-7.  GC/MS  ANALYSIS OF 141-XMB-SE-KD
                         (BLANK)  COMBINED EXTRACTS
Compound
Level 2 Analysis
Dlethyl benzene
Ethyl styrene
Netliyllndene
Naphthalene
Chloronaphthalene
(Internal Standard)
Ethyl talphenyl or Mphenylethane
Unknown
TMO Components believed to be
Trine thy 1 propenyl naphtha 1 ene
and DlhydrtMethylphenylbenzofuran
Unknown Sillcone Compound
C18H22
Mixture believed to contain
Hexadecyloxypentadecyl - 1.
3-D1oxane and an alcohol >C]4.
Butyl 1 sobutyl phthal ate
Unknown S 111 cone
Unknown Sillcone
Unknown Sillcone
01 octyl phthal ate
POM Analysis
Naphthalene
Possible
Trl Methyl propenyl naphtha 1 ene

Concentration
In Extract
ug/«l

26
60
3
44
20

1*
1
29


13
9
73


17
2
5
4
34

24
11


Simulated
Concentration
In Sampled Gas
wg/m3*

3
7
0.4
5
2

2
0.1
3


2
1
9


2
0.2
0.6
0.5
4

3
1.3

	 1
           Theoretical Sample Volume of 30 m used.
                                   76

-------
TABLE B-8.   GC/MS ANALYSIS OF  142 SASS COMPOSITE
Compound
level 2 Analysis
Ethyl styrene
Nethyllndene
Naphthalene
*B«nza1dehyde
*Tr1methylcyclohexene-one
*C. Substituted Acetophenone
•Substituted Benzole Acid. Methyl
Ester
Chloro naphthalene
(Internal Standard)
Ethyl biphenyl or 01 phenyl ethane
Unknown SlUcone
*D1ethylphthalate
Unknown
Two compounds believed to be
Trimethylpropenylnaphthalene and
Di hyd romethyl phenyl benzof uran
Unknown SI 11 cone
Unknown SlUcone
Unknown
Hexadecyloxypentadecyl - 1,
3-D1oxane
Butyl 1 sobuty 1 phtha 1 ate
*Fluoranthene
*Pyrene
Unknown Si li cone
Dioctylphthalate
POM Analysis
Naphthalene
'Possible Phenanthridene NU179
Possible Trimethylpropenylnaphthalene
'Probable POM KW184
•Phenanthrene
*Fluoranthene
*Pyrene
•Chrysene or other MU228 PON
•Benzopyrene or other MW252 POM
Concentration
In Sampled Gas
wg/m3

4
0.3
4
2
0.4
0.3
0.4
3
0.7
0.7
0.7
0.3
2
0.6
3
0.4
2
1
2
0.6
0.7
25

10
0.3
2
0.6
1
1
1
0.1
0.0)
DMEG Value
ng/m3



5.9E4
No Data
4.1E4+
6.1E4
___
	
—
5E3
...
• V —
• »
• .—
...
...
9E4
2.3E5
—
—

...
No Data
—
Unknown
1.6E3
9E4
2.3E5
2.2E3
2E-2
Detected compounds not found in blank sample:  141-XHB-SE-KO.
These are presuned to be 1n the gas sample.

Value is for acetophenone.
                               77

-------
   TABLE B-9.   GC/MS ANALYSIS OF 143 SASS  COMPOSITE
Compound
Level 2 Analysis
Possible trans Chlorocyclohexanol
Methylbenzene
Ethyl styrene
•Benzole Acid, Methyl ester
Possible Methyllndene
Nethyl Indent (Isomer)
•Ethylbenzaldehyde
Naphthalene
•Trine thylcyclohexene-one
*C2 Substituted Acetophenone
•Possible C3 Substituted Phenol
Chi oronaphtnalene
(Internal Standard)
Ethylblphenyl or. Dlphenyl ethane
•Unknown (apparent nle wt 180)
•Dlethylphthalate
Unknown SlUcone
Two Compounds believed to be
Trlnethylpropenylnaphthalene and
DlhydroMthylphenylbenzofuran
Unknown SlUcone
Unknown S1 11 cone
Unknown S1 11 cone
Unknown 51 11 cone
Unknown SlUcone
Unknown; Apparent wle wt 343
Butyl 1 sobutyl phthalate
Unknown SlUcone
•TetraKthyl phenanthrene-
Unknown SlUcone
Oloctylphthalate
POM Analysis
Naphthalene
Possible
Trine thy 1 propenyl naphtha 1 ene
•Anthracene or Phenanthrene or
Other MW178 POM.
Concentration
In Sanoled Gas
w9/"«3

o.s
2
2
0.02
0.07
0.1
0.4
2
O.S
0.2
O.S
2
0.1
0.4
0.2
0.4
2
O.S
0.4
3
0.4
0.4
1
0.8
1
0.6
0.4
2

6
0.5
0.2
OMEG Value
ug/m3

—
—
—
6.1E4
—
—
5.9E4+
—
NO Data
4.1E4+
1 .5E4*
—
—
5E3
...
«•
—

—
-T-
	
...
...
_—
1.6E3
• ••
...

•••
—
1.6E3
  Detected compounds not found 1n blank sanple:  141-XMB>SE-KO.
  Presumed to exist 1n sample gas.

* Value given 1s for parent compound.

* Value Is  for ethyl phenol.
                                  78

-------
The compounds which have been found in the two samples (Tables  B-8 and
B-9) and which are absent in the mixture of blank resin artifacts have been
designated by an asterisk preceding their name.  One will  notice that only
7 to 8 compounds have been so designated.  None of these compounds have been
                                                             3
determined to be in the sample gas at levels exceeding 2 yg/m .
     The lower portions of Tables B-7, B-8, and B-9 present the results of
the specific POM analysis performed.  Several POM compounds were found in
the 142-XM-SE-KD sample when the computerized search techniques for POM were
used.  Three of the compounds were also found by the nonspecific Level 2
technique.  In sample 143-XM-SE-KD, only one compound was found by specific
POM analysis which was not found in the blank.
                                    79

-------
                        REFERENCES  FOR APPENDIX B
B-l.   Leavitt, C., et al.   Environmental Assessment  of Coal  and Oil  Firing
      in a Controlled Industrial  Boiler.   Appendix B.   Report  prepared by
      TRW for the U.S. Environmental  Protection  Agency.  EPA-600/7-78-164a.
      August 1978.

B-2.   Hamersma, J.W., D.G.  Ackerman,  M.M.  Yamada, C.A. Zee,  C.Y.  Ung, K.J.
      McGregor, J.F.  Clausen,  M.L.  Kraft,  J.S. Shapiro, and  E.L.  Moon.
      Emissions Assessment  of  Conventional  Stationary  Combustion  Systems -
      Method and Procedures Manual  for Sampling  and  Analysis.  Report
      prepared by TRW for the  U.S.  Environmental  Protection  Agency.
      EPA-600/7-79-029a.  January 1979.
                                    80

-------
                               TECHNICAL REPORT DATA
                         (Please read Instructions on the reverse before completing)
 REPORT NO.
 EPA-600/7-80-087
                          2.
                                                     3. RECIPIENT'S ACCESSION-NO.
 , TITLE AND SUBTITLE
Environmental Assessment of an Oil-fired
 Controlled Utility Boiler
                                 5. REPORT DATE
                                 April 1980
                                 6. PERFORMING ORGANIZATION CODE
         c  Leavitt,K. Arledge, C. Shih,R. Orsini,
A. Saur ,W. Hamersma,R. Maddalone ,R. Beimer,
j. Richard, S. Unges  and M. Yamada	
. PERFORMING ORGANIZATION NAME AND ADDRESS
TRW, Inc.
One Space Park
Redondo Beach, California 90278
                                                     8. PERFORMING ORGANIZATION REPORT NO.
                                 10. PROGRAM ELEMENT NO.
                                 EHE624A
                                 11. CONTRACT/GRANT NO.

                                 68-02-2613, TaskS
12. SPONSORING AGENCY NAME AND ADDRESS
 EPA, Office of Research and Development
 Industrial Environmental Research Laboratory
 Research Triangle Park, NC  27711
                                                      13. TYPE OF REPORT AND PERIOD COVERED
                                                      Task Final; 6/78-12/79
                                 14. SPONSORING AGENCY CODE
                                   EPA/600/13
15. SUPPLEMENTARY NOTES IERL_RTP project officer is Michael C. Osborne, Mail Drop 62,
919/541-3996.
is. ABSTRACT
              repO1^. gjves results of a comprehensive emissions assessment of the
Haynes No. 5 boiler during oil-firing.  Levels 1 and 2 procedures were used to char-
acterize pollutant emissions. Assessment results , in conjunction with assumed ty-
pical and worst case meteorological conditions , were used to estimate the environ-
mental impact of emissions from this type of unit. Principal conclusions were: (1)
The risk of violating NAAQS due to criteria pollutant emissions is low. (2) Little
adverse health effect is anticipated as a result of SO2, SO4 (--), and particulate
emissions projected from widespread use of oil-fired units of the type tested.  (3) The
impact of trace element burdens in drinking water, plant tissue, soil, and the atmos-
phere is negligible. (4) The risk of plant damage due to criteria pollutant emissions
is remote.  (5) The likelihood of plant damage due to trace  element emissions is
remote.
17.
                             KEY WORDS AND DOCUMENT ANALYSIS
                DESCRIPTORS
                                          b.lDENTIFIERS/OPEN ENDED TERMS
                                             c.  COSATI Field/Group
 Pollution
 Assessments
 Boilers
 Fuel Oil
 Combustion
 Sulfur Oxides
Dust
Pollution Control
Stationary Sources
Environmental Asses-
 sment
Utility Boilers
Particulate
13B
14B
13A
2 ID
21B
07B
11G
13. DISTRIBUTION STATEMENT
 Release to Public
                     19. SECURITY CLASS (ThisReport)
                      Unclassified
                                                                  21. NO. OF PAGES
                     20. SECURITY CLASS (Thispage)
                      Unclassified
                                              22. PRICE
EPA Form 2220-1 (9-73)
                                         81

-------